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209-021
nCGCIV CV • STATE OF ALASKA DEC 10 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: 0 Oil 0 Gas 0 SPLUG El Other ®Abandoned 0 Suspended lb. Well Class 20AAC 25.105 20AAC 25.110 0 Exploratory 0 Stratigraphic ❑GINJ ❑WINJ ❑WAG ❑WDSPL 0 Other No.of Completions Zero • • ® Development 0 Service 2. Operator Name: 5. Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 11/14/2014 • 209-021 • 314-430 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage,Alaska 99519-6612 3/27/2009 50-029-20197-02-00 - 4a. Location of Well(Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 4/6/2009 PBU E-05B • 1353' FNL, 502' FEL, Sec. 06, T11N, R14E, UM 8. KB(ft above MSL): 59.05' 15. Field/Pool(s) Top of Productive Horizon: 734' FNL, 1681' FWL, Sec. 05,T11N, R14E, UM GL(ft above MSL): 30.89 Prudhoe Bay Field/Prudhoe Bay Total Depth: 9. Plug Back Depth(MD+TVD) Oil Pool 667' FNL, 3156' FWL, Sec. 05,T11N, R14E, UM 10099' ' 9066' - 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 664473 - y- 5975711 • Zone- ASP4 ,11440' ' 9068' • ADL 028304 - TPI: x- 666640 y- 5976379 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 668113 y- 5976478 Zone- ASP4 None 18. Directional Surve Y: ❑Yes ® No 19.Water depth, if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: DIR/GR/RES/PWD, DIR/GR/RES/NEU/DEN 5508' • 5216' • 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 31' 106' 31' 106' 26" 125 cu ft Cement 13-3/8" 72# N-80 31' 2845' 31' 2845' 18-1/2" 4020 cu ft PF'C'& Permafrost 9-5/8" 47# N-80 30' 5508' 30' 5216' 12-1/4" 1199 cu ft Howco Lite,250 cu ft Class'G',560 cu ft PF'C' 7" 26# L-80 29' 9670' 29' 8859' 8-1/2" 376 cu ft LiteCrete, 185 cu ft Class'G' 4-1/2" 12.6# L-80 9506' 11438' 8700' 9067' 6-1/8" 309 cu ft Class'G' 24. Open to production or injection? ❑Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ (MD+TVD of Top&Bottom; Perforation Size and Number): TVD) `e 19() 4-1/2", 12.6#, 13Cr80; 9518' 9399'/8596'; atilMfiall 3-1/2", 9.3#, L-80 10306' 11125' 10306•/9077',10701'/9060'.11109'i 9064' ( ��� 26. ACID,FRACTURE,CEMENT SQUEEZE, ETC. p' FEBkey WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ®No SCANNED FEB 2 0 2015 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 10099' Set Whipstock 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Production N/A Date of Test Hours Tested Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ® No Sidewall Core(s)Acquired? 0 Yes ® No If Yes to either question, list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250.071. None Form 10-407 Revised 10/2012 vri- 2/ //J CONTINUED ON REVERSE Submjt Qfi I al Only Alt �� gl ,nV FC JAN _ 9ZOiSr ✓6 29. GEOLOGIC MARKERS(List all formations an kers encounter 30. FORMATION TESTS • NAME ivu) ND Well Tested? v Yes ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sag River 9666' 8855' None Shublik A 9703' 8891' Shublik B 9725' 8911' Shublik C 9755' 8938' Sadlerochit-Zone 4B 9764' 8945' CGL-Zone 3 9894' 9025' Zone 2B 10064' 9059' Zone 2A 11102' 9064' Formation at Total Depth: 31.List of Attachment. Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Well Schematic Diagram 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Email: Trevor.Hyatt@bp.com Trevor Hyatt,564-4627 Printed Name Title: Drilling Technologist Joe Lastufk Signature: Phone 564-4091 Date• 12-h0/14- 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 ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation. Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only E-05B, Well History (Pre-Rig Sidetrack) Date Summary 08/03/14 CTU#9 1.75" QT-1000(CV=31.6)Job Objective: Mill XN, Mill CIBP, Dummy Whipstock Drift MIRU, Make up Baker 3.800" LH Milling Assembly, OAL:18.52'. Tagged XN at 9508 CTM. Milled XN and then continued reaming the profile for 4 up/down passes, followed by a dry drift of the 3.800"centralizer above the motor. Pump 10 bbl 50/50 cap on well. POOH. Inspected milling BHA: DIAMOND PARABOLIC MILL-3.79" GO, STRING MILL 3.79" NO GO, CENTRALIZER 3.79 NO GO-XN is milled to 3.800". Make up/Rih w/Motor, Venturi, 3.70" Burn shoe. Dry tag at 10027'ctm. Come online. Mill with full returns, Lost returns. PUH. Pump 20 bbls 50/50 down backside. Chase CIBP to KB Packer at 10291'ctm. PU 20' Flag pipe Red/Yellow at 10271' E (10293' M) Currently pooh at report time. 08/03/14 T/I/O/OO = 100/175/235/360. Temp =SI. Bleed OOAP (Assist CTU). No AL. Bled OOAP to open top tank, from 360 to 50 psi in 2 min. Monitor OOA while CTU pumps down hole. 08/04/14 Bleed OOAP (Assist CTU). Monitor OOAP while CTU pumps down hole. CTU in control of well upon departure. FWHP's=Vac/100/230/175. IA, OA, OOA=OTG. 0400. 08/04/14 CTU#9 1.75"QT-1000 (CV=31.6)Job Objective: Mill XN, Mill CIBP, Dummy Whipstock Drift. Pooh w/ CTC, DFCV, U/D Jars, Hyd Disco, DCV, Motor, Venturi, 3.70" Burn Shoe. Rih w/CTC, DFCV, U/D Jars, Hyd- Disco, DCV, 3.63"x 12' Drift Bar, 3.71"x 45KB Whipstock Packer Drift(OAL=31.96')to 10190 CTMD-Tagged hard, attempted jetting and could not make any more hole.As per town engineer, decision is to call this depth good. POOH. WS drift BHA laid down and begin weekly BOP test. BOP test complete. RDMO. 09/03/14 T/I/O/OO = SSV/60/260/60. Temp= SI. OA FL(OA FL campaign). No AL. OA FL @ surface. SV,WV, SSV=C. MV=O. IA, OA=OTG. NOVP. 04:15. 10/12/14 T/I/O=VAC/100/0. Install Nordic Test spool#4. Test top of SV to 300 low, 3500 high for 5 min each (PASSED). Set 4"TWC#260. Trorque all Tree flanges to API SPECS. Shell test tree using TWC as barrier to 300 low, 5000 high for 5 min each (PASSED). Pull 4"TWC#260. Shell test between SV and SSV to 3500 (PASSED). SEE LOG FOR DETAILS. RDMO. Final T/I/O=Vac/100/0. LOPC Drill conducted with Well site leader. 10/25/14 T/I/O/OO = SSV/38/?/?. Temp= SI. Snow drifted in cellar, no well house, unable to obtain OA, OOAP. Intial IA FL @ Near Surface. Bled IA from 38 to 0 psi in 1 min all gas. SV, WV, SSV=C. MV=O. IA, = OTG. 2200. 11/01/14 T/I/O/OO=Vac/0/250/0. Set 4""H"TWC#260 Pre CTD For Nordic 1. Final WHP's TWC/0/250/0. 11/05/14 T/I/O/OO = SSV/40/250/109. Temp= SI. Bleed WHP's to 0 psi (pre rig). Unable to reach OOA due to snow in cellar. No wellhouse, scaffold, or flowline. TWC installed. IA FL near surface& OA FL @ surface. Bled IAP&OAP to 20/120 psi in 5 hours filling up 2 slope trailers. Used 30 bbls AMB DSL to re-freeze protect OA. Obtained a LLR of 1.1 gals per minute @ 1000 psi & LLR of.22 bpm @ 1340 psi on OA. Post fill WHPs=SSV/21/1341/270. Monitor for 30 min. OAP decreased 689 psi& OOAP increased 92 psi to 362 psi. Bled OAP to 320 psi in 20 min (OOAP decreased 32 psi), to prevent OOAP from breaking MOASP. Monitor for 20 min. OAP increased 30 psi, OOAP increased 10 psi. Job complete. Final WHPs=SSV/12/350/340. SV,WV=?. SSV=Closed. MV=Open. IA,OA,00A=OTG. NOVP. (2359 hrs). 11/06/14 T/I/O/OO =TWC/12/330/?. Temp= SI. WHPs (Pre RIG). No wellhouse, Flowline or AL. Cannot access OOA, buried in snow. OAP decreased 20 psi overnight. SV, WV=? SSV=C. IA, OA=OTG. OOA=? NOVP 11:30. Page 1 of 2 E-05B, Well History (Pre-Rig Sidetrack) Date Summary 11/07/14 T/I/O/OO =TWC/20/300/390. Temp = SI. WHPs (Pre RWO). No Wellhouse, flowline or scaffolding. Shoveled snow from cellar box to access OA&OOA. Non Hazardous confined space permit for monitor. Installed heater trunk into cellar. IAP increased 8 psi, OAP decreased 30 psi overnight. SV, WV, SSV= C. MV=0. IA, OA, &OOA=OTG. NOVP. 10:00 hrs. 11/08/14 T/I/O/00 =TWC/30/280/380. Temp =SI. Bleed IAP &OOAP to 0 psi (pre RWO). Wellhouse, scaffold, and flowline removed. IA FL near surface. OOA FL . Bled IAP to 0 psi in 2 min (.5 gal). Held open bleed for 30. Monitored fro 30 min. IAP increased 6 psi. Bled IAP to 0 psi in 1 min. Held open bleed for 3 hrs. Bled OOAP to 3 psi in 1 hr. Monitored for 30 min. IAP increased 6 psi, OOAP increased 2 psi. WV, SSV = C. MV= 0. IA, OA, OOA= OTG. 1530. 11/09/14 T/I/O/OO =TWC/26/288/34. Temp= SI. MIT- IA to 3000 psi, **" PASSED***. Bleed IAP to 0 psi post MIT- IA(Pre RWO). IA FL near surface. Pumped 3.5 bbls to test pressure to 3000 psi. First 15 mins IA lost 78 psi, second 15 mins IA lost 24 psi for a total loss of 102 psi in a 30 min test. 11/10/14 Bled IAP from 2896 psi (applied test pressure)to 1 psi in 1 hr with 3 bbls DSL returns. Held open bleed on IA&OOA for 3 hrs. During 30 min monitor. IAP increased 3 psi, OAP unchanged, OOA increased 11 psi.Job complete. See log for details. Final WHPs=TWC/3/275/11. SC,WV, SSV=C. MV=0. IA, OA, OOA= OTG. 04:30. Page 2 of 2 North America-ALASKA-BP Page 13 Operation Summary Report Common Well Name:E-05 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/11/2014 End Date:11/19/2014 X3-015N3-C:(3,291,150.00) Project:Prudhoe Bay Site:PB E Pad Rig Name/No.:NORDIC 1 Spud Date/Time:2/9/1976 12:00:OOAM Rig Release:11/23/2014 Rig Contractor:NORDIC CALISTA UWI:500292019700 Active datum:E-05B©59.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/11/2014 12:00 - 13:00 1.00 MOB P PRE RELEASED FROM E-34,SECURE STACK IN THE CELLAR AND PREP TO MOVE RIG TO E-05 13:00 - 13:20 0.33 MOB P PRE HOLD PJSM TO MOVE OFF E-34 AND MOVE TO E-05 1 13:20 - 14:20 1.00 MOB P PRE MOVE RIG OF E-34 PU T-MATS&PLYWOOD AROUND WELL MOVE RIG DOWN PAD TO E-05 PAD OP SIGNED OFF ON WWTF HOOK UP OA&OOA EXTENSION HOSES TO READ PRESSURES BEFORE SPOTTING T-MATS CALL FOR CSE RESUE TEAM TO BE ASSIGNED TO OUR RIG BUT THEY ARE ON STBY FOR ANOTHER JOB 14:20 - 15:30 1.17 MOB P PRE SPOT RIG TOWARDS THE EDGE OF THE PAD, NORDIC WELDER NEEDS TO REPAIR THE TROUGH IN THE PITS BEFORE PULLING OVER THE WELL NORDIC CREW IS GREASING THE CHOKE MANIFOLD CTS CREW IS SWAPPING GOOSENECK ROLLERS AND THE GRIPPER BLOCKS ON THE INJECTOR 15:30 - 16:15 0.75 MOB P PRE RESUE TEAM ASSIGNED TO NORDIC 1 FOR CSE WORK TO INSTALL EXTENSION HOSES FOR OA&OOA BEFORE THEY GET COVERED WITH THE T-MATS 16:15 - 16:40 0.42 MOB P PRE WELDER IS DONE WITH THE REPAIR,SHUT DOWN ALL RIG POWER FOR THE ELECTRICIAN TO MOVE WIRES AWAY FROM THE RIG EXHAUST 16:40 - 17:50 1.17 MOB N RREP PRE ELECTRICIAN HAS COMPLETED THE WIRE MOVE AND THE RIG IS BACK ONLINE HAVING PROBLEMS GETTING ONE OF THE GENERATORS TO START UP. 17:50 - 18:00 0.17 MOB P PRE VERIFY ALL TREE VALVES ARE CLOSED OA AND OOA HAVE PRESSURE ON THEM (252/117 PSI)THAT WHERE NOTABLE TO BE BLED DOWN.THE VALVES ARE BELOW GROUND LEVEL AND ARE NOT AT RISK TO WHEN BACKING OVER WITH THE RIG.WE HAVE WRITTEN PERMISSION FOR THE WTL TO BACK OVER THE WELL. SPOT RIG OVER WELL 18:00 - 19:00 1.00 RIGU P PRE RIG SPOTTED AND ACCEPTED AT 1800 BEGIN MIRU 19:00 - 19:15 0.25 RIGU P PRE HOLD PJSM TO CYCLE ALL THE VALVES ON THE TREE AND LTT THE MASTER&SWAB VALVES 19:15 - 20:30 1.25 RIGU P PRE INSTALL ANNULUS GUARDS CYCLE TREE VALVES,0 PSI ON TREE CLOSE THE MASTER&SWAB VALVES AND PERFORM LEAK TIGHT TEST REMOVE TREE CAP 20:30 - 00:00 3.50 MOB P PRE INSTALL 4'RISER EXTENSION AND NU BOP GREASE MUD CROSS Printed 12/1/2014 12:49:56PM North America-ALASKA-BP Page 2 ef- fr Operation Summary Report Common Well Name:E-05 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/11/2014 End Date:11/19/2014 X3-015N3-C:(3,291,150.00) Project:Prudhoe Bay Site:PB E Pad Rig Name/No.:NORDIC 1 Spud Date/Time:2/9/1976 12:00:00AM Rig Release:11/23/2014 Rig Contractor:NORDIC CALISTA UWI:500292019700 Active datum:E-05B t 59.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/12/2014 00:00 - 00:30 0.50 RIGU P PRE TAKE AND POST BOP STACK HEIGHT MEASUREMENTS. 00:30 - 01:00 0.50 RIGU P PRE HOLD PJSM FOR PICKING UP GOOSENECK AND PULLING COIL ACROSS FLOOR. COMPLETE DERRICK WORK PERMIT. ESTABLISH BUFFER ZONE ON RIG FLOOR. 01:00 - 02:45 1.75 RIGU P PRE PICK UP AND STAB INJECTOR ON RISER. RU AND CENTER WINCH ON GOOSENECK _ PU GOOSENECK AND INSTALL ON INJECTOR. 02:45 - 04:00 1.25 RIGU P PRE HOLD PJSM,RU AND PULL COIL ACROSS RIG FLOOR. PULL CABLE BACK THROUGH CHAINS. 04:00 - 04:15 0.25 RIGU P PRE PU INJECTOR AND CUT COIL ABOVE GRAPLE. 04:15 - 05:00 0.75 RIGU P PRE PULL BACK INJECTOR. FLUID PACK BOPE. 05:00 - 05:30 0.50 RIGU P PRE HOLD RIG EVACUATION DRILL VITH NIGHT CREW. 05:30 - 06:30 1.00 RIGU P PRE RU FOR HIGH PRESSURE TESTING. HOLD PJSM FOR PRESSURE TESTING BOP. 06:30 - 07:15 0.75 RIGU _ P PRE HOLD PJSM WITH DAY CREW TO TEST BOPE DISCUSS PRESSURE CROSSCHECK CARD I WITH CREW 07:15 - 08:10 0.92 BOPSUR P PRE !SHELL TEST BOPE TO 250 PSI LOW AND 4500 PSI HIGH GOOD LOW PT INCREASE TO HIGH 07:35 BLEED OFF PRESSURE,THE CAP FOR THE KILL LINE CHECK VALVE IS LEAKING 08:10 - 09:20 1.17 BOPSUR P PRE INSTALLED A NEW CRUSH RING ON THE LCHECK VALVE CAP,RESTART SHELL TEST 09:20 - 10:15 0.92 BOPSUR P PRE GOOD SHELL TEST;BLEED OFF TEST PRESSURE LOAD BHI 3"TOOLS ON RIG THEN CONTINUE TESTING BOP 10:15 - 12:05 1.83 BOPSUR P PRE LOWER TEST JOINT AND START TESING BOPE 12:05 - 14:15 2.17 BOPSUR N MISC PRE CANT GET A TEST ON THE VARIBLE RAMS, BLOW DOWN THE STACK TO DOA VISUAL CAN'T TELL WHAT THE PROBLEM IS FROM THE FLOOR,OPEN THE VARIBLE DOORS TO INSPECT 14-15 - 16.00 1.75 BOPSUR N MISC PRE VARIABLE RAMS REMOVED FROM THE VARIABLE STATION HAVE AN OPENING OF 2-5/8".THE PART NUMBERS FOR THE RAMS AND RAM BODIES WERE CHECKED AND THEY ARE BOTH CORRECT.TOT SENT OUT A REVISION FOR THESE VERIABLE RAMS THAT SAYS THESE RAMS ARE GOOD FOR 2-3/8 X 3-1/2.NORDIC IS CHECKING WITH THE RAMS 'INSERTS ON RIG 2 AND THEY HAVE THE SAME EXACT RAMS AS WELL.WE ARE GOING TO TRY TO INSTALL A SET FROM RIG 2 THAT ARE FROM A DIFFERENT BATCH TO SEE IF THEY WORK.RIG 2 JUST SWAPPED FROM ;2-3/8 TO 2"AND USED THE RAMS FROM THAT I BATCH AND DID NOT HAVE ANY PROBLEMS GETTING A GOOD TEST. 16:00 - 17:00 1.00 BOPSUR N MISC PRE TEST GAS ALRAMS SET TEST PLUG WHILE STACK IS DRAINED TO TEST THE 3-1/2 VARIABLES Printed 12/1/2014 12.49.56PM North America-ALASKA-BP Page 3 etfi3 Operation Summary Report Common Well Name:E-05 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/11/2014 End Date:11/19/2014 X3-015N3-C:(3,291,150.00) Project:Prudhoe Bay Site:PB E Pad Rig Name/No.:NORDIC 1 Spud Date/Time:2/9/1976 12:00:00AM Rig Release:11/23/2014 Rig Contractor:NORDIC CALISTA UWI:500292019700 Active datum:E-05B @59.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:00 - 00:00 7.00 BOPSUR P PRE VARIABLE TEST IS GOOD,CONTINUE TESTING BOP TO 250 PSI LOW/3500 PSI HIGH THROUGH TEST#10 WITH 2-3/8"TEST JOINT FUNCTION TEST BOP FROM RIG FLOOR AND OPS CAB PU 3-1/2"TEST JOINT AND TEST VBR RAMS AND ANNULAR BOP TO 250 PSI LOW/3500 PSI HIGH LD 3-1/2"TEST JOINT 11/13/2014 00:00 - 02:15 ' 2.25 BOPSUR P PRE TEST BOP MANUAL LOCKDOWN COMPONENTS ON RAMS TO 250 PSI LOW/ 3500 PSI HIGH FOR 5 MINUTES 02:15 - 02:45 0.50 BOPSUR P PRE HOLD PJSM FOR HEADING UP BHI AND TESTING INNER REEL VALVE/PACKOFF 02:45 - 04:45 2.00 BOPSUR P PRE PU INJECTOR,CUT 5'COIL AND TEST ELINE INSTALL COIL CONNECTOR AND PULL TEST TO 35K HEAD UP BHI UQC 04:45 - 06:35 1.83 BOPSUR P 1 PRE STAB ON INJECTOR AND TORQUE TREE BOLTS FLUID PACK COIL WITH 5 BBLS METHANOL FOLLOWED BY FRESH WATER •PRESSURE TEST REEL HOUSE HARDLINE TO INNER REEL VALVE PRESSURE TEST INNER REEL VALVE TO PACKOFF GOOD TEST 06:35 - 06:50 0.25 BOPSUR P PRE HOLD PJSM TO REMOVE THE INJECTOR FROM THE WELL,INSTALL THE BHI DFCVS, TEST THE CV'S 06:50 - 07:45 0.92 BOPSUR P PRE PU THE INJECTOR,REMOVE THE FLOW SUB AND INSTALL THE DFCVS PT THE CTC&FLOW SUB GOOD PT i PT THE DFCVS 07:45 - 08:00 0.25 BOPSUR P PRE GOOD PT,BLEED OFF THE PRESSURE SET THE INJECTOR ON THE WELL AND 'REMOVE THE UPPER QTS FOR THE 7"OTIS SO THE VALVE CREW LUBRICATOR CAN MAKE UP TO THE STACK DISPLACE THE COIL TO MUD WHILE PULLING THE TWC 08:00 - 08:20 0.33 BOPSUR P PRE HOLD PJSM WITH VALVE CREW TO LOAD EQUIPMENT ON THE RIG TO PULL THE TWC 08:20 - 10:30 2.17 BOPSUR P PRE LOAD LUBRICATOR&PULLING RODS MU PULLING RODS GET STACK MEASUREMENTS PT THE LUBRICATOR GOOD PT GO OVER PROCEDURE TO PULL THE TWC WITH ALL CREW MEMBERS.THERE IS A POTENTIAL TO HAVE HIGH GAS PRESSURE UNDER THE TWC SO ONCE THE TOOL TAGS THE TWC WE WILL PRESSURE UP THE LUBRICATOR TO 2000 PSI THEN UNSEAT THE POPPET.IF THERE IS ANY PRESSURE WE WILL BLEED IT OFF TO THE TT Printed 12/1/2014 12:49:56PM • North America-ALASKA-BP Page 4.0> 8- Operation Summary Report Common Well Name:E-05 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/11/2014 End Date:11/19/2014 X3-015N3-C:(3,291,150.00) Project:Prudhoe Bay Site:PB E Pad Rig Name/No.:NORDIC 1 Spud Date/Time:2/9/1976 12:00:00AM Rig Release:11/23/2014 Rig Contractor:NORDIC CALISTA UW:500292019700 Active datum:E-05B©59.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:30 11:30 1.00 BOPSUR P PRE PULL TWC PULLING TOOL IS MADE UP TO THE TWC AND THERE IS NO PRESSURE UNDER THE TWC PULL TWC ADN TAG UP PERFORM LTTAS PER THE WELL PLAN TO RD THE LUBRICATOR WITH 0 PSI WHP PASSING TEST,RD LUBRICATOR LEFT THE SEAL IN THE WELL,CALL DRLG SUPT&ODE LOAD OUT VC TOOLS 11:30 - 12:30 1.00 BOPSUR P PRE PU THE INJECTOR TO MU THE UPPER QTS THAT WAS USED FOR PULLING THE TWC AND TEST 12:30 - 13:15 0.75 BOPSUR P PRE GOOD TEST RD TEST HOSE AND CHART RECORDER RU QTS TEST HOSE EXTENSION AND TEST 1 THE NIGHT CAP 13:15 - 14:00 0.75 BOPSUR P PRE GOOD TEST LOAD WS ON RIG Printed 12/1/2014 12:49:56PM • North America-ALASKA-BP Page 5 wlla9 Operation Summary Report Common Well Name:E-05 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/11/2014 End Date:11/19/2014 X3-015N3-C:(3,291,150.00) Project:Prudhoe Bay Site:PB E Pad Rig Name/No.:NORDIC 1 Spud Date/Time:2/9/1976 12:00:00AM Rig Release:11/23/2014 Rig Contractor:NORDIC CALISTA UWI:500292019700 Active datum:E-05B @59.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 16:00 2.00 BOPSUR P PRE PUMP 10 BBL METH SPEAR AHEAD FOLLOWED BY 290 BBLS OF 1%KCL FOLLOWED BY 158 BBLS OF 8.6 PPG MUD IAP=0 PSI OA PSI=299 PSI OOA PSI=171 PSI 40 BELS AWAY AND WHP HAS STABILIZED, RATE=6 BPM @1014 PSI 120 BBLS AWAY AND WHP HAS DROPPED, RATE=6 BPM @930 PSI BLEED OA PRESSURE FROM 450 PSI DOWN TO 245 PSI 150 BBLS AWAY WHP STARTING TO CLIMB IAP=482 PSI OA PSI=322 PSI OOA PSI= 198 PSI 170 BBLS AWAY WHP LEVELED OFF AT 1970 PSI IAP=535 PSI OA PSI=352 PSI OOA PSI= 212 PSI 180 BBLS AWAY WHP DROPPED TO 1586 PSI LIKE SOMETHING OPENED UP OR THE MILLED CIBP PUSHED DOWN FURTHER INTO THE PERFS BELOW IAP=559 PSI OA PSI=386 PSI OOA PSI= 236 PSI 220 BBLS AWAY WHP IS SLOWLY DROPPING AT 1527 PSI IAP=647 PSI OA PSI=446 PSI OOA PSI= 281 PSI 235 BBLS AWAY WHP STILL DROPPING AT 1425 PSI IAP=679 PSI OA PSI=469 PSI OOA PSI= 306 PSI BLEED OA DOWN FROM 470 PSI TO 180 PSI 260 BBLS AWAY SLOW DOWN RATE TO EMPTY TRUCK BEFORE SWAPPING TO MUD IAP=674 PSI OA PSI=272 PSI OOA PSI= 330 PSI 275 BBLS SWAP TO MUD 6 BPM AT 1340 PSI IAP=735 PSI OA PSI=310 PSI OOA PSI= 352 PSI 75 BBLS OF MUD AWAY,BLEED OOA FROM 470 TO IAP=479 PSI OA PSI=305 PSI OOA PSI= 200 PSI 100 BBLS AWAY WHP IS STABLE AT 1370 PSI IAP=338 PSI OA PSI=283 PSI OOA PSI= 236 PSI 160 BBLS AWAY WHP IS STARTING TO CLIMB, SHUT DOWN 1 PUMP 162 BBLS AWAY SHUT DOWN PUMP 2 AND Printed 12/1/2014 12:49:56PM North America-ALASKA-BP Page 6 nf$3 Operation Summary Report Common Well Name:E-05 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/11/2014 End Date: 11/19/2014 X3-015N3-C:(3,291,150.00) Project:Prudhoe Bay Site:PB E Pad Rig Name/No.:NORDIC 1 ,Spud Date/Time:2/9/1976 12:00:00AM Rig Release:11/23/2014 Rig Contractor.NORDIC CALISTA UWI:500292019700 Active datum:E-05B @59.05usft(above Mean Sea Level) Date I From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) LINE UP TO CIRCULATE ACROSS THE TOP FROM 1 PIT TO SEE IF WE HAVE A LOSS RATE BEFORE SHUTTING DOWN TO FLOW CHECK FOR 30 MIN 15:33 PIT 1 HAS 69 BBLS 15:36 PIT 1 HAS 66 BBLS j 15:43 LOST 6 BBLS IN 10 MIN OR 36 BPH, CALL DRLG SUPT AND ODE TO DISCUSS 30 MIN FLOW CHECK 16:00 - 16:15 0.25 BOPSUR P PRE 16:03 LOST 14 BBLS IN 30 MIN OR 28 BPH DISCUSSIONS WITH DRLG SUPT&ODE& WTLARE TO MU THE WS BHA AND RIH WHILE i MAINTAINING HOLE FILL HOLD PJSM TO MU THE WS BHA 16:15 - 16:45 0.50 STWHIP P WEXIT MU THE WS BHA 16:45 - 17:05 0.33 STWHIP P WEXIT PTTHEQTS 17:05 - 21:30 4.42 STWHIP P WEXIT RIH WITH WHIPSTOCK BHA AT70 FPM AND 1 BPM IN/1.4 BPM OUT TIE IN TO PDC LOG WITH-10'CORRECTION LOG CCL FROM 9700'TO 10,215' BLEED OOA FROM 480 PSI 21:30 - 22:45 1.25 STWHIP P WEXIT COMPARE CCL LOG TO PLANNED WHIPSTOCK SET DEPTH • CONFIRM 65 ROHS ORIENTATION PU AND SET BOTTOM OF PACKER AT 10115.7' PU TO BREAK OVER WEIGHT OF-49K(X2); PULL OUT 3'COIL SLACK CLOSE EDC AND PRESSURE UP TO 1850 PSI TO SHEAR TOP OF WHIPSTOCK SET AT 10,100' SET DOWN 5K AND CONFIRM ANCHOR SET 22:45 - 23:00 0.25 STWHIP P WEXIT PU,PUMP AT MAX RATE AND ESTABLISH 1/1 RETURNS FLOW CHECK;STATIC 23:00 - 00:00 1.00 STWHIP P WEXIT POH AT 100 FPM 1.5 BPM IN/1 BPM OUT 11/14/2014 '00:00 - 01:00 1.00 STWHIP P WEXIT -POH TO SURFACE -FLOW CHECK;STATIC -HOLD PJSM FOR HANDLING BHA 01:00 - 01:30 0.50 STWHIP P WEXIT LD WHIPSTOCK BHA 01:30 - 02:15 0.75 STWHIP P WEXIT -INSTALL NIGHT CAP AND TEST TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES I-PRESSURE TEST TUBING,LINER AND PACKER/WHIPSTOCK AGAINST NIGHT CAP TO 2400 PSI FOR 10 MINUTES PER WELL PLAN;DROP TO 1150 PSI THROUGH OPEN PERFS AT 9982'-9992' 02:15 - 03:30 1.25 STWHIP P WEXIT REMOVE NIGHT CAP AND MU MILL BHA WITH 2-7/8"XTREME MOTOR AND 3.80"MILL& REAMER 03:30 - 04:00 0.50 STWHIP P WEXIT TEST QTS TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES 04:00 - 05:30 1.50 STWHIP P WEXIT RIH AT 100 FPM WITH MILL BHA f 1.3 BPM IN/1.9 BPM OUT 105:30 - 06:00 0.50 STWHIP P WEXIT LOG TIE IN Printed 12/1/2014 12:49 56PM • North America-ALASKA-BP Page 7 of23 Operation Summary Report Common Well Name:E-05 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date: 11/11/2014 End Date: 11/19/2014 X3-015N3-C:(3,291,150.00) Project:Prudhoe Bay Site:PB E Pad Rig Name/No.:NORDIC 1 Spud Date/Time:2/9/1976 12:00:ODAM Rig Release:11/23/2014 Rig Contractor:NORDIC CALISTA UWI:500292019700 Active datum:E-05B©59.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ' (usft) 06:00 - 06:25 0.42 STWHIP P WEXIT CORRECT DEPTH-5',RIH TO TAG THE PINCH POINT DRY TAG AT 10100'ON DEPTH PU AND START THE MOTOR AND WORK DOWN TILL WE SEE MOTOR WORK 06:25 - 07:10 0.75 STWHIP P WEXIT START SEEING WOB&MOTOR WORK AT 10,099' Printed 12/1/2014 3:32:45PM North America-ALASKA BP Page a oto Operation Summary Report Common Well Name:E-05 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/11/2014 End Date:11/19/2014 X3-015N3-C:(3,291,150.00) Project:Prudhoe Bay Site:PB E Pad Rig Name/No.:NORDIC 1 Spud Date/Time:2/9/1976 12:00:00AM Rig Release:11/23/2014 Rig Contractor:NORDIC CALISTA UWI:500292019700 Active datum:E-05B©59.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:10 - 10:30 3.33 STWHIP N RREP WEXIT STOP MILLNG THE WINDOWAND PU OFF BOTTOM.TOOL PUSHER CALLED AND SAID THE LIQUID LEG OF THE MGS WILL NOT MAINTAIN THE HYDROSTATIC HEAD PRESSURE IT NEEDS TO WORK PROPERLY IN THE EVENT OF A WELL CONTROL INCIDENT.IT LOOKS LIKE THE BALL VALVE AT THE BOTTOM OF THE U-TUBE IS LEAKING AND NEEDS TO BE REPLACED.CALLED THE DRLG SUPT AND DISCUSSED WHAT NEEDS TO BE DONE AND HE IS ON HIS WAY TO OUR LOCATION.CALL OUT FOR A CLEAN EMPTY VAC TRUCK TO SUCK OUT THE PITS NEEDED TO ENTER THE PITS AND MAKE THE REPAIR. ALSO CALLED BP RADIO TO SECURE THE RESCUE TEAM FOR THE CONFINED SPACE ENTRY FILLED OUT THE BPXA CoW TASK-BASED RISK ASSESSMENT AND SENT IT TO THE WTL RICH BURNETT THEN GOT APPROVAL TO !PROCEED WITH THE REPAIR ONCE PIT 1 WAS SUCKED OUT WE COULD SEE WATER LEAKING FROM THE VALVE,THE DRILLER MOVED THE HANDLE EXTENSION A LITTLE AND THE LEAK STOPPED.CONTINUE MOVING AHEAD WITH GOING INSIDE THE PIT TO INSTALLA BULL PLUG WITH THREAD SEALER. PITS 1&2 ARE EMPTY,SHUT DOWN THE PUMP AND ALLOW RETURNS TO STOP.NO RETURNS FROM THE WELL,SHUT IN THE CHOKE AND DOUBLE BLOCK THE RETURN LINE.SNIFF TEST PITS,GOOD SNIFF TEST, FILL OUT CSE PERMIT,CHECK ISOLATION VALVES BETWEEN PIT 2&3,NO LEAKS, CONTINUOSLY MONITOR THE ATMOSPHERE WHILE WORK IS BEING PERFORMED.ALLOW MOTOR MAN TO ENTER PIT AND INSTALL BULL PLUG IN THE END OF THE VALVE. BULL PLUG IS INSTALLED,REMOVE MM AND TOOLS FROM PIT 1,FILL MGS AND CHECK FOR LEAKS,NO LEAKS,RELEASE RESCUE TEAM FROM NORDIC 1 AND FILL THE PITS CHECK THE WELL FOR PRESSURE,NO PRESSURE,OPEN THE 2 ISOLATION VALVES ON THE RETURN LINE THEN OPEN THE CHOKE NO FLOW FROM THE WELL,COME ONLINE WITH MUD DOWN THE COIL.WE HAVE 1:1 RETURNS DRLG SUPT SAYS WE ARE OK TO RETURN TO NORMAL OPERATIONS 10:30 - 11:00 0.50 STWHIP P WEXIT FILL PITS 1&2 AND RIH Printed 12/1/2014 3:32:45PM • North America-ALASKA-BP Page 9 t Operation Summary Report Common Well Name:E-05 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/11/2014 End Date:11/19/2014 X3-015N3-C:(3,291,150.00) Project:Prudhoe Bay Site:PB E Pad Rig Name/No.:NORDIC 1 Spud Date/Time:2/9/1976 12:00:00AM Rig Release:11/23/2014 Rig Contractor:NORDIC CALISTA UW:500292019700 Active datum:E-05B @59.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:00 - 12:20 1.33 STWHIP P WEXIT CONTINUE MILLING WINDOW FREE SPIN=2300 PSI AT 2.70 BPM RATE IN=2.68 BPM RATE OUT=2.69 BPM ROP=1 FPH WOB=1.26 K CIRC PSI= 2440 PSI MW IN=8.62 PPG MW OUT=8.64 PPG ECD =9.56 PPG IAP=820 PSI OAP=339 PSI OOA=309 PSI PVT=332 BBLS BOTTOMS UP ONCE WE STARTED MILLING THE WINDOWAGAIN IS CLEAN 12:20 - 13:10 0.83 STWHIP P WEXIT CONTINUE MILLING WINDOW FREE SPIN=2300 PSI AT 2.70 BPM RATE IN=2.68 BPM RATE OUT=2.69 BPM ROP=1 FPH WOB=2.13 K CIRC PSI= 2424 PSI MW IN=8.62 PPG MW OUT=8.62 PPG ECD =9.57 PPG IAP=916 PSI OAP=369 PSI OOA=355 PSI PVT=334 BBLS MUD IN THE PITS IS GETTING AIRED UP BLEED IA DOWN TO 300 PSI 13:10 - 13:40 0.50 STWHIP P WEXIT CONTINUE MILLING WINDOW FREE SPIN=2300 PSI AT 2.70 BPM RATE IN=2.68 BPM RATE OUT=2.69 BPM ROP=1 FPH WOB=3.47 K CIRC PSI= 2589 PSI MW IN=8.62 PPG MW OUT=8.61 PPG ECD =9.58 PPG IAP=374 PSI OAP=348 PSI OOA=411 PSI PVT=335 BBLS MANUAL STRAP SHOWS 333 BBLS(-2 BBLS) ADD SOME DEFOAMER TO THE PITS BLEED OOA FROM 455 PSI TO 200 PSI 13:40 - 13:50 0.17 STWHIP P WEXIT CONTINUE MILLING WINDOW FREE SPIN=2300 PSI AT 2.70 BPM RATE IN=2.68 BPM RATE OUT=2.68 BPM ROP=1 FPH WOB=4.61 K CIRC PSI= 2743 PSI MW IN=8.62 PPG MW OUT=8.60 PPG ECD =9.57 PPG IAP=402 PSI OAP=348 PSI OOA=214 PSI PVT=336 BBLS SLOW DOWN ROP,WE ARE AT MAX WOB 13:50 - 14:20 0.50 STWHIP P WEXIT WT DRILLED OFF,CONTINUE MILLING THE WINDOW 14:20 - 14:40 0.33 STWHIP P WEXIT DEFOAMER HAS NOT DECREASED THE PIT VOLUME AND WE ARE SHOWING-4 BBL GAIN SINCE WE STARTED MILLING.MUD TEMP HAS COME UP 10°SINCE WE STARTED LLAHE SE VMIOLUMINGE.PUND OFF BOTTOMSEEINGTANDINCREAFLOW IN i CHECK THE WELLAND CALL THE DRLG SUPT 14:40 - 14:50 0.17 STWHIP P WEXIT THERE IS A VERY FINE LINE OF MUD COMING OUT AT THE SHAKER WITH NO INCREASE IN PIT VOLUME SINCE WE SHUT DOWN.PUMP FRESH WATER ACROSS THE TOP TO FLUSH THE SURFACE LINES OF MUD Printed 12/1/2014 12:49:56PM 'TREE= " CNV Yv Ji EAD= MCLVOY r E 0 5 B SA NOTES:WELL ANGLE>70° 9905' -- ACTUATOR= BAKER C — ***4-1/2"CHROME TBG"'ORIG 8 E-05A WELL I(ITKB.ELEV= 56.56' NOT SHOWN BELOW WHIPSTOCK"' BF.B..EV= 28.3' KOP= 5500 20",94#,H-40, H 106' 1 _Max Angle= 95"CO 10383' CONDUCTOR Datum MD= 9670' F -- 1980' H9-5/8"FOC D=19.124" Datum TVD= $800'SS ' ' ' - 1998' —4-112"FES X NP,D=3.813" 11-3/4"x 9-5/8"THERMOCASE I — 160• /�X X 9-5/8"CSG,47#,N-80,BTC,D=8.681" H 2107' { GAS LFT MANDRELS 13-3/8"CSG,72#,N-80,BTG,D=12.347" --I 2845' ' ST MD ND DEV TYPE VLV LATCH FORT DATE 2 3486 3481 12 KBG2 DMY BK 0 04/25/14 Minimum ID =2.370" 10688• 1 6193 5782 34 KBG2 DMY BK 0 04/25/14 3-1/2" X 2-7/8" XO 9-5/8"WHFSTOCK(03/25/09) H 5500' MLLOUT WINDOW(E-058) 5508'-5525' 9-5/8"CSG,47#,N-80,HYD,0=8.681" -L —5508' I 7"LNR,26#,L-80 TCI XO TO L-80 BTC-M --I 6705' }—X X I I 9368' H4-1/2"FES X NP,D=3.813" Z g— 9399' H7"X 4-1/2"BKR S-3 PKR,D=3.870" ' , 9433' —14-1/2"H=S X NP,D=3.813" II I 9505' -14-1/2"HES XN NIP,MLLED TO 3.80'(08/03/14) 4-112"TBG, 12.6#,13CR-80 VAM TOP, —{ 9518' 9506' —7"X 5"HRD ZXP LTPw/TEBK SLV,D=4.460' .0152 bpf,D=3.958" 7'CSG,26#,L-80 BTC-M, .0383 bpf,ID=6.276" H 9670• 9518' —14-112"WIG,O=3.958' 9528' —7"X 5"BKR FLEXLOCK LNR HGR,ID=4.450" T SUMMARY —{5"X 4-1/2"XO,D=3.930" PERFORAREF LOG: h.ANGLE AT TOP PERF:81'@ 9982 10099' --(WHIPSTOCK(11/14/14) Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SCZ 10306' —I FISH:MILLED 4-1/2"FES CEP(08/03/14) 2-7/8" 6 9982-9992 0 06/29/12 2.88" 6 10330-10400 0 04/08/09 M C. 10306' —3-1/2"KB(UPPER)STRADDLE PES ID=2.560" 2.88" 6 10510-10640 0 04/08/09 — 2..88" 6 10870-10910 0 04/08/09 10688' —3-1/2"X 2-7/8"XO,ID=2.370" 2.88" 6 10970-11080 0 04/08/09710701' —3-1/2"KB(MIDDLE)STRADDLE FKR D=2.560" 2.88" 6 11130-11200 0 04/08/09 2.88" 6 11260-11350 0 04/08/09 11097' —3-1/7 X 2-7/8"XO w/SEAL ASSY EVBLY,ID=2.380" 11109' —3-1/2"KB(LOWER)STRADDLE PKR,D=2.440" 3-1/7 TBG,9.3#,L-80,STL,.0087 bpf,D=2.992" --I 11097' 11125' —2-7/8"WLEG,ID=2.625" PBTD --{ 11352' alb, 11335' —FISH-QBP,MILLED&PUSHED TO BTM(12/05/10) ••••••• 4-1/2"LNR, 12.6#,L-80 BT-M,.0152 bpf,D=3.958" — 11438' ••1•�•••� DATE REV BY COMu6'ffS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/26/76 ORIGINAL COMPLETION 01/31/14 ATO/JM)SET CEP(01/25/14) WELL: E 05B 01/10/89 RWO 05/01/14 DLW/JMGLV(70(04/25/14) PE MT No:'2090210 05/19/99 SIDETRACK(E-05A) 07/21/14 TR/JM) SCHEMATIC CORRECTIONS AR Nb: 50-029-20197-02 04/10/09 N7ES SIDETRACK(E-05B) 08/22/14 JDM'JM)XN ICBP WILLED(08/03/14) SEC 6,T11F' R14E, 1353'FNL&502'FEL 12/21/10 40RDIC 1 CTD PATCH(E-05B) 08/27/14 PJC LNR CORRECTION 01/31/14 ATO/JMJ SET Cl3P(01/25/14) BP Exploration(Alaska) • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~ - ~ ~~ Well History File Identifier Organizing (done) ^ Two-sided III II III II III II III ^ Rescan Needed III IIIII II II III III RES AN DIGITAL DATA OVERSIZED (Scannable) olor Items: C ^ Diskettes, No. ^ Maps: // p ~Greyscale Items:1 ~~`' '~ Other, No/Type: C~ ~o ~ ^ Other Items Scannable by a Large Scanner ^ Poor. Quality Originals: OVERSIZED (Non-Scannable). ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~ /s/ Project Proofing III IIIIIIIIIII IIIII BY: Maria Date: S /s/ Scannin Pre aration g P _~ x 30 = ~~ + ~_ =TOTAL PAGES__~ (Count does not include cover sheet) BY: Maria Date: ~J~ ~® /s/ Production Scanning I II I III II III II I III I Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES NO BY: Maria Date: ]~ ~~ / D /s/ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I (III IIIII IIIIIIIIIIIIIIIIIII ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III (IIIII III II'I II 10/6/2005 Well History File Cover Page.doc . STATE OF ALASKA RECEIVED ALAI OIL AND GAS CONSERVATION COM•ION AUG 0 8 2012 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LI Repair Well Li Plug Perforations U Perforate U Other L .\O `^ CC Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development IO Exploratory ❑ — 209 -021 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20197 -02 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028304 PBU E -05B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): - ' To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11440 feet Plugs measured 10069 feet true vertical 9067.52 feet Junk measured 11335 feet Effective Depth measured 10069 feet Packer measured See Attachment feet true vertical 9059.95 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 78 20" 94# H-40 28 - 106 28 - 106 1530 520 Surface 2817 13 -3/8" 72# L -80 27 - 2844 27 - 2843.86 4930 2670 Intermediate 5474 9 -5/8" 47# N -80 26 - 5500 26 - 5210.04 6870 4760 Production 9645 7" 26# L -80 25 - 9670 25 - 8859.21 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet NAKED AU Ci h 1 Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 24 - 9518 24 - 8711.36 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 421 39646 21 1733 Subsequent to operation: 427 33461 68 1329 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development la Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil - Q Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ sUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Prepared by Nita Summerhays 564 -4035 Printed Name Nita ummerh• s Title Petrotechnical Data Technician - Amur Signatur i / .�— Phone 564 -4035 Date 8/8/2012 •; Cl \ ti R8DMS AUG 0 9 2012 - i "f��"4 Submit Original onl ' `\ Form 10-404 Revised 10/2010 l / 'L y • • Perforation Attachment ADL0028304 Pert Opera Meas Meas SW Operation tion Depth Depth ND Depth ND Depth Name Date Code Top Base Top Base E -05B 6/29/12 APF 9982 9992 9046.91 9048.39 E -05B 6/29/12 BPS 10069 11350 9000.9 9005.85 E -05B 4/8/09 PER 10330 10400 9016.25 9010.51 E -05B 4/8/09 PER 10510 10640 9006.98 9002.09 E -05B 5/21/10 BPS 10750 11350 9001.28 9005.85 E -05B 12/5/10 BPP 10750 11350 9001.28 9005.85 E -05B 4/8/09 PER 10870 10910 9004.41 9006.34 E -05B 4/8/09 PER 10970 11080 9008.48 9005.03 E -05B 4/8/09 PER 11130 11200 9004.65 9005.52 E -05B 4/8/09 PER 11260 11350 9005.7 9005.85 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • Packers and SSV's Attachment ADL0028304 SW Name Type MD TVD Depscription E -05B PACKER 9399 8536.92 4 -1/2" Baker S -3 Perm Packer E -05B PACKER 9506 8640.68 5" HRD ZXP LTP E -05B PACKER 10306 9017.77 3 -1/2" KB UPPER STRADDLE PAC E -05B PACKER 10701 9001.22 3 -1/2" KB MIDDLE STRADDLE PA( E -05B PACKER 11109 9004.82 3 -1/2" KB LOWER STRADDLE PA( Y Casing / Tubing Attachment ADL0028304 Casing Length Size MD ND Burst Collapse CONDUCTOR 78 20" 94# H-40 28 - 106 28 - 106 1530 520 INTERMEDIATE 5474 9 -5/8" 47# N -80 26 - 5500 26 - 5210.04 6870 4760 LINER 1932 4 -1/2" 12.6# L -80 9506 - 11438 8699.73 - 9067.46 8430 7500 LINER 396 3 -1/2" 9.3# L -80 10701 - 11097 9060.27 - 9063.98 10160 10530 LINER 395 3 -1/2" 9.3# L -80 10306 - 10701 9076.82 - 9060.27 10160 10530 PRODUCTION 9645 7" 26# L -80 25 - 9670 25 - 8859.21 7240 5410 SURFACE 2817 13 -3/8" 72# L -80 27 - 2844 27 - 2843.86 4930 2670 • TUBING 9494 4 -1/2" 12.6# 13Cr80 24 - 9518 24 - 8711.36 8430 7500 • 1 ,, TREE = • CAN VVELLFEAD = ACEVOY • 4 8 NOTES: WELL. ANGLE> 70' 89905' ACTUATOR = BAKER C E-05B .4-1/2" CHROME TBO""ORIG & E WELL KB. ft.EV ; NOT SHOWN BELOW WHIPSTOCK' -107131i.T;;--- -' --ie':S.- - f<b - T:i;; ---- -- 51ififf [- U i I i Angie = 95 „ iii3 20', 94#, H-40, H 106' di pdo ... - ' 9 9, CONDUCTOR, r/l/...... 1980' 9-5/8" FOC Datum TVD = any ii ID = 19.124" I 1 1998' H4-1/2" HES X NP, ID = 3.813" I 111-3/4" x 9-5fir THERMOCASE 1 H 160' I 9-5/8" CSG, 471, N-80, BIC, 0 = 8.681" H 2107' 1- -......"."X ■ GAS LIFT MANDRELS 1 13-3/8" CSG, 721, N-80, BIC, ID = 12.347" H 2844' I-- Efil PA) D DEV TYPE MEM PORT &AA 1 Minimum ID = 2.370" fa 10688' Ir 1 11 634:3 348 Einitill . 0 0 1 1 10 ,071" 1 3-1/2" X 2-7/8" XO 1 9-5/8" WHIPSTOCK (03/25/09) 5600' 1 9-5/8" CSG, 470, N-80, HY D, ID = 8.681" H -5525 --1__IA , ML LOUT WIND OW (E-018) 5508' -5526' I r LNR 281-80 Tell X0 TO L-80 BTC-M 6706' 1 I I 9368' H41/2" HES X NP, ID= 3.813" 1 g ■ 9399' Hr X 41/2" BKR S-3 PKR, ID = 3.870" I • 1 9433' H41/2" HES X NP, ID= 3.813" I • 1 9506' H4-1/2" HES XN NIP, ID = 3.72S I 4-1/Z TEC, 12.6#, 13CR-80 VAM TOP, --1 9518' 9506' H7" X 5" HRD ZXP LTPw/T1B3K SLV, 10 = 4.480" 1 .0152 bpf, ID = 3.95T ; 17" CSG, 281, L-80 BTC-M, .0383 bpf, ID - 8.278" H 96700 9518' H4-1/2" WLEG, ID = 3.958" I 4 9528' H7" X 5" BKR FLEXLOCK LNR HGR, ID = 4.450" 1 PERFORATION SUMMARY Il 9538' HT X4-1/2" XO, ID = 3.930" I REF LOG: A NGLE AT TOP PERF: 81* 0 9987 111 .-(- ---- --vi.c--/ I i 9e(f. .j n I 4... , c" Note: Refer to Production DB for historical perf data r IL/ SIZE SFF INTERVAL Opn/ D Sqz ATE , ) (r _ - wow 4 WFD WRP (06/29/12) 2-7/8" 6 9982 - 9992 0 6/29/2012 --•..--- 1 2.88 6 10330 - 10400 C 04/06/09 2.88 6 10510 - 10640 C 04/06/09 .,:. I.:. 10306' H3-1/2" KB (UPPER) STRADDLE FICK ID = 2.560" I 2.88 6 10870 - 10910 C 04/08/09 2.88 6 10970 - 11080 C 04/08/09 0 10688' H3-1/2" X 2-7/8" XO, ID = 2.370" 1 2.88 6 11130 - 11200 C 04/08/09 10701' H3-1/2" KB (SADDLE) STRADDLE FKR, 10= 2.560" 1 2.88 6 11260 - 11350 C 04/08/09 - I 11097' H3-1/2" X2-7/8" X0 w /SEAL ASSY BVEILY , ID= 2.380" I 3-1/2" TBG, 9.3/C L-80, STI_ ID = 2.008 992" 11097' I 11109' 1-13-1/2 KB (LOWER) STRADDLE PKR ID = 2.440" I • 11125' H2-7/3" WLEG, ID = 2625" I I 11335' H FISH - CEP, MILLED & PUSHED TO BT1.1(12/)5/10) I PBTD 11352' .':•••• • • • 141/2" LNR, 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" H 11438' •••• DATE REV BY COMMENTS DATE REV BY CONVENTS PRUDHOE BAY UNIT 04/28/78 ORIGINAL COMPLETION 01/03/11 PJC DRLG HO CORRECTIONS VVELL: E-058 01110189 RINO 01/09/11 ET/PJC GLV C/0 (01/07/11) PERMIT No: '090210 05119/99 SIDETRACK (605A) 01/12/11 PJC DRLG DRAFT CORRECTIONS AR No: 50-029-20197-02 04/10/09 N7E8 SIDETRACK ( &NB) 01/12/11 GRIPJC FINAL DRLG CORRECTION SEC 6, Ti IN, R14E, 1353' FN_ & 502 FEL 11/11/10 OR/JPAD DRLG DRAFT CORRECTIONS 07/02/12 ' RM/JIVD ADPERF & SET WRP (06/29/12) 12121/10 NORDIC 1 CTD PATCH (E-0513) _ BP Exploration (Alaska) , . • STATE OF ALASKA ALASKfIL AND GAS CONSERVATION COMMI N REPO OF SUNDRY WELL OPERA ONS 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Set tubing patch for GSO 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory " 209 -021 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 • 50 - 029 - 20197 - 02 - 00 7. Property Designation: • 8. Well Name and Number: ADL 028304 • PBU E -05B 9. Field / Pool(s): Prudhoe Bay Field / Prudh Bay Oil Pool 10. Present well condition summary Total depth: measured 11440' feet Plugs (measured) None feet true vertical 9068' feet Junk (measured) 11335 Effective depth: measured 11352' feet Packer: (measured) 9399 feet true vertical 9065' feet Packer: (true vertical) 8596 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 106' 20" 106' 106' Surface 2844' 13 -3/8" 2844' 2844' 4930 2670 Intermediate 5508' 9-5/8" 5508' 5216' 6870 4760 Production Liner 9670' 7" Surface - 9670' Surface - 8859' 8160 7020 Liner 1932' 4 -1/2" 9506' - 11438' 8700' - 9067' 8430 7500 Perforation Depth: Measured Depth: 10330' - 11350' True Vertical Depth: 9075' - 9065' Tubing (size, grade, measured and true vertical depth): 4 - 1/2 ", 12.6# 13Cr - 9518' MD 8711' TVD 3 -1/2 ", 9.3# w/2 -7/8" tail L-80 11125' MD 9064' TVD 7" x 4-1/7' Baker S-3 le packer 9399' MD 8596' TVD Packers and SSSV (type, measured and true vertical depth): 45 "KB" Upper Straddle packer 10306' MD 9077' TVD 45 "KB" Middle Straddle packer 10701' MD 9060' TVD 45 "KB" Lower Straddle packer 11109' MD 9064' TVD 11. Stimulation or cement squeeze summary: ' Intervals treated (measured): - MAR Ci 20r, MAR 0 3 2011 Treatment description including volumes used and final pressure: Alaska Oil & Gas Cons. Commission Anchorage 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 200 Subsequent to operation: 705 45915 56 1000 1400 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory • ® Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations Well Schematic Diagram 15. Well Status after work: ❑ GINJ t Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. 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: Contact Eli Vazquez, 564-5918 N/A Printed Name Elizabeth Barker Title Drilling Technologist F � ' Prepared By Name/Number. Signature ' ,,, j ;, , � a t ... , Phone 564 -5674 Date 3�3�0 /ff Elizabeth Barker, 564 -5674 Form 10-404 Revised 10 /20R MAR O � �� 45171 / / 3'N' (( Submit Original Only f 1 u1W�7 — �14J • • E -05B Well History (Pre Rig Workover) Date ummar S y 11/21/2010 SET 4 -1/2" SS C -SUB @ 6300' SLM PULLED BK -OGLV FROM STA# 1 @ 6175' SLM / 6193' MD PULLED RK -LGLV FROM STA# 2 @ 3467' SLM / 3486' MD SET RK -DGLV IN STA# 2 @ 3467' SLM / 3486' MD 11/22/2010 Assist S /L- Load and MIT IA 3000 psi PASS Rigged up to IA and pumped 5 bbls neat meth, 147 bbls crude down IA to load for S /L- S/L set Dummy valve. MIT IA 3000 psi- Pumped 2.7 bbls crude down IA to reach test pressure, IA lost 100 psi in 15 min's, 20 psi in 2nd 15 min's for a total loss of 120 psi in 30 min's. Bled back -3.1 bbls. 11/22/2010 SET BK -DGLV IN STA #1 @ 6175' SLM / 6193' MD LRS MIT -IA TO 3000 psi, TEST PASSES PULL EMPTY S.S. C -SUB FROM 6300' SLM DRIFT W/ 2.25" CENTRALIZER, DEVIATE OUT @ 9941' 11/26/2010 PPPOT -T: External check installed. Stung into test port (1100 psi), bled to 0 psi (fluid /gas). Functioned LDS, all moved freely (2.5 "). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 11/29/2010 WO DSM to RU hardline. MIRU CTU, MU BOT MHA w/3.7 "milling assembly, 24.88' TOL. Tagged CIBP & started milling @ 10,689' CTM. Milled & pushed CIBP to PBTD /hard tag @ 11265' CTM. POOH w /milling assembly. 11/30/2010 Finish RIH w/ 3.71" drift assy to 11198' CTM. POH. FP wellbore to 2500'. RDMO to F -27 12/2/2010 RIH w/ 2.25" PDS logging assy to tag at 11315'. Log data showed PBD at 11319' ELMD. 12/2/2010 RIH w/ GR/CCL 2.2" gauge carrier & 2.25" jet nozzle 12/3/2010 MU 3.70" milling assy. Can't raise T -bar. Find problem with trolley winch. LD BHA. FP wellbore to 2000' RDMO to SWS shop for winch replacement 12/4/2010 Finish repair of trolley winch sheave system in SWS shop. WOW (wind). Move unit back to E Pad. MIRU. MU 3.70" junk mill assy 12/6/2010 POH w/ 3.71" drift assy, clean. FP wellbore to 2000' w/ diesel. RDMO to MPF -96 12/6/2010 WHPs IA & OA FL (pre -rig). No AL. IA FL near surface. OA FL @ surface. 12/7/2010 Pressure tested down on swab to 300 psi low and 3500 psi high to verify barriers. (passed) Rigged up lubricator and tested to 300 psi low and 3500 psi high.(passed) Set 4" CIW H TWC @ 114" w/ 1 -1' ext. Reinstalled tree cap and tested to 500 psi (passed).Torque all tree flanges to API specifications. Performed charted tests on swab valve at 300 psi and 3500 psi and tree shell test against TWC to 300 psi and 5000 psi (passed); Pulled 4" CIW H TWC; Pre Nordic 1 Page 1 of 1 TREE = CW WELLHEAD = MCEVOY • E 0 5 B SAFETY : WELL ANGLE> 70° @ 9905' ACTUATOR= BAKER * * *4 -1/2" OMETBG* * *ORIG &E- 05AWELL KB. ELEV = 56.56' NOT SHOWN BELOW WHIPSTOCK * ** BF. ELEV = 28.3' 1 KOP = 5500' 20 ", 94 #, H-40, - 106' I--- Max Angle = 95° @ 10383' CONDUCTOR, Datum MD = 9670' "' 1980' I--I -5/8" FOCI Datum TV D = 8800' SS 0 = 19.124" I 1998' 1-14-1 /2" HES X NIP, ID = 3.813" I 111-3/4" x 9 -5/8" THERMOCASE II H 160' X 1 9 -5/8" CSG, 47 #, N -80, BTC, ID = 8.681" H 2107' 1.........„....„›< ■ GAS LIFT MANDRELS 13 -3/8" CSG, 72 #, N -80, BTC, ID = 12.347" I-1 2844' ST MD ND DEV TYPE VLV LATCH PORT DATE Minimum ID = 2.370" @ 10688' ILI 2 3486 3481 12 KBG2 DOME BK 16 01/07/11 1 6193 5782 34 KBG2 SO BK 20 01/07/11 3-1/2" X 2 -7/8" XO 19 -5/8" WHIPSTOCK (03/25/09) I 5500' 9 -5/8" CSG, 47 #, N -80, HYD, ID = 8.681" H -5525 MILLOUT WINDOW (E -05B) 5508' 5525' ■ 7" LNR, 26 #, L-80 TCII XO TO L -80 BTC-M H 6705' i 9368' I- -I4 -1/2" HES X NIP, ID = 3.813" I e C 9399' I--17" X 4 -1/2" BKR S -3 PKR, ID = 3.870" I 9433' H 4 - 1/2" HES X NIP, ID = 3.813" I 9505' H4-1/2" HES XN NIP, ID = 3.725" I 4 -1/2" TBG, 12.6 #, 13CR 80 VAM TOP, 9518' .0152 bpf, ID = 3.958" 1 9506' H7" X 5" HRD ZXP LTP w /TIEBK SLV, ID = 4.460" I 7" CSG, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" 9670' 9518' I- 14 -1/2" WLEG, ID = 3.958" I H 9528' H 7" X 5" BKR FLEXLOCK LNR HGR, ID = 4.450" I PERFORATION SUMMARY 9538' H 5" X 4 -1/2" XO, ID = 3.930" I REF LOG: ■ ���� _ p ANGLE AT TOP PERF: 94° @ 10330' � 1 / / �� _ Note: Refer to Production DB for historical perf data (. ")56 5 SIZE SPF INTERVAL Opn /Sqz DATE 2.88 6 10330 - 10400 C 04/08/09 2.88 6 10510 - 10640 C 04/08/09 2.88 6 10870 - 10910 C 04/08/09 � 10306' J- I3 -1/2" KB (UPPER) STRADDLE PKR, ID = 2.560" I il 2.88 6 10970 - 11080 C 04/08/09 1 10688' JJ 3 -1/2" X 2 -7/8" XO, ID = 2.370" 2.88 6 11130 - 11200 0 04/08/09 , 1 (I I 2.88 6 11260 - 11350 0 04/08/09 10701' H 3-1/2" KB (MIDDLE) STRADDLE PKR, ID = 2.560" I .1. u I 1 11097' H 3 -1/2" X 2 -7/8" XO w /SEAL ASSYEMBLY, ID = 2.380" I I3 -1/2" TBG, 9.3 #, L -80, STL, .0087 bpf, ID = 2.992" H 11097' 1 11109' H 3 -1/2" KB (LOWER) STRADDLE PKR, ID = 2.440" I ✓ 11125' H 2 -7/8" WLEG, ID = 2.625" I PBTD H 11352' I Alb. I 11335' H FISH - CIBP, MILLED & PUSHED TO BTM (12/05/10) I •••• I4 -1/2" LNR, 12.6 #, L -80 IBT -M, .0152 bpf, ID = 3.958" H 11438' .•�•�•�■ • DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/26/76 ORIGINAL COMPLETION 01/03/11 PJC DRLG HO CORRECTIONS WELL: E -05B 01/10/89 RWO 01/09/11 ET /PJC GLV C/O (01/07/11) PERMIT No: F 2090210 05/19/99 SIDETRACK (E -05A) 01/12/11 PJC DRLG DRAFT CORRECTIONS API No: 50- 029 - 20197 -02 04/10/09 N7E5 SIDETRACK (E -05B) 01/12/11 GR/PJC FINAL DRLG CORRECTION SEC 6, T11 N, R14E, 1353' FNL & 502' FEL 11/11/10 GR/JMD DRLG DRAFT CORRECTIONS 1 12/21/10 NORDIC 1 CTD PATCH (E -05B) BP Exploration (Alaska) • . th America- ALASKA - BP , Q•a Lion Summary Report � , - ' � �.. tom Common Well Name: E -05 AFE No Event Type: WORKOVER (WO) Start Date: 12/5/2010 End Date: APBEPDWL05 -N (740,427.00 ) Project: Prudhoe Bay Site: PB E Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 2/9/1976 12:00:OOAM Rig Release: 12/21/2010 Rig Contractor: NORDIC CALISTA UWI: 500292019700 Active Datum: E -05 @56.60ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/7/2010 12:00 - 00:00 12.00 MOB C PRE 12/8/2010 00:00 - 12:00 12.00 MOB C PRE CHANGE OUT FLANGE VALVE ON CHOKE. USE HOT WATER TO CLEAN OUT TIGER TANK 12:00 - 00:00 12.00 MOB C PRE MOVE TIGER TANK CLOSER TO RIG, USE STEAM TO MELT ICE BULB. TRAIN ON WELL CONTROL SCENARIOS. SWAP FARR TONGS HANGING LINE TO DRILLERS SIDE. 12/9/2010 00:00 - 12:00 12.00 MOB C . PRE RIG MAINTENANCE IN PREPARATION FOR MOVING ONTO E -05B 12:00 - 00:00 12.00 MOB C PRE SCRUB RIG. PAINT WORK BASKET. START ■ CRITICAL ITEMS INSPECTION. MEASURE HIGH PRESSURE PIPING. 12/10/2010 00:00 - 12:00 12.00 MOB C PRE PREPARE RIG FOR MOVEMENT TO STAGING AREA. WARM UP MOVING SYSTEM. PJSM ON MOVING RIG. MOVE RIG TO STAGING AREA ON E -PAD 12:00 - 00:00 12.00 MOB C PRE RUN OVERHEAD LINE ON GENERATOR #1. MU HARDLINE TO REEL. INSPECT CHAINS ON'DRAWWORK TRANSMISSION. ASSEMBLE JIB HOIST AT CAMP SHOP. 12/11/2010 00:00 - 12:00 12.00 MOB C PRE GRIND AND PAINT EQUIPMENT, CLEAN RIG. 12:00 - 00:00 12.00 MOB C PRE WELD SUCTION LINE ON NUMBER 1 MIXER, CRITICAL ITEMS INSPECTION, CLEAN AND PAINT EQUIPMENT 12/12/2010 00:00 - 12:00 12.00 MOB C PRE CONDUCT RIG MAINTENANCE: GRINDING, PAINTING, PLUM AIRLINE IN CAMP MOTOR ROOM, CONTINUE WITH CRITICAL ITEMS INSPECTION LIST 12:00 - 00:00 12.00 MOB P__ PRE COMPLETE WELDING SUCTION LINE ON MIXER. PREP FOR RIG MOVE. SITE PREPARATION ON E -05B. 12/13/2010 00:00 - 06:00 6.00 MOB P PRE PREP RIG FOR RIG MOVE. WARM UP MOVING SYSTEM. ASSEMBLE VALVES ON CHOKE MANIFOLD. COMPLETE PREP OVER E -05B. STAGE HEATER TO BEGIN WARMING TREE, TUBING HANGER FOR INSTALLING TWC. 06:00 - 15:30 9.50 MOB P PRE RIG ON STANDBY WHILE WAITING ON WELLS ■- GROUP INSTALL TWC. CONDUCT PRE-RIG MOVE MOVE INSPEECTI TION. 15:30 - 16:00 0.50 MOB P PRE CONDUCT PRE -SPUD MEETING WITH FIELD ■- SUPERINTENDENT. CONDUCT PJSM ON RIG MOVE. 16:00 - 18:00 2.00 MOB P -_ PRE MOVE RIG FROM STAGING AREA TO E -05B. MOVE OVER WELL. RIG ACCEPT 1800 HRS. -- 18:00 - 21:30 3.50 RIGU P PRE STAGE CUTTINGS BOX, CONNECT LINES TO CUTTINGS BOX AND BLEED TRAILER, INSTALL GAUGES TO TREE, PREPARE CELLAR FOR NU BOP. CLEAR FROZEN STEAM LINE IN CELLAR HEATER. CHANGE OUT PLUG IN SSV WITH BURST DISK. Printed 3/2/2011 5:06:10PM a • f)rth America g ,of rEre `` `ice 4 4 -e o .. .�. �`�� �3�� _:a* -.�.. as,__ _ � �.... ,;� .�..�.�.�€zC��:' �_ ..�.. �� � Y �.. .� ill.. .� Common Well Name: E -05 AFE No Event Type: WORKOVER (WO) Start Date: 12/5/2010 End Date: APBEPDWL05 -N (740,427.00 ) Project: Prudhoe Bay Site: PB E Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 2/9/1976 12:00:OOAM Rig Release: 12/21/2010 Rig Contractor: NORDIC CALISTA UWI: 500292019700 Active Datum: E -05 @56.60ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:30 - 22:15 0.75 RIGU P PRE CONDUCT PRE -SPUD MEETING WITH NIGHT CREW, TOURPUSHER, WSL. DISCUSS OPERATIONS, GOR RISK MITIGATION, BOP CONFIGURATION FOR THIS WELL. PJSM ON NU OF BOP AND CHANGING OUT RAMS. 22:15 - 00:00 1.75 RIGU P PRE STAGE BOP EQUIPMENT FOR NU. NU ADAPTER EXTENSION. 12/14/2010 00:00 - 04:30 4.50 RIGU P PRE COMPLETE NU OF ADAPTER EXTENSION. LINE BOP UP FOR NU. NU BOP. CHANGE OUT 2 3/8" FIXED COMBI RAMS FOR 2 3/8" BY 3 1/2" VARIABLE RAMS. 04:30 - 05:00 0.50 RIGU P PRE INSTALL DRAIN BOX AROUND LUBRICATOR. NU INJECTOR LUBRICATOR. CLEAR AND CLEAN RIG FLOOR FOR BOP TEST. CONDUCT AAR OF BOP NU. 05:00 - 06:00 1.00 BOPSUR P PRE FUNCTION TEST RAMS BEFORE BEGINNING TEST. CONDUCT BOP TEST WITH 2" AND 3 1/2" TEST JOINTS TO 250 PSI LOW AND 3500 80 PSI HIGH. AOGCC REP BOB NOBLE WAIVED VV WITNESS OF TEST. TEST WITNESSED BY � TOOLPUSHER ROB ROBINSON AND JAY (/j MURPHY, WSL ROB O'NEAL AND RICH BURNETT. 06:00 - 13:00 7.00 BOPSUR P PRE CONTINUE TEST OF BOPE. TEST COMPLETED WITH NO FAILURES. CHECK SAFETY CRITICAL EQUIPMENT INCLUDING PVT ALARMS, GAS ALARMS AND MICRO- MOTION SENSORS. ALL PASSED AND FUNCTIONAL 13:00 - 14:00 1.00 RIGU P PRE CLEAR FLOOR AND PREP TO PUMP REVERSE ELINE SLACK INTO COIL. 14:00 - 15:20 1.33 RIGU P PRE PUMP SLACK INTO COIL. RIG UP AND CUT 220' OF COIL TO FIND ELINE 15:20 - 16:15 0.92 RIGU P PRE INSTALL BTT COIL CONNECTOR. PULL TEST AND PT SAME. 16:15 - 17:00 0.75 RIGU P PRE PJSM, INSTALL INTEQ UQC AND PRESSURE TEST TO 3500PSI. 17:00 - 18:00 1.00 RIGU P PRE PJSM, P/U LUBRICATOR. 18:00 - 20:15 2.25 BOPSUB P PRE PRESSURE TEST TREE AGAINST MASTER VALVE AND TWC TO 250 PSI AND 3500 PSI. 20:15 - 22:00 1.75 BOPSUB P PRE P/U INJECTOR, REMOVE UQC CHECKS, PRESSURE TEST INNER REEL VALVE TO 250 PSI AND 3500 PSI. INSTALL UQC CHECKS. 22:00 - 00:00 2.00 DHB P DECOMP PJSM, R/U AND PRESSURE TEST LUBRICATOR TO 250 PSI AND 3500 PSI. PULL TWC. 12/15/2010 00:00 - 00:30 0.50 DHB P DECOMP PULL TWC, WELL ON VACUUM. CLOSE MASTER VALVE. RID LUBRICATOR AND OFF LOAD. 00:30 - 03:00 2.50 KILLW P DECOMP PJSM, BULLHEAD AND KILL WELL WITH 8.4 PPG KCL AT 5 BPM, 3000 PSI. PUMP 1 1/2 TIMES WELL BORE VOLUME. SPOT 22 BBLS 130 LSRV PILL AT PERFS AT 10,330' NO RAMP UP, WELL ON VACUUM. PVT 314 BBLS 03:00 - 03:30 0.50 EVAL P DECOMP FLOW CHECK WELL FOR 30 MINUTES. WELL DRINKING 11 BPH. Printed 3/2/2011 5:06:10PM rth America 'Operation Summa Common Well Name: E -05 AFE No Event Type: WORKOVER (WO) Start Date: 12/5/2010 End Date: APBEPDWL05 -N (740,427.00 ) Project: Prudhoe Bay Site: PB E Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 2/9/1976 12:00:OOAM Rig Release: 12/21/2010 Rig Contractor: NORDIC CALISTA UWI: 500292019700 Active Datum: E -05 @56.60ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 04:00 0.50 EVAL P ■- DECOMP DISCUSS WITH TOWN TO TO PPG PG N-VIS 40K+ LSRV MUD AFTER LOGGING RUN. 04:00 - 04:30 0.50 EVAL P DECOMP PJSM, P/U GR,CCL LOGGING BHA. 04:30 - 07:00 2.50 EVAL P DECOMP RIH TO 10063' 07:00 - 12:00 5.00 EVAL P DECOMP GR LOG UP FROM 10050' TO 9800' AT 100 FPH. FINAL GR SPIKE AT 9854', - 5' CORRECTION, RIH TO 11354'. LOG CCL UP FROM 11310 TO 10960' AND FROM 10460' TO 11160' AT 1000 FPH. 12:00 - 14:30 2.50 EVAL P DECOMP POH WITH LOGGING BHA. 14:30 - 15:00 0.50 EVAL P DECOMP PJSM, L/D BHI BHA. 15:00 - 16:00 1.00 EVAL P DECOMP INSTALL NEW BAKER CTC, PULL TEST TO 20 KAND PRESSURE TEST. 16:00 - 21:00 5.00 EVAL N HMAN DECOMP LOST O -RING FROM LUBRICATOR DOWN HOLE, CLOSE MASTER VALVE. M/U NOZZLE AND JET STACK ATTEMPTING TO WASH 0 -RING TO SURFACE. 21:00 - 00:00 3.00 EVAL P DECOMP R/U AND PUMP OUT E -LINE SLACK, CUT 187' E -LINE. INSTALL NOZZLE, STAB INJECTOR ONTO WELL. LOAD AND PUMP 3/4" BALL. 12/16/2010 00:00 - 01:00 1.00 EVAL N HMAN DECOMP P/U 3.13" VENTURI BASKET, BOWEN OIL JAR BHA. 01:00 - 03:30 2.50 EVAL N HMAN 11,150.00 DECOMP RIH TO 11,150', 03:30 - 04:00 0.50 EVAL N HMAN 11,150.00 DECOMP PUMP 30 BBL HIGH VIS SWEEP, FISHING FOR 0 -RING. 04:00 - 07:30 3.50 EVAL N HMAN 9,700.00 DECOMP POH WITH VENTURI BASKET BHA. REPAINT FLAG AT 9700' YELLOW AND 9400' WHITE. 07:30 - 08:00 0.50 EVAL N HMAN DECOMP LD AND INSPECT FISHING BHA. ENTIRE 0 -RING FISH RECOVERED. ALSO RECOVERED — 1/2 GALLON OF COARSE CEMENT CHIPS 08:00 - 08:15 0.25 EVAL P DECOMP PJSM WITH DRILLER, BTT SUPERVISOR AND RIG CREW 08:15 12:45 4.50 RUNCOM P ■- RUNCMP C RUNNING 3" FOR PATCH. CONDUCT KICK WHILE RUNNING ING LINER DRILL(WITH NON - SHEARABLE BHA'S) 12:45 - 17:30 4.75 RUNCOM P RUNCMP RIH WITH PATCH ASSEMBLY WHILE PUMPING .3 BPM SET DOWN AT 9405' CTMD. ESTABLISH PUW OF 28K AND RIH SLOWLY ABLE TO RIH WITH 5K ADDITIONAL DOWN WEIGHT. SET DOWN AT 9919' CTMD WITH SWELL PACKER AT XN NIPPLE. PICKUP WEIGHT = 28K 17:30 - 21:30 4.00 RUNCOM N DPRB 9,919.00 RUNCMP WAIT ON DRUM OF CFS520 LUBRICANT TO BUILD 100 BBL PILL. 21:30 - 00:00 2.50 RUNCOM N DPRB 9,919.00 RUNCMP PUMP 100 BBL .6 % CFS520 LUBRICANT PILL DOWN COIL, KEEPING CIRCULATING PRESSURE BELOW 500PSI. .64 BPM, 450 PSI. DEPTH AT 9919' Printed 3/2/2011 5:06:10PM Orfi Arrte i`ICc7 A #' S 3 .,I - � ° °� 1. Common Well Name: E -05 AFE No Event Type: WORKOVER (WO) Start Date: 12/5/2010 End Date: APBEPDWL05 -N (740,427.00 ) Project: Prudhoe Bay Site: PB E Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 2/9/1976 12:00:OOAM Rig Release: 12/21/2010 Rig Contractor: NORDIC CALISTA UWI: 500292019700 Active Datum: E -05 @56.60ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/17/2010 00:00 - 00:30 0.50 RUNCOM N DPRB 9,919.00 RUNCMP ATTEMPTING TO GET SWELL PKR PAST XN, NIPPI F AT 9505' SET 10 K DOWN 5 TIMES WITH NO SUCCESS. P/U 28K, S/O 20K 00:30 - 04:00 3.50 RUNCOM N DPRB 9,919.00 RUNCMP " POH WITH TBG PATCH BHA. 04:00 - 04:30 0.50 RUNCOM N DPRB RUNCMP ` PJSM, STAND BACK INJECTOR. M/U SAFETY JT. PVT 255 BBLS. R/U AND UD 3 1/2" TBG PATCH BHA. 04:30 - 08:00 3.50 RUNCOM N DPRB RUNCMP NO TUBING PATCH RECOVERED. DISCUSS WITH TOWN TEAM. CALL FOR FISHING BHA. 08:00 - 09:30 1.50 RUNCOM N DPRB RUNCMP INSTALL NEW COILED TUBING CONNECTOR AND MU FISHING BHA INCLUDING ACCELERATOR, WEIGHT BARS, JARS AND GS SPEAR. 09:30 - 11:00 1.50 RUNCOM N DPRB RUNCMP RIH TO FISH PATCH 11:00 - 11:15 0.25 RUNCOM N DPRB 8,800.00 RUNCMP WEIGHT CHECK AT 8800' = 30K UP AND 16K DOWN. 11:15 - 11:30 0.25 RUNCOM N DPRB 9,101.00 RUNCMP TAG FISH, PU AND OVERPULL TO 50K, WORK FISH THROUGH JEWELRY 11:30 - 15:45 4.25 RUNCOM N DPRB 9,101.00 RUNCMP POOH SLOWLY WITH 10K ADDITIONAL WEIGHT. CHECK PVT AND PITS OFTEN FOR SIGNS OF POTENTIAL SWABBING. 15:45 - 19:00 3.25 RUNCOM N DPRB RUNCMP OOH. BEGIN LAYING DOWN FISHING BHA AND TUBING PATCH. SWELL PACKER HAD NORMAL WEAR ON BOTTOM SIDE FROM RUNNING IN THE HOLE, BUT ON THE TOP SIDE A COUPLE INCHES FROM BOTTOM IT HAD A COUPLE SMALL BLISTERS. 19:00 - 19:30 0.50 RUNCOM N DPRB RUNCMP CREW CHANGE AND PJSM TO CONTINUE LAYING DOWN TUBING PATCH. 19:30 - 20:00 0.50 RUNCOM N DPRB RUNCMP 1 TUBING PATCH. LOWER KB PACKER LEFT__ IN HOLE. 20:00 - 21:00 1.00 RUNCOM N DPRB RUNCMP WAIT ON GS SPEAR AND DISCUSS PLAN FORWARD WITH TOWN. 21:00 - 22:15 1.25 RUNCOM N DPRB RUNCMP PJSM, PICKUP FISHING BHA, 4" GS SPEAR, DISCONNECT, BOWEN JARS, 4 WT BARS, BOWEN ACCELERATOR, DUAL BPV, XO, 3 JTS 2 3/8" PH6, XO, BOT LOCABLE SWIVEL, XO, BOT CTC. M/U INJECTOR. 22:15 - 00:00 1.75 RUNCOM N DPRB 2,000.00 RUNCMP RIH WITH FISHING BHA # 5. 12/18/2010 00:00 - 01:00 1.00 FISH N DPRB 8,950.00 RUNCMP AT 8950', UP WT 30K, DOWN WT 30K. WHITE FLAG AT 9410' AND YELLOW FLAG AT 9710' ARE BOTH 10' DEEPER. 01:00 - 02:00 1.00 FISH N DPRB 9,856.00 RUNCMP TAG AT 9856' WITH 6K BOBBLE, MAY HAVE KB PACKER. FISH IS ONLY 400LB. 02:00 - 04:45 2.75 FISH N DPRB RUNCMP POOH AT 70FPM, PUMPING .95 BPM DOWN BACK SIDE. HOLDING 500 PSI WELL HEAD PRESSURE TO PREVENT SWABBING. 04:45 - 06:00 1.25 FISH N DPRB RUNCMP STANDBACK INJECTOR AND LD FISHING BHA AND KB PACKER FISH. 06:00 - 13:45 7.75 FISH N DPRB RUNCMP DISCUSS PLAN FORWARD AND WAIT ON TOOLS FROM BAKER TT 13:45 - 14:00 0.25 FISH N DPRB RUNCMP TOOLS AND DRIFT ON LOCATION. CONFIRM OD'S AND LENGTHS. PREP TO PICK UP BHA Printed 3/2/2011 5:06:10PM • rt NIt a ALASK, E3. z E e 5 o t ' 3. :. Common Well Name: E -05 AFE No Event Type: WORKOVER (WO) Start Date: 12/5/2010 End Date: APBEPDWL05 -N (740,427.00 ) Project: Prudhoe Bay Site: PB E Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 2/9/1976 12:00:OOAM Rig Release: 12/21/2010 Rig Contractor: NORDIC CALISTA UWI: 500292019700 Active Datum_ : E -05 @56.60ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 14:45 0.75 FISH N DPRB RUNCMP MU DRIFT AND LOG ASSEMBLY WITH 3.70" DRIFT AND SLB MEMORY GR/CCL LOGGING TOOLS 14:45 - 18:30 3.75 FISH N DPRB 9,942.00 RUNCMP RIH WITH DRIFT /LOGGING BHA. SET DOWN_ AT 9942'. PUH AND ABLE TO RUN PAST. ERRATIC SET DOWN WEIGHTS AS COIL WAS RUN PAST 9942'. CONTINUE RUNNING IN HOLE. 18:30 - 19:00 0.50 FISH N DPRB 10,643.00 RUNCMP ON BOTTOM LOG UP AT 45 FPM. PAINT YELLOW FLAG AT 10,643', MECHANICAL COUNTER SHOWS 10,537'. CONTINUE LOG UP TO 9,900' AT 45 FPM. 19:00 - 19:45 0.75 FISH N DPRB 9,900.00 RUNCMP STOP AT 9900' AND RETURN TO BOTTOM. 19:45 - 20:15 0.50 FISH N DPRB 11,171.00 RUNCMP AT 11,171' LAUNCH 1/2" ALUMINUM BALL. BALL ON SEAT AT 20:15 WITH 31 BBLS AWAY. SHEARED AT 2600PSI. 20:15 - 21:00 0.75 FISH "N DPRB 11,171.00 RUNCMP ` PUMP HIGH VIS PILL. 21:00 - 00:00 3.00 FISH N DPRB 8,630.00 RUNCMP POOH AT 75 FPM. PUMPING 1.92 BPM THRU CIRC SUB. AT 8630' UP WT 30K, DOWN WT 21K, PVT 243 BBL. 12/19/2010 00:00 - 00:30 0.50 CLEAN N DPRB RUNCMP POH WITH 3.70 DRIFT AND SLB MEMORY CCL/GR BHA. PVT 209BBLS. 00:30 - 01:45 1.25 CLEAN N DPRB RUNCMP PJSM, UD LOG TOOLS AND DRIFT. RECOVERED 1/2" ALUM BALL. 01:45 - 03:10 1.42 RUNCOM N DPRB RUNCMP PJSM. P/U LOWER PACKER BHA. WLEG, 45 KB PKR, DEPLOYMENT SLEEVE, CTLRT, HYD DISC, DUAL BPV, XO, 3 JTS 2 3/8" PH6, XO, XO, CTC. M/U INJECTOR. ESTABLISH CIRC. 03:10 - 04:30 1.33 RUNCOM N DPRB, RUNCMP RIH WITH LOWER PKR RUN. 70 FPM PUMPING .37 BPM. SLOWED TO 30 FPM THROUGH GLM 'S AND NIPPLES. 04:30 - 06:15 1.75 RUNCOM N DPRB 10,042.00 RUNCMP AT 05:54 SET DOWN TWICE AT 10,042'. AT PAINTED FLAG APPLIED -10' CORRECTION PER SLB LOGGERS. 06:15 - 09:45 3.50 RUNCOM N DPRB 11,110.00 RUNCMP ON DEPTH WITH KB PACKER ELEMENT AT 11.110'. DROP 5/8" ALUMINUM BALL. PUMPING .6 BPM AT 275 PSI. DID NOT SEE BALL LAND AT EXPECTED COIL VOLUME. MOVE COIL, SHUT PUMPS OFF AND RAMP UP. PUMP ADDITIONAL COIL VOLUME AT SLIGHTLY HIGHER RATE. PUMP 10 BBL HIGH VIS PILL. SHUT PUMPS OFF AND RAMP UP AND SAW BALL LAND SHEARED AND SET PACKER AT — 3200PS1. 09:45 - 12:15 2.50 RUNCOM N DPRB 11,110.00 RUNCMP POOH WITH SETTING TOOL 12:15 - 12:30 0.25 RUNCOM N DPRB 11,110.00 RUNCMP OOH. PJSM WITH ONCOMING BAKER SUPERVISOR AND RIG CREW. 12:30 - 13:45 1.25 RUNCOM N DPRB 11,110.00 RUNCMP LD LINER SETTING TOOL. BALL RECOVERED. 13:45 - 16:00 2.25 RUNCOM N DPRB 11,110.00 RUNCMP SEND CTLRT TO BAKER SHOP FOR RE- DRESS. 16:00 - 18:20 2.33 RUNCOM N DPRB 11,110.00 RUNCMP MU MIDDLE KB PACKER OF STRADDLE ASSEMBLY. Printed 3/2/2011 5:06:10PM • C? ltkt A G s 1 a* of 7 tt-ttitt ` " ' A B n a 't ` += Common Well Name: E -05 AFE No Event Type: WORKOVER (WO) Start Date: 12/5/2010 End Date: APBEPDWL05 -N (740,427.00 ) Project: Prudhoe Bay Site: PB E Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 2/9/1976 12:00:OOAM Rig Release: 12/21/2010 Rig Contractor: NORDIC CALISTA UWI: 500292019700 Active Datum: E -05 ©56.60ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:20 - 21:00 2.67 RUNCOM N DPRB 11,110.00 RUNCMP RIH WITH MIDDLE PACKER ASSEMBLY. 21:00 - 21:10 0.17 RUNCOM N DPRB 11,110.00 RUNCMP 11,000' UP WT 36K, DW WT 20K, PUMPING .36BPM AT 150 PSI. PVT = 241 BBLS. 21:10 - 22:10 1.00 RUNCOM N DPRB 11,110.00 RUNCMP AT DEPTH 11,118' CIRC PRESSURE WENT UP. WT DROPPED. SET DOWN 10K. PICKUP TO BREAK OVER WT PLUS 2' (11,111'), LAUNCH 5/8 "ALUMINUM BALL. BALL ON SEAT AT 28.4 BBLS AWAY. STACK 1 OK DOWN (11,122') PICK UP TO BREAK OVER WT PLUS 2' (11,111'). PRESSURE UP TO 1,700 PSI TO SET SLIPS. PICK UP AND STACK 1OK DOWN 2' (11,120'). PRESSURE UP TO 3,800 PSI TO SHEAR BALL SEAT. 22:10 - 00:00 1.83 RUNCOM N DPRB 11,110.00 RUNCMP PU'FREE WITH NO OVER PULL. POOH 12/20/2010 00:00 - 00:15 0.25 RUNCOM N DPRB RUNCMP CONTINUE TO POOH WITH MIDDLE KB PACKER TUBING PATCH RUNNING TOOLS. 00:15 - 00:45 0.50 RUNCOM N DPRB RUNCMP PJSM AND POP OFF WELL AND INSPECT COIL TUBING. 00:45 - 01:30 0.75 RUNCOM N DPRB RUNCMP LD PACKER RUNNING TOOLS AND LOAD OUT BAKER. 01:30 - 03:30 2.00 RUNCOM N DPRB RUNCMP WAIT ON BAKER TO REDRESS TOOLS AND BRING BACK TO RIG. PJSM TO INSPECT CHAINS AND CARRIERS. INSPECT CARRIERS AND CHANGE OUT 4. 03:30 - 04:15 0.75 RUNCOM N DPRB RUNCMP BAKER ON LOCATION. PJSM AND BRING THIER TOOLS TO FLOOR. SLB FINISHING UP INJECTOR MAINTANCE. 04:15 - 04:45 0.50 RUNCOM N DPRB RUNCMP PJSM TO MU TOP KB PACKER TUBING PATCH AND RUNNING TOOLS. 04:45 - 07:15 2.50 RUNCOM N DPRB RUNCMP MU TOP KB PACKER TUBING PATCH. 7.4' SEAL ASS., 12 JTS 3 -1/2" TUBING23' PUP JT, 45 KB PACKER, 4" GH RUNNING TOOL, HI LOAD DISCONNECT, 3 JTS 2 -3/8" PI-16, BAKER LOCKABLE SWIVEL AND BOT CTC. 07:15 - 10:30 3.25 RUNCOM N DPRB RUNCMP RIH WITH TOP KB PACKER AND TUBING STRADDLE ASSEMBLY Printed 3/2/2011 5:06:10PM �v merl a L SKA BR P i k ''' P e 7 ©pkation Summary Report .::;m4f E � Common Well Name: E -05 AFE No Event Type: WORKOVER (WO) Start Date: 12/5/2010 End Date: APBEPDWL05 -N (740,427.00 ) Project: Prudhoe Bay Site: PB E Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 2/9/1976 12:00:OOAM Rig Release: 12/21/2010 Rig Contractor: NORDIC CALISTA UWI: 500292019700 Active Datum: E -05 @56.60ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 13:00 2.50 RUNCOM N DPRB RUNCMP WT CHK AT 10500' = 35K UP AND 19K DOWN. STING INTO DEPLOYMENT SLEEVE AT 10703' AND CONTINUE RUNNING IN HOLE TO 10713'. NOTED IMMEDITATE INCREASE IN COILED TUBING PRESSURE AS WE STUNG INTO DEPLOYMENT SLEEVE AND SAW RETURNS TO SURFACE STOP. RECORD SPACE OUT AND RE- CONFIRM TAG DEPTH AND WT. PUH AND DROP 5/8" ALUMINUM BALL FOR PACKER SET BALL DID NOT SEAT ON FIRST COIL VOLUME PUMPED. PUMPED ADDITIONAL COIL VOLUME AND CHASED WITH 30 BBL HIGH -VIS PILL BALL LANDED ON SEAT. RIH TO TAG DEPTH INSIDE DEPLOYMENT SLEEVE AND PUH 2'. SET PACKER AND TEST DOWN THE BACKSIDE TO 2400 PSI FOR 20 MINUTES(GOOD TEST) CONTINUE TO PRESSURE UP AND SHEAR SETTING TOOL AT 3600 PSI. 13:00 - 16:00 3.00 RUNCOM N DPRB RUNCMP POOH 16:00 - 16:30 0.50 RUNCOM N DPRB RUNCMP LD LINER RUNNING TOOL 16:30 - 16:45 0.25 RUNCOM P RUNCMP PJSM WITH LRS PUMP CREW AND RIG TEAM. DISCUSS MUSTER AREA, WIND DIRECTION AND GOOD COMMUNICATION. DISCUSSED ROLES AND RESPONSIBILITIES. 16:45 - 17:20 0.58 RUNCOM P RUNCMP MU AND RIH WITH FREEZE PROTECT BHA 17:20 - 18:30 1.17 RUNCOM P RUNCMP FREEZE PROTECT WELL FROM 2500' WITH DIESEL. 18:30 - 19:00 0.50 RUNCOM P RUNCMP MONITOR WELL, 19:00 - 20:00 1.00 RUNCOM P RUNCMP PJSM, GREASE MASTER AND SWAB VALVES 20:00 - 00:00 4.00 RUNCOM P RUNCMP PJSM, R/U AND TEST LUBRICATOR TO 250 PSI AND 3500 PSI WITH DIESEL, CHART TEST. SET BPV. 12/21/2010 00:00 - 00:30 0.50 RUNCOM P RUNCMP PJSM, UD LUBRICATOR. 00:30 - 05:30 5.00 RUNCOM P RUNCMP PJSM, OPEN AND INSPECT ALL BOP RAMS. FP COIL WITH DIESEL. C/O VARIABLES TO 2" COMBI RAMS. REMOVED SPOOLS AND CROSS OVERS. CLEANED PITS. 05:30 - 06:00 0.50 RUNCOM P RUNCMP RELEASE FROM WELL AT 06:00 Printed 3/2/2011 5:06:10PM 01/20/11 Schtumber e NO. 5676 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 5 Log Description Date BL Color CD 14-43 BGZ7 -00010 CROSSFLOW CHECK 4 ' - — / ♦ 11/13/10 1 • 1 NGt -14 AV1H -00052 USIT 1, )T. ° 12123110 •C:‘,,, , i 1 1 L -205 BLPO -00073 MEM LDL c� a 4, - 0.5" 12/21/10 1 �I 1 A-42A BL65 -00012 MEM PRODUCTION PROFILE O(p_- • j '3 v 01106111 1 • 1 01 -30 BCZ2 -00031 INJECTION PROFILE ) Z /10 ('4 '-'1 4 l 12/03/10 1 (j . 1 02 -20 BBSK -00040 RST — . 11119110 1 Y .1 1 07 -23B AY1 M -00056 ti:rlaU► , Z 1 K -11A B088 -00073 IMINliMMY ' ' le40 - N 1 04.24 AY1M -00058 IMEINIPF%1�Ft: I ' ' E' -rT•WL 1 1 • 11 -12 BCZ 2 - 00033 oQL ' ' ' fJ j 1 2- 28B/O -19 BCRJ -00055 RST q ♦ "' 12/01/10 1 0 1 1 S -128 BCZ2 -00035 USIT 01/02111 . n(n • 1 1 W -220 BG4H -00025 �I 12/27/10 lj 1 1 S-41A 10AKA0108 OH MWD WD EDIT ) ' ' ) 1 S -41AL1 10AKA0108 OH MWD /LWD EDIT 41.11 —10 a. wczoirmli _ •, , C 1. y 1 H -11 BGZ7 -00014 RST J 'S') - nip if 12/18/10 1 _ p , 1 __ P1D6pf4 . 11�1�i P_MIIIMIIIIIIF79L ri _ • . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data 8. Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 • .1r\ r1 0 • gem r �f r9 DATA SUBMITTAL COMPLIANCE REPORT 8/12/2010 Permit to Drill 2090210 Well Name/No. PRUDHOE BAY UNIT E-05B Operator BP EXPLORATION (ALASKIy INC API No. 50-029-20197-02-00 MD 11440 TVD 9068 Completion Date 4/8/2009 Completion Status 1-OIL Current Status 1-OIL UI~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes _ __ DATA INFORMATION Types Electric or Other Logs Run: DIR / GR /RES / PWD, DIR / GR /RES / NEU /DEN (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 ame Scale Media No Start Stop CH Received Comments D C Lis 18093 Induction/Resistivity 5353 11441 Open 6/3/2009 LIS Veri, GR, ROP, FET, RPX, RPS, RPM, RAM, RPD, NPHI, TRPM og Induction/Resistivity 25 Blu 5350 11395 Open 6/3/2009 MD Vision Service Lo Induction/Resistivity 25 Blu 5350 11395 Open 6/3/2009 TVD Vision Service I D C Asc Directional Survey 0 11440 Open 4/20/2009 pt Directional Survey 0 11440 Open 4/20/2009 og Production 5 Blu 8890 11256 Case 6/10/2010 Mem PPL, Spin, Temp, Pres, GR, CCL, XY Cal D C Pds 19729~roduction 8890 11256 Case 6/10/2010 Mem PPL, Spin, Temp, Pres, GR, CCL, XY Cal Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments • DATA SUBMITTAL COMPLIANCE REPORT 8/12/2010 Permit to Drill 2090210 Well Name/No. PRUDHOE BAY UNIT E-056 Operator BP EXPLORATION (ALASKIy INC MD 11440 TVD 9068 Completion Date 4/8/2009 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL INFORMATION Well Cored? Y /~ Daily History Received? (®/ N Chips Received? '~'-f-td' Formation Tops ~3 N Analysis -~ /-f~t Received? API No. 50-029-20197-02-00 UIC N Comments: Compliance Reviewed By: Date: -l.~ LJ os/osito Schlum~erger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Weil Job # Log Description Date BL NO.5538 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Color CD E-OSB V-220 E-09C BD88-00015 BCUE-00019 A%BD-00062 MEM PROD PROFILE MEM INJECTION PROFI E MCNL 05/20!10 05/16/10 11!20/09 1 1 1 1 1 1 0.13A 09-44A 09-44AP81 BBUO.00008 10AKA0043 t0AKA0043 RST OH 6Aylr WD EDIT OH MWD/LWD EDIT D3/09110 03/09/10 03/08/10 1 1 2 1 1 1 17-12A 09AKA0079 OH MWDA-WD EDIT ~ 03/10/10 2 1 PLEASE ACKNnWI Frl[:F GFr `LIDT RV CI!_rJaJ l: wun oerrro~uw,n ..~.~ ....nv ...,....~.._ BP Exploration (Alaska) Inc. Petrotechnical Dala Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, SuAe 400 Anchorage, AK 99503-2939 mid r x ~:~~~;o ~F~~ai~~i~~~ o5/2s/os ~~ • N0.5242 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambeil Street, Suite 40o Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 won .Inh it Laa Description Date BL Color CD PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. ~~ i Petrotechnical Data Center LR2-1 , . ~1 . ~ 1~~1 900 E. Benson Blvd. - ~ - '. ~ ~ Anchorage, Alaska 99508 Date Delivered: a~~~N d ~ ZOC~~ 4-04AIT-30 BOCV-00014 CH EDIT PDCL-GR (SCMT) ~ j 04/27/09 1 4-02/0-28 AYKP-00019 RST 05/07/09 1 1 H-196 B2WY-00004 MCNL 7/09 1 1 18-26B B2NJ-00001 MCNL - 04/14/09 1 1 J-20B AXBD-00020 MCNL ~ 04/12/09 1 1 W-06A AZCM-00021 RST ''~ _ L 05/16/09 1 1 15-15C BOOR-00004 MCNL ~ 03/15/09 1 1 14-31 BOCV-000015 RST ~ / ~ 05/15/09 1 1 E-05B 09AKA0035 OH MWD/LWD EDIT 04/06/09 2 1 06-14B 09AKA0031 OH MWD/LWD EDIT 03/27/09 2 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 0 Anchorage, AK 9 3-28 ATTN: Beth Received by: ~1~5 fit as. ~orn~missi~r~ `~ q~ch~r~ Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, May 18, 2009 10:49 AM To: Saltmarsh, Arthur C (DOA) Subject: PBU E-056 / PTD # 209-021 H i Art, Please reference the following well: Well Name: PBU E-05B Permit #: 209-021 API #: 50-029-20197-02-00 Top Perf MD: 10330' Bottom Perf MD: 11350' This well began Production on May 14, 2009 Method of Operations is: Flowing Date of Test: 05/16/09 Hours Tested: 4 24-Hour Rate /Oil-Bbl: 8,219 24-Hour Rate /Gas-Mcf: 59,277 24-Hour Rate /Water-Bbl: 192 Test Rate /Oil-Bbl: 1,370 Test Rate /Gas-Mcf: 9,880 Test Rate /Water-Bbl: 32 Choke Size: 95 Gas-Oil Ration: 7,212 Flow Tubing Pressure: 1,100 Casing Pressure: 1,140 Oil Gravity-API: 26 5/18/2009 STATE OF ALASKA ! .~ ~ ALASKA OIL AND GAS CONSERVATION COMNR'~~SION '!'~~Y ~ ~I 1.009 WELL COMPLETION OR RECOMPLETION REPORT AND LOG~~~~, ;~ ~~s COns, Commission Attt:hctranp 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.los zoAAC zs.11o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband 4/ 2009 12. Permit to Drill Number 209-021 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 3/27/2009 13. API Number 50-029-20197-02-00 4a. Location of Well (Governmental Section): Surface: 7. Date T.D. Reached 4!6/2009 14. Well Name and Number: PBU E-05B 1353' FNL, 502' FEL, SEC. 06, T11 N, R14E, UM Top of Productive Horizon: 669' FNL, 1834' FWL, SEC. 05, T11 N, R14E, UM 8. KB (ft above MSL): 59.05' Ground (ft MSL): 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 667' FNL, 3156' FWL, SEC. 05, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 11352' 9065' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 664473 y- 5975711 Zone- ASP4 10. Total Depth (MD+TVD) 11440' 9068' 16. Property Designation: ADL 028304 TPI: x- 666791 y- 5976447 Zone- ASP4 5976478 Zone- ASP4 668113 th T t l D 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: : x- y- o a ep 18. Directional Survey ®Yes ^ No S mi lectronic and rin d information r 20 AAC 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information oer 20 AAC 25 71): DIR / GR /RES / PWD, DIR / GR /RES / NEU /DEN %/y~J~/~iS~S"O~ 'MD So?/d S~7'YO 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE' AMOUNT WT. PER FL GRADE TOP BOTTO(N TOP BOTTOM SIZE CEMENTING RECORD -PULLED 20" 94# H-4 Surfa 106' rf 106' 26" 12 cu ft ment " 44' -1/2" r fr 9- / " 47# N-8 Surfa rf 216' 12-1/4" 11 9 u ft Howco it 8 250 cu tt Class 'G', 560 cu tt PF 'C' " 7 ' rf -1/ 376 cu ft LiteCrete 3.32 185 cu ft'G' 1.16 4-1/ " 12.6# L-8 95 114 7 0' 067' 6-1/8" 09 cu lass 'G' 1.17 23. Open to production or inject ion? ®Yes ^ No 24. TusING RECORD If Yes, IISt each I P TVD f T & B tt nterval Open mb r) Si d N f ti SIZE DEPTH SET MD PACKER SET MD : ze an u e om; er ora on (MD+ op o o f 2-7/8" Gun Diameter 6 s 4-1/2", 12.6#, 13Cr80 9518' 9399' , p MD TVD MD TVD 10330' - 10400' 9075' - 9070' 9061' 1 ' 9066' ' 2rj, ACID., FRACTURE, CEMENT SQUEEZE, ETC. 0640 - 10510 - 10870' - 10910' 9063' - 9065' DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 10970' -11080' 9068' - 9064' ' ' ' ' 2000' Freeze Protect w/ 68 Bbls of Diesel 9064 - 9065 11130 - 11200 11260' - 11350' 9065' - 9065' 26, PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: CALCULATED 24-HOUR tZATE~ OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewall Core s A wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. .;... -~~usu None ` -~ §T Form 10-407 ReVlSeci 02/Zp07 r ~ P L;ONTINUED VN KEVERSE JIDI'' 1ZGi ~ ~ f~~j~ 28. VEOLOGIC MARKERS (LIST ALL FORMATIONS AND ERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No If yes, list intervals and formations tested, briefly summarizing test Permafrost Top results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 9666' 8855' None Shublik A 9703' 8891' Shublik B 9725' 8911' Shublik C 9755' 8938' Sadlerochit 9764' 8945' Top CGL 9894' 9025' Zone 26 10064' 9059' Zone 2A 11102 9064' Formation at Total Depth (Name): Zone 2A 11102' 9064' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore ing is true and correct to the best of my knowledge. ` / ~ %~ / D7/ V Signed Terrie Hubble Title Drilling Technologist Date PBU E-05B 209-021 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number Per it N . / A rOVBI NO. Drilling Engineer: Jovy Roach, 564-4352 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). Irenwl 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). IreM 20: Repoli true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of ~ Leak-Off Test Summary Legal Name: E-05 Common Name: E-05 -- --~ Test Date i Test Type.: ! Test Depth (TM ~- - -- 3/26/2009 LOT 5,509.0 (ft) 4/2/2009 FIT 9,670.0 (ft) Test Depth (TVD) 5,215.0 (ft) 8,860.0 (ft) AMW Surface Pressure __ -- 9.00 (ppg) 711 (psi) 8.50 (ppg) 1,152 (psi) Leak Off Pressure (BHP) 3,149 (psi) 5,064 (psi) EMW 11.62 (PPg) 11.00 (ppg) Printed: 4/27/2009 10:13:25 AM BP EXPLORATION Operations Summary Report Legal Well Name: E-05 Common Well Name: E-05 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 7ES Date ~! From - To Hours. Task I Code', NPT 6.00 MOB P 3/20/2009 18:00 - 00:00 3/21/2009 100:00 - 03:30 I 3.501 MOB I P 03:30 - 09:30 ~ 6.00 MOB ~ N ~ WAIT 09:30 - 16:30 7.00 MOB P 16:30 - 18:00 1.50 MOB P 18:00 - 23:00 5.00 MOB P 23:00 - 00:00 1.00 ~ RIGU ~ P 3/22/2009 100:00 - 02:00 2.00 RIGU ~ P 02:00 - 04:00 2.00 ~ EVAL P 04:00 - 05:00 ~ 1.00 ~ WHSUR ~ P 05:00 - 07:30 ~ 2.501 WHSUR ~ P 07:30 - 09:00 I 1.501 WHSUR I P 09:00 - 12:00 3.00 WHSUR P 12:00 - 16:00 4.00 16:00-18:00 2.00 BOPSU~N SFAL 18:00 - 19:30 1.50 BOPSU P 19:30 - 00:00 4.50 BOPSU P 13/23/2009 100:00 - 01:00 01:00 - 03:00 1.00 BOPSU P 2.00 BOPSU P Start: 3/19/2009 Rig Release: 4/10/2009 Rig Number: Page 1 of 15 Spud Date: 2/9/1976 End: 4/10/2009 Phase j Description of Operations __ __ _ _ -- PRE Released rig from F-18A at 1800. Crew continued with securing well and preparing for rig move to E-056. Preparing to lay down derrick, blowing down steam lines, disconnecting power for move. Satellite camp, truck shop connected and began movement at 2200. Staged at beginning of access road leading out to Spine. PRE Move pits, truck shop and satellite camp from F-18A to E-056. Stage camp and truck shop. PRE Waiting on weather. Ambient temperature at -38 to -40. Cannot lower derrick. PRE Lay down derrick, move rig off of F-18A. Move to E-05B. PRE Move rig onto E-05B. Position over well. PRE Secure derrick, spot Sub structure, spot pits, hang bridle lines, secure rig floor. Make up serivice lines from rig to pits. Rig accepted at 2300 hrs 03/21/09 on well E-05B. DECOMP Berm, RU temporary cuttings box and hard-line returns box for taking diesel freeze protect from well. DECOMP RU pressure testing equipment for IA and OA. Continue staging and MU hardline to tank for displacement of freeze protect diesel. Begin taking on seawater into pits. DECOMP Pressure test OA to 2000 psi for 30 min on chart. Bled 100 psi in first 15 min, 30 psi second 15 min. Pressure test TxIA to 2000 psi for 30 min on chart. Bled 30 psi in first 15 min, 10 psi in second 15 min. Pressure built to 150 psi on OA during test. RD test equipment. DECOMP RU DSM lubricator and pressure test to 500 psi. Pull BPV. RD DSM lubricator. DECOMP Reverse circulate 33 bbls diesel freeze protect out of tubing with 80 deg seawater. Line up on tubing, pump 50 bbl Safe-Surf-O sweep and circulate out with 80 degree seawater to clear diesel freeze protect from annulus at 260 gpm, 650 psi. Blow down all lines. DECOMP Install TWC and pressure test from below to 1000 psi and from above to 3500 psi for 10 minutes each. DECOMP ND tree and adapter flange DECOMP NU BOP. Adjust turnbuckles, choke lines due to height of wellhead. Test of choke lines show restriction. Remove choke hose, apply steam, free block. Test line, clear. DECOMP Remove choke hose, apply steam, free block. Test line, clear. DECOMP Continue to RU BOP test equipment and pressure test lines. DECOMP PJSM on testing BOP. With TWC installed, test BOP equipment with 4" and 4 1/2" test joints to 250 psi / 3500 psi. Each test held for 5 minutes. Bob Noble of AOGCC waived witness of test. -Test witnessed by Toolpusher Lenward Toussant, WSL Rob O'Neal. DECOMP Complete BOP test. Test BOP equipment with 4" and 4 1/2" test joints to 250 psi / 3500 psi. Each test held for 5 minutes. Bob Noble of AOGCC waived witness of test. -Test witnessed by Toolpusher Lenward Toussant, WSL Rob O'Neal. DECOMP RU DSM lubricator, extension and pressure test to 500 psi. Pull TWC. RD DSM extension and lubricator. rnntea: ciuieuuy lU 133V HIVI BP EXPLORATION Page 2 of 15 Operations Summary Report Legal Well Name: E-05 Common Well Name: E-05 Spud Date: 2/9/1976 Event Name: REENTER+COMPLETE Start: 3/19/2009 End: 4/10/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/10/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To ' Hours Task 3/23/2009 03:00 - 04:00 ~ 1.00 PULL P 04:00 - 05:00 1.00 PULL P 05:00 - 12:00 7.00 PULL P 12:00 - 14:30 2.50 BOPSU P 14:30 - 15:00 0.50 PULL P 15:00 - 17:00 2.00 PULL P 17:00 - 19:00 2.00 PULL P 19:00 - 20:30 1.50 PULL P 20:30 - 22:00 1.50 PULL P 22:00 - 00:00 2.00 PULL P 3/24/2009 100:00 - 03:00 03:00 - 04:00 04:00 - 05:00 05:00 - 05:30 05:30 - 07:00 07:00 - 08:30 08:30 - 09:00 09:00 - 09:30 09:30 - 11:00 11:00 - 12:00 3.001 CLEAN I P 1.001 CLEAN I P 1.00 CLEAN P 0.50 CLEAN P 1.50 CLEAN P 1.50 CLEAN P 0.50 CLEAN P 0.50 CLEAN P 1.50 CLEAN P 1.00 CLEAN P 12:00 - 14:00 Code NPT Phase Description of Operations 2.001 CLEAN ~ P DECOMP RU spear assembly. Spear tubing hanger and unseat with 105k. Pull hanger to floor with 93k and LD. DECOMP CBU. RU SLB control line spooling equipment while circulating. DECOMP POH with 4 1/2" 12.6# L-80 AB-BTC tubing and spool up control line. Recovered 5 stainless steel bands and 25 contol line protectors. Continue to LD tubing. Recovered a total of 150 jts, 1 BVLN, and 1 cut off jt 19.25' in length DECOMP RD tubing equipment. RU BOP testing equipment. Insert test plug and test lower rams to 250 psi low and 3500 psi high for 5 minutes each with 4" test joint. Test witnessed by Tool Pusher Larry Wurdeman and WSL Mike Dinger. RD BOP test equipment. DECOMP Clear and clean rig floor. Mobilize equipment to rig floor. DECOMP MU scraper BHA: 8 1/2" bit, 9 5/8" scraper, two boot baskets, string mill, bumper jars, nine DCs, HWDP. DECOMP Change elevators to PU DP. RIH with scraper BHA on 4" DP one-by-one. DECOMP Make scraper run and RIH on 4" DP to 1,977'. Saw first tight spot at 1,948'. Able to work through first tight spot with pumps and rotation with 15 rpm. At 1,977', unable to work through tight spot with pumps. Did not rotate due to fear of cutting through casing with string mill. POH for BHA change. DECOMP POH, stand back 4" DP DECOMP Stand back HWDP, DCs. Lay down bumper sub, string mill, boot baskets, scraper and bit. Small amounts of new metal shavings in boot baskets. DECOMP Inspection of scraper blades show heavy damage to lower areas, indicating casing may be tight. Decide to use tapered 8 1/4", then 8 1/2" swedge to open up casing. Change out actuator valve in IBOP of top drive to two manual safety valves to avoid damage during swedging operations. DECOMP PJSM on making up and running swedge BHA. MU swedge BHA #3: 8 1/4" swedge, bumper jars, oil jars, accelerators, nine DCs, HWDP. DECOMP RIH with 8 1/4" swedge BHA #3 on 4" DP to 2187'. No problems. PUW 77k, SOW 77k. DECOMP POH with 8 1/4" swedge BHA #3 from 2187' to 950'. MW in /out 8.5 ppg. DECOMP LD 8 1/4" swedge BHA #3. DECOMP MU swedge BHA #4: 3 DC, 8 1/2" Swedge, bumper jars, oil jars, 6 DC, accelerators, HWDP. DECOMP RIH with 8 1/2" swedge BHA #4 on 4" DP to 2288'. No problems. PUW SOk, SOW 80k. DECOMP POH with 8 1/2" swedge BHA #4 from 2288' to 950'. MW in /out 8.5 ppg. DECOMP LD 8 1/2" swedge BHA #4. DECOMP MU window mill BHA #5: 8 1/2" window mill, 8 3/8" string mill, flex joint, 8 1/2" string mill, bumper jar, oil jars, 9 DC, 21 jts 4" HWDP. DECOMP PU 14 stands from derrick and 111 jts from pipe shed of 4" DP and RIH with window mill BHA #4 from 950' to 5755' with no issues. rnmea: aiz nzuua 1U:7 J:JU HM ~ ~ BP EXPLORATION Page 3 of 15 Operations Summary Report Legal Well Name: E -05 Common W ell Name: E -05 Spud Date: 2/9/1976 Event Nam e: R EENTE R+COM PLET E Start : 3/19/2009 End: 4/10/2009 Contractor Name: N ABORS ALASK A DRI LLING I Rig Release: 4/10/2009 Rig Name: N ABORS 7ES Rig Number: Date From - To Hours ~ Task Code NPT Phase Description of Operations 3/24/2009 14:00 - 16:30 2.50 CLEAN P DECOMP Circulate one bottoms up at 6 bpm with 480 psi. 16:30 - 17:00 0.50 CLEAN P DECOMP POH with window mill BHA #5 in stands and set back. MW in /out 8.5 ppg. 17:00 - 21:00 4.00 CLEAN P DECOMP LD window mill BHA #5. All BHA components in gauge. 21:00 - 22:00 1.00 CLEAN P DECOMP Pressure test 9 5/8" casing to 2000 psi for 10 min to determine that the FOC in the 9 5/8" casing is closed -good test. Pressure test lost 20 psi during 1st 5 min and 10 psi during 2nd 5 min. OA pressure up to 180 psi during test and bled off to 0 psi after pressure on IA was bled off. 22:00 - 00:00 2.00 DHB P DECOMP RU to run 9 5/8" Halliburton EZSV plug on E-line. 3/25/2009 00:00 - 01:30 1.50 DHB P DECOMP RIH with Halliburton 9 5/8" EZSV bridge plug and set at 5531' MD (top element), 5' above casing collar at 5536' MD. Positive indication at surface of set. Tension in E-line lost 212 lbs. PU and SO on EZSV 400 Ibs to confirm set. 01:30 - 02:00 0.50 DHB P DECOMP POH with E-line. Verified tension sleeve in EZSV setting tool sheared. 02:00 - 03:00 1.00 DHB P DECOMP RU to test EZSV bridge plug. Pressure test 9 5/8" casing to EZSV bridge plug to 2000 psi for 10 minutes -good test during first 6 min, IA lost 10 psi and OA remained constant at 180 psi. During the second 4 min of the test the IA decreased 50 psi as the OA gained 40 psi. Bleed off pressure on IA to zero and OA remained with 80 psi. Open OA valve and bled off OA to 0 psi. Re-tested EZSV to 2000 psi. IA lost 70 psi during test while OA gained 60 psi. 03:00 - 03:30 0.50 DHB P DECOMP Rig down Schlumberger E-Line unit. 03:30 - 04:00 0.50 WHSUR P DECOMP Service rig and change out Top Drive IBOP. 04:00 - 05:00 1.00 WHSUR P DECOMP ND BOP. 05:00 - 12:00 7.00 WHSUR P DECOMP ND McEvoy 2 Step tubing spool with YB pack off. Backed out lock down screws and changed 9 5/8" primary seal on slips. Run in lock down screws. Install new 2 Step tubing spool with 9 5/8" YB pack off. Pump plastic into packing void and attempt to test pack off -test failed due to leaking seal. 12:00 - 18:00 6.00 WHSUR P DECOMP Removed 2 Step tubing spool and changed damaged seal in secondary 9 5/8" YB pack off. Install 2 Step tubing spool. Filled packing void with plastic and tested primary and secondary pack offs to 3800 psi for 30 min -good test. NU BOP stack, install test plug, 4" test joint and test service break on stack to 250 / 3500 psi for 10 min -good test. 18:00 - 19:30 1.50 DHB P DECOMP RU to test 9 5/8" casing. Pressure test 9 5/8" casing to EZSV bridge plug to 3500 psi for 30 min - 9 5/8" casing lost 60 psi during first 15 min and 50 psi during last 15 min. OA (9 5/8" x 13 3/8" annulus) gained 80 psi during first 15 min and 50 psi during last 15 min. 19:30 - 21:00 1.50 DHB P DECOMP Rig down test equipment. Consulted with town on 9 5/8" casing test. Decision made to trip in and ensure FO cementer is closed -mobilize Halliburton tools. 21:00 - 22:30 1.50 DHB P DECOMP MU BHA #6 with Halliburton FOC closing tool, 7 stands of 4" HWDP and RIH on 4" DP to 1980' MD. Good indication on surface that Halliburton closing tool found FOC at 1980' MD with 7k lbs. Cycled tools three times and determined that FOC was already closed. h'rl rlt2tl: 4/L//LUUH IUa J:3U HM BP EXPLORATION Operations Summary Report Legal Well Name: E-05 Common Well Name: E-05 Event Name: REENTER+COMPLETE Start: 3/19/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/10/2009 Rig Name: NABORS 7ES Rig Number: Date I From - To I Hours Task I Code I NPT ~ Phase 3/25/2009 22:30 - 00:00 1.50 DHB ~P 3/26/2009 100:00-02:30 02:30 - 06:00 06:00 - 06:30 2.50 STWHIP P 3.50 STWHIP P 0.50 STWHIP P Page 4 of 15 Spud Date: 2/9/1976 End: 4/10/2009 Description of Operations DECOMP POH with Halliburton FOC closing tool and LD. RU to test 9 5/8" casing. Pressure test 9 5/8" casing to EZSV bridge plug to 3500 psi for 15 min - 9 5/8" casing lost 70 during first 7 min and 80 psi during last 8 min. OA (9 5/8" x 13 3/8" annulus) gained 70 psi during first 7 min and 130 psi during last 8 min. Bleed off pressure on 9 5/8" casing to 0 psi and OA remained with 300 psi. WEXIT Make up 9 5/8" whipstock BHA #7 with 8 3/8" Bottom Trip Anchor, Baker Gen II 9 5/8" whipstock slide, 8 1/2" window mill, 8 3/8" lower watermellon mill, 5" flex joint, 8 1/2" upper watermellon mill, float sub, 1 jt 5" HWDP, XO sub, MWD, UBHO sub, 6 1/4" bumper sub, XO sub and 9 6-1/2" DC. WEXIT RIH with whipstock BHA #7 on 4" DP to 1500' MD and shallow test MWD tools: 784 psi, 530 gpm. Continue to RIH from 1500' MD to 5517' MD. PUW 125k, SOW. 130k. WEXIT Orient Baker Gen II 9 5/8" whipstock 62 degrees left of high - side. Tag EZSV at 5530' MD and SO 18k to set bottom trip anchor. PU 10k over to confirm. Shear mills from slide with 35k down weight. Pick up to confirm mills sheared from the whipstock assembly. WEXIT Displace well to 9.0 ppg LSND milling fluid at 516 gpm with 1230 psi for a total of 500 bbls of 9.0 ppg LSND pumped. Take and record slow pump rates prior to begin milling operations. S I~, `~ -` .A 06:30 - 07:00 0.50 STWHIP P ~~ 13:45 - 15:00 15:00 - 16:00 16:00 - 19:00 19:00 - 20:00 20:00 - 21:30 21:30 - 00:00 3/27/2009 100:00-04:30 o.ro o i vvnir r vv~ni i. .v.... u uc vv~~~...,.v ~~~ .....v vu~.~.y .....~ .. .......~.,..~..y parameters: 500 gpm and 1325 psi, weight on mills 6k - 20k ~ ) ~ Ibs, torque on bottom 5k - 15k ft-Ibs at 40 - 90 rpm. PUW ' 130k, SOW 125k, ROT 125k. Milled window from 5508' MD to 5525' MD. Pump Super Sweeps with nut plug at 40-80 rpms at 5520' MD and work the mills as needed. Drilled new hole to 5546' MD. Worked mills through the window several times with and without rotation with no issues. - Top of window at 5508' MD -Bottom of window at 5525' MD. -Average mill speed thru casing = 4.06 ft/hr 1.25 STWHIP P WEXIT Circulate bottoms up with a 25 bbls Super Sweep to clean metal debris from wellbore at 510 gpm with 1314 psi and 40 rpm, torque 4k-5k ft-Ibs. Total of 283 Ibs of metal shavings retrieved across shaker ma nets. Work mills through the window several times with rotation with no issues. 1.00 STWHIP P WEXIT Pull BHA #7 into casing at 5492' MD and perform LOT to EMW of 11.62 with 9.0 ppg mud in the hole at a epth of 5215' TVD. 3.00 STWHIP P WEXIT Pump dry job prior to POH at 5592' MD. POH from 5592' MD to 1007' MD. MW in /out 9.0 ppg. Monitor well -static. 1.00 STWHIP P WEXIT La down millin BHA #7 -upper string mill in gauge at 8 1/2". 1.50 STWHIP P WEXIT Pull wear bushing and jet BOP stack. Clean and clear rig floor. Function rams. 2.50 STWHIP P WEXIT Make u 8 1/2" drillin BHA #8 with: rebuilt 8 1/2" DTX619-D6 Hycalog Bit, XP Motor 1.5, ARC, MWD, NM Stab, 2 NM Spiral DC, NM Stab, NM Spiral DC, Float, Jars, PBL Circ Sub, XO and 23 jts 4" HWDP. 4.50 STWHIP P WEXIT RIH with 8 1/2" drilling BHA #8 while picking up 4" DP singles from 912' MD to 5350' MD. Shallow test MWD tool at 1107' Printed: 4/27/2009 10:13:30 AM BP EXPLORATION Page 5 of 15 Operations Summary Report Legal Well Name: E-05 Common Well Name: E-05 Spud Date: 2/9/1976 Event Name: REENTER+COMPLETE Start: 3/19/2009 End: 4/10/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/10/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/27/2009 00:00 - 04:30 4.50 STWHIP P WEXIT MD at 500 gpm with 850 psi -good test. 04:30 - 05:30 1.00 STWHIP P WEXIT Log for tie in from 5350' MD to 5546' MD at 300 ft/hr with pumps off for recording mode only. 05:30 - 12:00 6.50 DRILL P INTi Drill ahead in 8 1/2" hole from 5546' to 5971' MD ~ - 550 gpm, 1960 psi on, 1885 psi off - 10k WOB, 5k ft/Ibs torque on, 3.4k ft/Ibs torque off, 80 rpm - 135k PUW, 115k SOW, 125k ROT Wt -ART 1.08 hrs, AST 3.13 hrs, ADT 4.21 hrs, Jars 144.9 hrs -Adding 20 bbls of H2O per hour - No fluid loss - Mud Weight in/out - 9.0 ppg Surve s indicate drillin BHA #8 followed motherbore annulus fora roximatel 300'. 12:00 - 22:30 10.50 DRILL P INTi Drill ahead in 8 1/2" hole from 5971' to 6478' MD - 550 gpm, 2100 psi on, 1954 psi off - 10k WOB, 5.5k ft/Ibs torque on, 4k fUlbs torque off, 80 rpm - 143k PUW, 124k SOW, 127k ROT Wt -ART 0.37 hrs, ADT 6.25 hrs, Bit 10.47 hrs, Jars 151.2 hrs -Adding 20 bbls of H2O per hour - No fluid loss - Mud Weight in/out - 9.0 ppg Unable to get the required deg dog legs needed to drill interme is a secion as p a e o inspect and change 22:30 - 23:00 0.50 DRILL P INTi POH from 6478' MD to 5885' MD. Pump out of the hole 5885' MD to 5530' MD at 126 gpm with 320 psi due to swabbing. POH on elevators from 5530' MD to 5315' MD. Monitor well -static. MW in 9.0 ppg / MW out 9.0 ppg. 23:00 - 23:30 0.50 DRILL P INT1 Circulate one bottoms up at 500 gpm with 1550 psi, 3k ft-Ibs torque, 112 RTWT and 60 rpm. 23:30 - 00:00 0.50 DRILL P INT1 POH from 5315' MD to 5155' MD. Monitor well -static. MW in/out - 9.0 ppg 3/28/2009 00:00 - 02:00 2.00 DRILL P INTi Continue to POH from 5155' MD to 910' MD. - MW in /out 9.0 ppg 02:00 - 04:00 2.00 DRILL P INTi LD drillina BHA #8. Inspect bit. Bit grade: 1-2-CT-A-X-I-BU-BHA. 04:00 - 06:30 2.50 DRILL P INT1 MU 8 1/2" drilling BHA #9 with: 8 1/2" DTX619 Hycalog Bit, XP Motor 1.83, ARC, MWD, NM Stab, 2 NM Spiral DC, NM Stab, NM Spiral DC, Float, Jars, PBL Ball Catch and Circ Sub, and 23 jts 4" HWDP. 06:30 - 07:00 0.50 DRILL P INT1 RIH with 8 1/2" drilling BHA #9 from 913' MD to 1008' MD. Shallow test MWD tool at 558 gpm with 1266 psi -good test. 07:00 - 09:00 2.00 DRILL P INT1 RIH on 4" DP stands from 1008' MD to 5413' MD. 09:00 - 10:00 1.00 DRILL P INTi Slip and cut 88' drilling line. Inspect brakes -good. Service top drive and crown. 10:00 - 12:00 2.00 DRILL P INTi RIH from 5413' MD to 6369' MD. Wash down from 6369' MD to 6478' MD. 12:00 - 00:00 12.00 DRILL P INT1 Drill ahead in 8 1/2" hole from 6478' to 7038' MD - 550 gpm, 2405 psi on, 2227 psi off - 10k WOB, 6k ft/Ibs torque on, 4.5k ft/Ibs torque off, 60 rpm PrintBtl: 4/17/"LUUy 1U:1:1::SU AM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: E-05 Common Well Name: E-05 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 7ES Date From - To Hours Task Code NPT 3/28/2009 12:00 - 00:00 12.001 DRILL P 3/29/2009 ~ 00:00 - 12:00 12.001 DRILL P 12:00 - 00:00 I 12.001 DRILL I P 3/30/2009 100:00 - 12:00 12.001 DRILL ~ P 12:00 - 13:30 I 1.501 DRILL I P 13:30 - 15:30 I 2.001 DRILL I P 15:30 - 23:30 I 8.001 DRILL I P Start: 3/19/2009 Rig Release: 4/10/2009 Rig Number: Page 6 of 15 Spud Date: 2/9/1976 End: 4/10/2009 Phase Description of Operations INTi INTi INT1 INT1 INT1 INT1 INTi - 150k PUW, 125k SOW, 135k ROT Wt - ADT 7.72 hrs, ART 1.35 hrs, AST 6.37 hrs, Bit 7.72 hrs, Jars 158.9 hrs - Adding 20 bbls of H2O per hour - No fluid loss noted - Mud Weight in/out - 9.1 ppg Drill ahead in 8 1/2" hole from 7038' to 7921' MD - 550 gpm, 2917 psi on, 2521 psi off - 15k WOB, 9.3k fUlbs torque on, 6.4k fUlbs torque off, 60 rpm - 170k PUW, 135k SOW, 140k ROT Wt -ADT 7.31 hrs, ART 3.23 hrs, AST 4.08 hrs, Bit 15.5 hrs, Jars 166.3 hrs -Adding 20 bbls of H2O per hour - No fluid loss noted - Mud Weight in/out - 9.1 ppg Drill ahead in 8 1/2" hole from 7921' to 8662' MD - 500 gpm, 2865 psi on, 2556 psi off - 15k WOB, 7.8k fUlbs torque on, 6.8k fUlbs torque off, 60 rpm - 185k PUW, 137k SOW, 152k ROT Wt -ADT 8.68 hrs, ART 2.85 hrs, AST 5.83 hrs, Bit 23.84 hrs, Jars 174.98 hrs -Adding 20 bbls of H2O per hour - 290 bbls of 11.5 ppQ LSND spike fluid were slowly added at - No fluid loss noted - Mud Weight in/out - 9.9 ppg Drill ahead in 8 1/2" hole from 8662' to 9520' MD - 500 gpm, 3220 psi on, 2960 psi off - 15k WOB, 10k fUlbs torque on, 9.3k fUlbs torque off, 60 rpm - 207k PUW, 150k SOW, 152k ROT Wt -ADT 7.74 hrs, ART 5.02 hrs, AST 2.72 hrs, Bit 31.58 hrs, Jars 182.8 hrs -Adding 20 bbls of H2O per hour - No fluid loss noted - Mud Weight in/out - 9.9 ppg Drill ahead in 8 1/2" hole from 9520' to 9670' MD - 500 gpm, 3360 psi on, 3030 psi off ' - 16k WOB, 10k fUlbs torque on, 9.Ok fUlbs torque off, 60 rpm - 220k PUW, 150k SOW, 165k ROT Wt -ADT 0.88 hrs, ART 0.88 hrs, AST 0 hrs, Bit 32.46 hrs, Jars 183.7 hrs - Adding 20 bbls of H2O per hour - No fluid loss noted - Mud Weight in/out - 9.9 ppg Circulate for samples for Geologist at 500 gpm with 3020 psi for a total of 2 bottoms up. Monitor well -static. POH from TD at 9670' MD to 9420' MD. Wiped 16 tight spots of 35k to 40k over normal drag between 9420' MD and 9037' MD. Make up top drive and pump out of the hole at 4 bpm with 860 psi due to swabbing until upper ghost reamer inside 9 5/8" casing. Attempt to pull 2 stands on the elevators -hole still tight. Make up top drive and pump out of the hole to 5504' MD rrmtea: aiz nzuua IUa J:JU HM BP EXPLORATION Operations Summary Report Legal Well Name: E-05 Common Well Name: E-05 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 7ES Date From - To ,Hours Task Code NPT -- _ __ 3/30/2009 15:30 - 23:30 8.00 DRILL P 23:30 - 00:00 0.50 DRILL P 3/31/2009 00:00 - 01:30 1.50 DRILL P 01:30 - 03:30 I 2.001 DRILL I P 03:30 - 05:30 I 2.001 DRILL I P 05:30 - 10:30 5.00 DRILL P 10:30 - 13:30 3.00 DRILL P 13:30 - 15:30 2.00 BOPSU P 15:30 - 17:00 1.50 CASE P 17:00 - 00:00 7.00 CASE P 4/1/2009 00:00 - 02:30 2.50 CASE P 02:30 - 04:00 1.50 CASE P 04:00 - 08:00 I 4.001 CASE I P 08:00 - 09:00 1.00 CASE P 09:00 - 10:30 1.50 CASE P Page 7 of 15 ~ Spud Date: 2/9/1976 Start: 3/19/2009 End: 4/10/2009 I Rig Release: 4/10/2009 .Rig Number: Phase Description of Operations ___ INT1 at 500 gpm with 2800 psi. MW in /out 9.9 ppg INTi Service top drive and draw works. INT1 Circulate casing clean at 550 gpm with 2311 psi for a total of 362 bbls pumped. PUW 120k, SOW 110k. Orient BHA at 62 deg left of high side in prepartion for TIH to TD. MW in /out 9.9 ppg. Monitor well -static. Continue to service top drive and draw works. INT1 RIH and filled the pipe at 7984' MD. Continue to RIH and hung up at 9647' MD. Attempt to establish circulation at 250 gpm with 40 psi and saw no return flow. Work pipe free with 41 k overpull. Stage up pups and saw return flow at 28 gpm with 575 psi. Found neutral point at 10k ft-Ibs torque with 29 rpm and ROTW 165k. Continue to stage up pumps and observe pressure stablize while rotating and reciprocating pipe. Continue to RIH to 9670' MD. INT1 Stage up pumps and circulate 41 bbl Hi Vis Sweep surface to surface while reciprocating and rotating the pipe at 500 gpm with 3280 psi. PUW 220k, SOW 150k, ROTW 165k and 60 rpm. Increase of 50 - 60 % of cuttings after Hi Vis Sweep back to surface. INTi POH from 9670' MD to inside of 9 5/8" casing window at 5508' MD and pump dry job, monitor well -static. Continue to POH from 5508' MD to 912' MD with no problems. MW in /out 9.9 ppg. INT1 La down 8 1/2" drillin BHA #9. Inspect bit; grade 0-1-BU-A-X-I-PN-TD. Bit had two plugged nozzles and 4 plugged junk slots. Clear and clean rig floor of all 8 1/2" BHA and handling equipment. Pull wear ring. LNR1 Chan a out u er ram from 3.5" x 6" to 7". Test upper rams with 7" test joint and test plug to 250 psi low and 3500 psi high. Record on chart. Good test. Install wear ring. LNR1 RU to run 7", 26#, L-80, BTC-M x TC-II Intermediate Long String. Change baffles and RU 7" casing handling tools and torque turn equipment. LNR1 Make up 7" and Baker-lok shoe track, check floats. Run 73 'oints of 7" 26# L-80 BTC-M with an average make up torque of 8000 ft-Ibs to 2926' MD. Make up 7" BTC-M x 7" TC-II XO and run 4 joints of 7", 26#, L-80, TC-II with an optimal make up torque of 10100 ft-Ibs to 3150' MD. Filled pipe every joint with Franks Fill Up Tool. INT1 Continue to RIH with 7" 26# L-80 BTC-M x TC-II casing filling up every joint from 3150' MD to 5484' MD (9 5/8" casing window). Average MU torque on TC-II is 10100 ft-bls. INT1 Circulate 1.5 casing volumes staging pumps to 5"bpm with 430 psi for a total of 315 bbls pumped. INT1 Continue to RIH with 7" casing from 5484' MD to 8400' MD (THRZ) breaking circulation every 10th joint. PUW 225k, SOW 145k. INT1 Circulate one bottoms up at 5 bpm with 675 psi. INTi Continue to RIH with 7" casing from 8400' MD to TD at 9670' MD. Pick up 1' to set casing shoe at 9669' MD. SOW 160k, PUW 250k. Printed: 4/27/2009 10:13:30 AM • BP EXPLORATION Page 8 of 15 Operations Summary Report Legal Well Name: E-05 Common Well Name: E-05 Spud Date: 2/9/1976 Event Name: REENTER+COMPLETE Start: 3/19/2009 End: 4/10/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/10/2009 Rig Name: NABOBS 7ES Rig Number: Date ~ From - To ;Hours Task !Code NPT ' Phase Description of Operations 4/1/2009 10:30 - 14:00 3.50 CEMT P INT1 PJSM with SLB, crew, WSL, Toolpusher. MU cement head. Circulate one bottoms up. Stage up pumps: 1,5 bpm C~ 465 psi, 3 bpm C~ 600 psi, 4 bpm C~3 664 psi, 4.5 bpm @ 635 psi, 5 bpm (~ 600 for a total of 550 bbls. No losses noted during circulation. 14:00 - 17:00 3.00 CEMT P INTi Cement casing per SLB cement plan. - Pump 10 bbls of MudPUSH II @ 10.5 ppg - Pressure test cement lines to 4000 psi with MudPUSH II. - Pump 20 bbls of MudPUSH II ~ 10.5 ppg - Drop Bottom Plug; positive indication plug left head - Pump 67 bbls, 113 sx at 3.32 cufUsx of 11.0 LiteCRETE lea cement at 5 bpm - Pump 33 bbls, 189 sx at 1.16 cufUsx of 15.8 ppg Class G tail cement at 3 bpm - Drop Top Plug and kick out with 5 bbls water; positive indication plug left head - Switch to rig pumps. - Displace cement with 366 bbls of 9.9 ppg LSND mud at 5 bpm and 3 bpm for last 30 bbls per pumping schedule. - Bump the plug at 366 bbls (6269 strokes), 1630 psi. Bleed off pressure and check floats -floats holding. - Full returns throw hout the 'ob -Cement in place at 16:37 hrs. NOTE: Tail cement 500 psi compressive strength 9:05 hrs. Lead cement 500 psi compressive strength 8:47 hrs. 17:00 - 17:30 0.50 CEMT P INT1 Pressure test 7" casing to 3500 psi for 30 minutes -good test. Zero pressure lost during 7" pressure test. 17:30 - 19:30 2.00 CEMT P INT1 Line up on 9 5/8" x 7" annulus. Close annular preventer and establish injectivity at 890 psi. Clear annulus with 5 bbls of 9.9 ppg LSND. Continue to pump 1 bbl of 9.9 LSND into 9 5/8" x 7" annulus every 30 minutes to ensure clear. 19:30 - 20:30 1.00 BOPSU P INT1 N OP and raise to insert Cameron 7" emergency slips. 20:30 - 22:00 1.50 WHSUR P INTi Install 7" Cameron emergency slips and pack off in casing spool with 200k lbs. Run in lock down screws to energize primary seal. Cut 7" casing with Wachs cutter. Lay down cut off joint. 22:00 - 00:00 2.00 WHSUR P INT1 Install 13 5/8" 5k Cameron (McEvoy) tubing spool with 7" YBT secondary seal. 4/2/2009 00:00 - 01:30 1.50 WHSUR P INT1 Continue to install 13 5/8" 5k Cameron (McEvoy) tubing spool with 7" YBT secondary seal. Pressure test primary and secondary seals to 4300 psi (80% of 7", 26#, L-80, TC-II casing collapse) for 30 minutes -good test. Pump plastic into packing void in secondary seal between T and Y seal of to energize Y seal. 01:30 - 04:30 3.00 BOPSU P INT1 NU BOP. Change top rams from 7" to 3 1/2" x 6". During NU BOP: - From 02:00 hrs to 03:00 hrs: Establish injectivity in OA (9 5/8" x 7" annulus) with 1154 psi. Pump 155 bbls of 9.9 LSND into 9 5/8" x 7" annulus (110% of annular volume) at 3 bpm with 1050 psi. - From 03:22 hrs to 05:08 hrs: Pump 56 bbls of diesel Freeze Printed: 4/L//LUUy 1U:1:i::1U AM ~ ~ BP EXPLORATION Operations Summary Report Page 9 of 15 Legal Well Name: E-05 Common W ell Name: E-05 Spud Date: 2/9/1976 Event Nam e: REENTE R+COM PLET E Start : 3/19/2009 End: 4/10/2009 Contractor Name: NABORS ALASK A DRI LLING I Rig Release: 4/10/2009 Rig Name: NABORS 7ES Rig Number: Date From - To I Hours Task ~ Code', NPT Phase Description of Operations 4/2/2009 01:30 - 04:30 3.00 BOPSU P INTi Protect (80 deg F) at a constant 1000 psi. Check annulus pressure, bled off to zero psi (-4 bbls of diesel bled back) and close OA valve. 04:30 - 05:30 1.00 BOPSU P INT1 RU to test BOP. 05:30 - 09:30 4.00 BOPSU P INT1 Test BOP equipment with 4 1/2" and 2 7/8" test joints to 250 psi / 3500 psi. Each test held for 5 minutes. Lou Grimaldi of AOGCC waived witness of test. Test witnessed by WSL Duncan Ferguson and Toolpusher Lenward Toussant. 09:30 - 10:30 1.00 BOPSU P INT1 Rig down BOP test equipment. Install wear ring. Clear and clean rig floor. 10:30 - 13:00 2.50 DRILL P PROD1 MU BHA #10 with: 6 1/8" Hughes MX-R18DX, ShortPak PDM 1.69 deg, NM Stablizer, NM Flex 10' Lead DC, MWD, ADN4, 3 NM Flex DC, Jars, CCV Ball Catcher, CCV Circ Sub and 15' Lead DC. 13:00 - 14:00 1.00 DRILL P PROD1 RIH with BHA #10 picking 4" DP singles to 1236' MD. Shallow test MWD at 230 gpm with 1080 psi -good test. 14:00 - 14:30 0.50 DRILL P PROD1 Service Top Drive. 14:30 - 15:30 1.00 DRILL P PROD1 RIH with BHA #10 picking up 4" DP singles from 1236' MD to 2593' MD. 15:30 - 18:00 2.50 DRILL P PROD1 Continue to RIH in 4" stands from 2593' MD to 9546' MD filling up pipe every 30 stands. Screw in top drive and wash down to float collar at 9585' MD. PUW 240k, SOW 115k. 18:00 - 19:30 1.50 DRILL P PROD1 Tag landing collar at 9585'. Drill up landing collar, cement and oat co ar wit no ro a ion o 9659' MD. 250 gpm, 2131 psi. 19:30 - 21:00 1.50 DRILL P PROD1 Pump 75 bbl of water, followed by 40 bbl spacer (DuoVis and water). Displace to 8.5 ppg FloPro mud at 250 gpm with 1360 psi for a total of 800 bbls of FloPro pumped. 21:00 - 22:30 1.50 DRILL P PROD1 Drill up shoe and 20' of new hole to 9690' MD sliding only at 250 gpm, 1515 psi. PUW 180k, SOW 145K. 22:30 - 23:00 0.50 DRILL P PROD1 Pull back into shoe. Conduct FIT to EMW 11 ppg, TVD 8860', 9670' MD, 1152 psi. ood test. 23:00 - 00:00 1.00 DRILL P PROD1 Drill ahead in 6 1/8" hole to from 9690' to 9695'. - 250 gpm, 1580 psi on, 1515 psi off, 15k WOB - 180k PUW, 1145k SOW - ADT 0.6 hrs, AST 0.6 hrs, Bit 0.6 hrs, Jars 118.5 hrs - No fluid loss noted while drilling -Mud Weight in/out - 8.5 ppg 4/3/2009 00:00 - 07:00 7.00 DRILL P PROD1 Drill ahead in 6 1/8" hole from 9695' MD to 9896' MD. BHA nave an average o 25.37 DLS that allowed to finish the curve - 250 gpm, 1700 psi on, 1548 psi off, 25k WOB - 180k PUW, 145k SOW - ADT 6.31 hrs, AST 6.31 hrs, Bit 6.91 hrs, Jars 124.82 hrs - No fluid loss noted while drilling - Mud Weight in/out - 8.5 ppg 07:00 - 08:00 1.00 DRILL P PROD1 Circulate bottoms up at 250 gpm with 1564 psi. PUW 185k, SOW 150k. 08:00 - 12:00 4.00 DRILL P PROD1 POH from 9896' MD to 9650' MD (inside 7" casing shoe). Monitor well -static. Pump dry job and blow down top drive. Continue to POH from 9650' MD to 281' MD. MW in /out 8.5 PPg• 12:00 - 13:30 1.50 DRILL P PROD1 LD BHA #10. Inspect 6 1/8" tricone bit; grade: 2-2-BT-M-E-1-WT-BHA. F'~Int2tl: 42//"LUU`J IUa J:JU NM ~ ~ BP EXPLORATION Page 10 of 15 Operations Summary Report Legal Well Name: E-05 Common Well Name: E-05 Spud Date: 2/9/1976 Event Name: REENTER+COMPLETE Start: 3/19/2009 End: 4/10/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/10/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To 'Hours Task ' Code NPT ~ Phase' Description of Operations 4/3/2009 13:30 - 15:00 1.50 DRILL P PROD1 MU BHA #11 with: 6 1/8" Smith XR-20D, 1.5 deg bent mud motor, NM Stablizer, NM Flex 10' Lead DC, MWD, ADN4, 3 NM Flex DC, Jars, CCV Ball Catcher, CCV Circ Sub and 15' Lead DC. 15:00 - 18:30 3.50 DRILL P PROD1 RIH in 4" stands from 281' MD to 9650' MD filling up pipe every 30 stands. 18:30 - 19:30 1.00 DRILL P PROD1 Cut and slip 112' of drilling line. Service top drive, blocks, crown, inspect draw works and brakes. 19:30 - 20:00 0.50 DRILL P PROD1 RIH from 9650' MD to 9896' MD. PUW 186k, SOW 140k. 20:00 - 00:00 4.00 DRILL P PROD1 Drill ahead in 6 1/8" hole to from 9896' to 10,005'. - 250 gpm, 1730 psi on, 1630 psi off, 13.5k WOB - 190k PUW, 147k SOW, ROTW 160k - ADT 2.49 hrs, ART 0.82 hrs, AST 1.67 hrs, Bit 2.49 hrs, Jars 127.34 hrs - No fluid loss noted while drilling - Mud Weight in/out - 8.5 ppg 4/4/2009 00:00 - 05:30 5.50 DRILL P PROD1 Continue to drill ahead from 10,005' MD to 10,130' MD. - 250 gpm, 1785 psi on, 1630 psi off, 15k WOB - 195k PUW, 150k SOW, ROTW 160k - ADT 4.3 hrs, ART 3.12 hrs, AST 1.18 hrs, Bit 6.76 hrs, Jars 131.6 hrs - No fluid loss noted while drilling - Mud Weight in/out - 8.5 ppg Unable to drill ahead and pressure differential indicate under au a bit. Bit had also reached its life limit when compared with its performance on F-33A through same formation (bit revs: -47k and -7 hrs). Decision made to POH and change bits. 05:30 - 06:30 1.00 DRILL P PROD1 Circulate bottoms up at 250 gpm with 1630 psi and 40 rpm. 06:30 - 10:30 4.00 DRILL P PROD1 POH from 10,130' MD to 9650' MD (inside 7" casing shoe). Monitor well -static. Pump dry job. Continue to POH from 9650' MD to 281' MD. MW in /out 8.5 ppg. 10:30 - 12:00 1.50 DRILL P PROD1 LD BHA #11. Inspect 6 1/8" Smith tricone bit; 3/8" undergauge and gra e: 8-8-BT-A-F-6-SD-PR. 12:00 - 13:30 1.50 DRILL P PROD1 MU BHA #12 with: 6 1/8" Smith XR-20D, 1.5 deg bent mud motor, NM Stablizer, NM Flex 10' Lead DC, MWD, ADN4, 3 NM Flex DC, Jars, CCV Ball Catcher, CCV Circ Sub and 15' Lead DC. 13:30 - 15:00 1.50 DRILL P PROD1 RIH in 4" stands from 281' MD to 1235' MD and shallow test MWD at 250 gpm with 900 psi -good test. Continue to RIH from 1235' MD to 4670' MD. 15:00 - 17:00 2.00 DRILL P PROD1 Service top drive, change wash pipe and packing. Test to 3000 psi. Refer to remarks section of this report for incident. 17:00 - 19:00 2.00 DRILL P PROD1 Continue to RIH from 4670' MD to 10,022' MD. PUW 193k, SOW 143k. 19:00 - 20:30 1.50 DRILL P PRODi Ream down due to under au a hole from 10,022' MD to 10,130' MD at 250 gpm with 1550 psi, 40 rpm and 5.5k ft-Ibs torque, ROTW 160k, WOB 2 - 5k lbs. 20:30 - 00:00 3.50 DRILL P PROD1 Continue to drill ahead from 10,130' MD to 10,250' MD. - 250 gpm, 1640 psi on, 1555 psi off, 15k WOB - 193 PUW, 146k SOW, ROTW 160k - ADT 2.22 hrs, ART 0.7 hrs, AST 1.52 hrs, Bit 2.22 hrs, Jars rrincea: niziizuua IV:IJ:SV HM BP EXPLORATION Page 11 of 15 Operations Summary Report Legal Well Name: E-05 Common Well Name: E-05 Spud Date: 2/9/1976 Event Name: REENTER+COMPLETE Start: 3/19/2009 End: 4/10/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/10/2009 Rig Name: NABOBS 7ES Rig Number: Date !~ From - To 'Hours Task Code ! NPT ', Phase , Description of Operations 4/4/2009 20:30 - 00:00 I 3.501 DRILL I P I PROD1 133.8 hrs 4/5/2009 100:00 - 12:00 I 12.001 DRILL I P 12:00 - 15:30 I 3.501 DRILL I P 15:30 - 16:30 I 1.001 DRILL I P 16:30 - 21:00 I 4.501 DRILL I P 21:00 - 22:30 1.501 DRILL P 22:30 - 00:00 1.501 DRILL P 14/6/2009 00:00 - 04:30 4.501 DRILL P 04:30 - 12:00 7.50 DRILL P 12:00 - 18:30 6.50 DRILL P 18:30 - 19:30 1.00 DRILL P 19:30 - 20:30 I 1.001 DRILL I P - No fluid loss noted while drilling - Mud Weight in/out - 8.5 ppg PROD1 Continue to drill ahead from 10,250' MD to 10,754' MD. - 250 gpm, 1700 psi on, 1620 psi off, 15k WOB - 195k PUW, 145k SOW, ROTW 155k - ADT 9.05 hrs, ART 4.2 hrs, AST 4.85 hrs, Bit 11.32 hrs, Jars 142.87 hrs - No fluid loss noted while drilling - Mud Weight in/out - 8.5 ppg PROD1 Continue to drill ahead from 10,754' MD to 10,842' MD. - 250 gpm, 1790 psi on, 1625 psi off, 20k WOB - 198k PUW, 145k SOW, ROTW 155k - ADT 2.47 hrs, ART 0.8 hrs, AST 1.67 hrs, Bit 13.78 hrs, Jars 145.3 hrs - No fluid loss noted while drilling - Mud Weight in/out - 8.5 ppg PROD1 Circulate bottoms up at 250 gpm with 1720 psi, 60 rpm and 6k ft-Ibs torque. ROTW 155k. PROD1 POH from 10,842' MD to 10,400' MD. Intermittent swabbing with no over pull. Pump out from 10,400' MD to 10,100' MD at 128 gpm with 750 psi. POH on elevators from 10,100' MD to 9545' MD (inside 7" casing shoe). Pump dry job. Continue to POH from 9545' MD to 280' MD. PROD1 LD BHA #12. Inspect 6 1/8" Smith tricone bit; 1/4" undergauge and grade: 4-7-BT-G-E-4-SD-PR. PROD1 MU BHA #13 with: 6 1/8" Hughes MX-R18DX, 1.5 deg bent mud motor, NM Stablizer, NM Flex 10' Lead DC, MWD, ADN4, 3 NM Flex DC, Jars, CCV Ball Catcher, CCV Circ Sub and 15' Lead DC. MWD tool was changed. PRODi RIH in 4" stands from 280' MD to 10,842' MD. PUW 195k, SOW 145k. PROD1 Continue to drill ahead from 10,842' MD to 11,255' MD. - 250 gpm, 1841 psi on, 1741 psi off, 15k WOB - 205k PUW, 135k SOW - 5k ft-Ibs torque on, 7k ft-Ibs torque off, 60 rpm, ROTW 155k - ADT 5.21 hrs, ART 3.28 hrs, AST 1.93 hrs, Bit 5.21 hrs, Jars 150.6 hrs - No fluid loss noted while drilling - Mud Weight in/out - 8.6 ppg PROD1 Continue to drill ahead from 11,255' MD to 11,440' MD. - 250 gpm, 1977 psi on, 1881 psi off, 15k~~ - 205k PUW, 135k SOW, - 7.5k ft-Ibs torque on, 6k ft-Ibs torque off, ROTW 155k, 60 rpm - ADT 5.8 hrs, ART 5.38 hrs, AST 0.42 hrs, Bit 11 hrs, Jars 156.4 hrs - No fluid loss noted while drilling - Mud Weight in/out - 8.6 ppg PROD1 Circulate one bottoms up at 250 gpm with 1880 psi, 60 rpm, 6.5k ft-Ibs torque, 155k ROTW. Shakers look clean, very fine articles of sand comin across and showed no indication of wellbore instabilit . PROD1 Pump out of the hole from 11,440' MD to 10,640' MD at 125 Printed: 4/27/2009 10:13:30 AM BP EXPLORATION Page 12 of 15 Operations Summary Report Legal Well Name: E-05 Common Well Name: E-05 Spud Date: 2/9/1976 Event Name: REENTER+COMPLETE Start: 3/19/2009 End: 4/10/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/10/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours a/6/2o09 19:30 - 20:30 1.001 Task Code N PT DRILL ~ P 20:30 - 00:00 ~ 3.50 ~ DRILL ~ P 4/7/2009 00:00 - 01:30 ~ 1.50 ~ DRILL ~ P 01:30 - 02:30 I 1.001 DRILL I P 02:30 - 06:30 I 4.001 DRILL I P 06:30 - 08:30 I 2.001 DRILL I P 08:30 - 09:00 0.50 CASE P 09:00 - 12:30 3.50 CASE P 12:30 - 17:00 I 4.501 CASE I P 17:00 - 17:30 I 0.501 CASE I P 17:30 - 19:30 I 2.001 CEMT I P Phase I Description of Operations PROD1 gpm with 810 psi. One tight spot with 25k over pull, wiped clean from 10,995' MD to 10,980' MD. PROD1 MAD Passing in the UP direction from 10,640' MD to 10,025' MD at 250 fUhr, 250 gpm, 1800 psi, 40 rpm, 6k ft-Ibs torque, ROTW 150k. MW in /out 8.6 ppg PROD1 Continue to MAD Pass in the UP direction from 10,025' MD to 9791' MD at 250 ft/hr, 250 gpm and 1656 psi with no rotation due to dog leg severity close to the 7" casing shoe (ADN4 tool cannot be rotated accross dog leg greater than 15 deg / 100 ft). PROD1 POH from 9791' MD to 9630' MD (inside 7" casing). Open CCV and circulate casing clean at 400 gpm with 1411 psi. Monitor well -static. Pump dry job and drop rabbit. MW in /out 8.6 ppg. PROD1 POH from 9630' MD to 281' MD. MW in /out 8.6 ppg. PROD1 LD BHA. PJSM on removing nuclear source. Remove source. Continue to lay down BHA. LD 6 1/8" PDC bit. Bit grade: 2-6-W T-A-E-2/16-LT-TD -Clear and clean rig floor RUNPRD RU 4 1/2" liner running equipment RUNPRD MU shoe assembly, test floats. Floats good. RIH with 4 1/2" 12.6# L-80 IBT-M liner. Baker-Lok shoe track joints #'- ~ -i with 4 1/2" 12.6# L-80 IBT-M liner filling every joint, topping off every 10 joints. -Make-up torque 4440 ft/Ibs -Centralizers: One centralizer on joint #1 10' from shoe, one centralizer on joint #2 in middle, two centralizers on joints #3-43 with stop ring in middle of joint. 84 total centralizers. -MU liner running tool, liner and packer to 4 1/2" liner -MU one stand DP, circulate 1.5 times liner volume at 215 gpm, 270 psi -PUW 52k, SOW 49k RUNPRD -Continue to RIH with 4 1/2" liner on 4" DP filling every 20 stands. RUNPRD -Circulate 1.5 times DP and liner volume at shoe at 9,669' -Stage pumps up from 1-5 bpm; ICP at 1 bpm 370 psi, FCP at 5 bpm 750 psi -No losses -PUW 170k, SOW 137k RUNPRD Continue to RIH with 4 1/2" liner on 4" DP. MU cement head, RIH to bottom. -PUW 19~c,~OW 147k 19:30 - 21:00 1.50 CEMT P RUNPRD Stage up pumps to 5 bpm, 1050 psi and circulate prior to cement job while reciprocating. RU SLB cementers. PJSM with crew, SLB cementers, WSL, Toolpusher, Mud Engineer. 21:00 - 00:00 3.00 CEMT N WAIT RUNPRD Wait on water trucks. Trucks ordered for arrival at 20:00 for cement job but unavailable due to activity on Slope. 4/8/2009 00:00 - 00:45 0.75 CEMT N WAIT RUNPRD Wait on water trucks. Trucks ordered for arrival at 20:00 for cement job but unavailable due to activity on Slope. 00:45 - 01:45 1.00 CEMT P RUNPRD Begin batching up mudpush and cement for cement job. PJSM with crew, SLB cementers, WSL, Toolpusher, Mud Engineer. 01:45 - 03:30 1.75 CEMT P RUNPRD Cement liner per cement plan: F'flflt8tl: 4/"L//"LUUy lU:1 J:JU HM BP EXPLORATION Operations Summary Report Legal Well Name: E-05 Common Well Name: E-05 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 7ES Date From - To Hours ' Task j Code NPT Page 13 of 15 ~ Spud Date: 2/9/1976 Start: 3/19/2009 End: 4/10/2009 Rig Release: 4/10/2009 Rig Number: Phase, Description of Operations 4/8/2009 01:45 - 03:30 1.75 CEMT P RUNPRD -Pump 10 bbls of 10.5 ppg MudPush II and pressure test cement lines to 4,500 psi -Pump 10 bbls of 10.5 ppg MudPush II -Pump 55 bbls of 15.8 ppg Class G cement at 5 bpm. Yield 1.17 cu-ft/sx, Sacks 264. Compressive strengt :500 psi at 9 hrs, 2000 psi at 14 hrs. -Switch over to rig pump and displace with 30 bbls 8.5 ppq perf ill followed b 92 bbls of 8.5 FloPro mud at SBPM. -Slow rate to 26PM prior to latching liner wiper plug, shear at 1625 psi. Increase pump rate until just prior to bumping plug at 2400 psi. Increase pressure to set hanger, slack off 25K to ensure hanger set. -Increase pressure to 4200 psi to release HRD and set down 25k to ensure set. -Bleed pressure to zero and check floats; floats holding -Pick up string to ensure HR tool released. S/O 50K to set ZXP liner top packer and see good surface indication of set. Repeat sequence once with no rotation and twice with rotation. -Pressure up to 1000 psi and pick up string to clear setting tool packoff. -Top of liner at 9,505', shoe at 11,438'. -Displace ~ 12 bpm, 2000 psi. -A roximatel 18 bbls of contaminated cement returns -Full returns throughout cement iob. CIP C~ 02:52 03:30 - 04:00 0.50 CEMT P RUNPRD RD cementing equipment 04:00 - 05:30 1.50 CEMT P RUNPRD Displace well to 8.5 ppg seawater from top of 4 1/2" liner to surface. Pump 100 bbl fresh water ahead of displacement to seawater. Liner is full of new 8.5 ppg FloPro mud. 05:30 - 08:30 3.00 CEMT P RUNPRD POH from 9,500' to 1,624' laying down 4" DP 08:30 - 09:30 1.00 CEMT P RUNPRD POH from 1,624' to surface laying down 4" DP -LD liner running tool. Confirmation dog sub sheared. 09:30 - 10:30 1.00 PERFO P OTHCMP RU to run perforation guns 10:30 - 11:00 0.50 PERFO P OTHCMP Casing pressure test on production liner to 3500 psi recorded -Lost 40 psi in first 15 minutes, 0 psi in second 15 minutes; good test 11:00 - 13:00 2.00 PERFO N WAIT OTHCMP Waiting on delivery of pert guns. Transportation had been coordinated since 2200 hrs previous night with delivery expected after 0600 changeout today. 13:00 - 16:30 3.50 PERFO P OTHCMP PJSM. PU 2-7/8" HSD Power Jet 2906 pert guns (60 degree phasing, 6 spf). Run 31 jts of 2-7/8" Fox pipe and RIH to 2,497'. 16:30 - 20:30 4.00 PERFO P OTHCMP RIH with erforatin BHA on 4" DP. Ta u on de th at 11,35 (float collar at 11,352', with liner wiper plug and pump-down plug seated). Pull up 2' to put guns on depth. -PUW 180k, SOW 140k -8.5 ppg seawater in and out 20:30 - 21:30 1.00 PERFO P OTHCMP PJSM. Conduct 3 practice runs, execute firing sequence and fire pert guns. Good indication of firing on surface. Perfed intervals: -10,330'-10,400' -10,510'-10,640' -10,870'-10,910' PfIlltBtl: 4/L//LUUy 1U:1:S::iU AM BP EXPLORATION Page 14 of 15 Operations Summary Report Legal Well Name: E-05 Common Well Name: E-05 Spud Date: 2/9/1976 Event Name: REENTER+COMPLETE Start: 3/19/2009 End: 4/10/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/10/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To !Hours Task Code ~~ NPT ' Phase ', Description of Operations 4/8/2009 20:30 - 21:30 1.00 PERFO P OTHCMP -10,970'-11,080' -11,130'-11,200' -11,260'-11,350' 21:30 - 22:00 0.50 PERFO P OTHCMP POH from 11,350' to 10,310' (above top perf). Monitor well; 5 bbls of fluid lost to the formation after firing the perforation 22:00 - 22:30 0.50 PERFO P OTHCMP Circulate bottoms up at 400 gpm, 2330 psi; 4 bbls of fluid lost to the formation during bottoms up. 8.5 ppg seawater in and out. 22:30 - 00:00 1.50 PERFO P OTHCMP POH, laying down DP, from 10,310' to 9,000'. 4/9/2009 00:00 - 02:30 2.50 PERFO P OTHCMP POH laying down DP from 9,000' to 2,497'. 02:30 - 03:30 1.00 PERFO P OTHCMP Slip and cut drilling line. 03:30 - 06:00 2.50 PERFO P OTHCMP RIH with 13 stands of 4" DP in derrick and then lay down DP. 06:00 - 10:00 4.00 PERFO P OTHCMP PJSM. RU handling equipment for 2-7/8" Fox tubing. LD 31 joints Fox tubing and pert guns from 2,497' to surface. Bleed and LD E-Fire firing head. LD guns; visually confirm all shots fired. -4 bph of fluid was lost to the formation while tripping out of the hole and laying down DP. -Total of 81 bbls o seawater ost to the formation for the day. 10:00 - 11:00 1.00 PERFO P OTHCMP RD handling equipment and clear and clean rig floor. 11:00 - 12:00 1.00 BUNCO P RUNCMP PJSM. Pull wear bushing. Make dummy run with tubing hanger. LD hanger and test joint 12:00 - 13:30 1.50 BUNCO P RUNCMP RU handling equipment for 4.5" 12.6# 13Cr Vam Top completion, Torque turn computer and compensator. 13:30 - 00:00 10.50 BUNCO P RUNCMP RIH with 4 1/2" 12.6# 13Cr Vam To com letion tubin . Baker-Lok all connections below S-3 packer. Average make-up torque at 4440 fUlbs. Tailpipe assembly: WLEG, XN nipple, full joint, X nipple, S-3 packer, X nipple. GLMs: #1 at 6,186' (DCK shear valve w/BEK latch), #2 at 3,480 with dummy latch. X nipple at 1,991'. Total of 220 joints run. 4/10/2009 00:00 - 01:30 1.50 BUNCO P RUNCMP Space out for pup joints. MU tubing hanger and land. RILDS. Bottom of WLEG at 9,517'. Top of packer set at 9,398'. 01:30 - 03:00 1.50 BUNCO P RUNCMP Reverse circulate 137 bbls clean seawater at 124 gpm, 190 psi. Displace with 60 bbls corrosion inhibited seawater followed by 78 bbls clean seawater to position inhibited water between GLM#1 and packer at 124 gpm, 190 psi. 03:00 - 04:30 1.50 BUNCO RUNCMP Drop ball and rod, seat on RHC plu .Set acker. Pressure test tubing to 3500 psi for 30 min on chart. Bled 20 psi in first 15 min 0 si in second 15 minutes. Bleed ressure t 1500 si, ressure back u to 3500 si on annulus for 30 min on chart. Bled 30 psi first 15 min, 10 si second 15 minutes. Bleed tubing and annulus to 0 psi. Pressure up annulus to 2800 psi to shear DCK valve in GLM #1. Pump 5 bbls both ways to comfirm shear. RD and blowdown test lines and equipment. 04:30 - 05:00 0.50 BUNCO P RUNCMP Install TWC, pressure test from below to 1000 psi for 10 min. 05:00 - 07:30 2.50 BOPSU P WHDTRE ND BOP. ack bac in ce ar an secure. 07:30 - 10:30 3.00 WHSUR P WHDTRE MU adapter flange and NU tree. Pressure test adapter flange and tree to 5000 psi with diesel. 10:30 - 11:30 1.00 WHSUR P WHDTRE RU Drill Site Maintenance lubricator. Test, ull TWC. 11:30 - 13:00 1.50 WHSUR P WHDTRE Clear and clean rig floor, prepare for laying down Derrick. RU Hot Oil Service for freeze protect. Pressure test lines to 3500 rnmea: 4iz nzwa lU:7 J:JU HM BP EXPLORATION Page 15 of 15 Operations Summary Report Legal Well Name: E-05 Common Well Name: E-05 Spud Date: 2/9/1976 Event Name: REENTER+COMPLETE Start: 3/19/2009 End: 4/10/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/10/2009 Rig Name: NABOBS 7ES Rig Number: Date 'From - To Hours Task Code NPT Phase Description of Operations 4/10/2009 11:30 - 13:00 1.50 WHSUR P WHDTRE psi. 13:00 - 16:00 3.00 WHSUR P WHDTRE Freeze protect to 2000' TVD by pumping down inner annulus at 1 gpm, psi with 68 bbls diesel and allow to u-tube into tubing. 16:00 - 17:00 1.00 WHSUR P WHDTRE Lubricate in BPV and test from below to 1000 si. 17:00 - 18:00 1.00 RIGD P POST Secure well and continue to prepare rig for move to A-44. Release rig at 1800 hrs. 18:00 - 00:00 6.00 RIGD P POST can pa area, peep pits and Sub for move. LD derrick. Stage equipment. rnnzeo: viuizuua iu:isa~raw by E-05B Survev Report Schlumberger . -~~.. _~--. Client: ..r.... ...... BP Exploration Alaska Field: Prudhoe Bay Unit- WOA Structure 1 Slot: E-PAD / E-05 Well: E-05 Borehole: E-056 UWI/API#: 500292019702 Survey Name 1 Date: E-056 I April 7, 2009 Tort 1 AH01 DDI 1 ERD ratio: 340.072° / 4628.49 ft / 6.297 / 0.510 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaHLong: N 70 20 23.795, W 148 39 54.956 Location Grid NIE YIX: N 5975711.000 ftUS, E 664473.000 ftUS Grid Convergence Angle: +1.25695225° Vertical Section Azimuth: 113.450° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 59.05 ft relative to MSL Sea Bed 1 Ground Level Elevation: 30.89 ft relative to MSL Magnetic Declination: 22.813° Total Field Strength: 57706.992 nT Magnetic Dip: 80.945° Declination Date: March 23, 2009 Magnetic Declination Model: BGGM 2008 • North Reference: True North Total Corr Mag North •> True North: +22.$13° Comments Measured Inclination Azimuth SulrSea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth TNe Section Departure True North True North (# de de ft ft k ft ft ft ft de 100 ft ftUS ftUS nn wl Tn nn nn Tnc In/ w ao nn e.l nac KI t U.UU V.UV V.UV -.7`J.V7 V.VU U.UV V.UU V.VV V.VV V.VV V.VV V.~/ VI I I.VV VVYY/J.VV IY / V LV GJ.IJJ YY 1?V JJ JT.JJV 2.45 0.00 180.00 -56.60 2.45 0.00 0.00 0.00 0.00 0.00 0.00 5975711.00 664473.00 N 70 20 23.795 W 148 39 54.956 WRP 29.05 0.00 0.00 -30.00 29.05 0.00 0.00 0.00 0.00 0.00 0.00 5975711.00 664473.00 N 70 20 23.795 W 148 39 54.956 SPERRY 3/5/76 102.45 0.20 187.58 43.40 102.45 0.04 0.13 0.13 -0.13 -0.02 0.27 5975710.87 664472.99 N 70 20 23.794 W 148 39 54.957 SU316053 GYRO 202.45 0.33 190.65 143.40 202.45 0.15 0.59 0.59 -0.58 -0.09 0.13 5975710.42 664472.92 N 70 20 23.789 W 148 39 54.959 302.45 0.12 162.94 243.40 302.45 0.28 0.98 0.97 -0.97 -0.12 0.23 5975710.03 664472.91 N 70 20 23.786 W 148 39 54.960 402.45 0.33 192.27 343.40 402.45 0.40 1.36 1.36 -1.35 -0.15 0.23 5975709.65 664472.88 N 70 20 23.782 W 148 39 54.961 502.45 0.33 210.14 443.40 502.45 0.42 1.93 1.91 -1.88 -0.35 0.10 5975709.11 664472.69 N 70 20 23.777 W 148 39 54.967 602.45 0.35 177.83 543.39 602.44 0.52 2.51 2.48 -2.43 -0.48 0.19 5975708.56 664472.57 N 70 20 23.771 W 148 39 54.970 702.45 0.17 187.28 643.39 702.44 0.70 2.96 2.93 -2.88 -0.49 0.18 5975708.11 664472.57 N 70 20 23.767 W 148 39 54.971 802.45 0.25 150.78 743.39 802.44 0.91 3.32 3.25 -3.22 -0.40 0.15 5975707.77 664472.67 N 70 20 23.763 W 148 39 ~8 902.45 0.18 134.22 843.39 902.44 1.23 3.69 3.53 -3.52 -0.19 0.09 5975707.47 664472.89 N 70 20 23.760 W 148 39 5.62 1002.45 0.17 279.81 943.39 1002.44 1.23 3.78 3.61 -3.61 -0.22 0.33 5975707.39 664472.86 N 70 20 23.760 W 148 39 54.963 1102.45 0.33 200.17 1043.39 1102.44 1.11 4.16 3.88 -3.85 -0.46 0.34 5975707.14 664472.62 N 70 20 23.757 W 148 39 54.970 1202.45 0.18 189.96 1143.39 1202.44 1.16 4.60 4.32 -4.28 -0.59 0.16 5975706.71 664472.50 N 70 20 23.753 W 148 39 54.974 1302.45 0.03 111.83 1243.39 1302.44 1.22 4.77 4.48 -4.44 -0.59 0.18 5975706.55 664472.50 N 70 20 23.751 W 148 39 54.974 1402.45 0.18 16.98 1343.39 1402.44 1.23 4.93 4.33 -4.30 -0.52 0.18 5975706.69 664472.57 N 70 20 23.753 W 148 39 54.972 1502.45 0.25 335.04 1443.39 1502.44 1.05 5.29 3.99 -3.95 -0.57 0.17 5975707.04 664472.52 N 70 20 23.756 W 148 39 54.973 1602.45 0.32 45.18 1543.39 1602.44 0.99 5.73 3.59 -3.56 -0.46 0.33 5975707.43 664472.61 N 70 20 23.760 W 148 39 54.970 1702.45 0.17 36.65 1643.39 1702.44 1.13 6.16 3.25 -3.24 -0.18 0.15 5975707.76 664472.89 N 70 20 23.763 W 148 39 54.961 1802.45 0.25 87.93 1743.39 1802.44 1.36 6.50 3.12 -3.12 0.13 0.20 5975707.89 664473.20 N 70 20 23.764 W 148 39 54.952 1902.45 0.83 94.56 1843.38 1902.43 2.24 7.45 3.34 -3.16 1.07 0.58 5975707.86 664474.14 N 70 20 23.764 W 148 39 54.925 SurveyEditor Ver SP 2.1 Bld( users) E-05\E-05\E-056\E-056 Generated 4/30/2009 12:49 PM Page 1 of 5 Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing EasGng Latitude Longitude Depth Ttie Section Departure True North True North ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS ZWZ.45 l.U/ 1U5.5L l'J43.3/ ZUUZ.4Z 3.155 y.lU 4.3y -3.4/ L.oy u.3v as/a/v/.aa OO49/O./! IV !V GV L3./OI VV 14o Jy V4.8/o 2102.45 1.42 60.70 2043.35 2102.40 5.53 11.16 5.62 -3.12 4.67 1.00 5975707.99 664477.74 N 70 20 23.764 W 148 39 54.820 2202.45 1.33 46.15 2143.32 2202.37 6.72 13.55 6.81 -1.71 6.59 0.36 5975709.44 664479.62 N 70 20 23.778 W 148 39 54.764 2302.45 1.33 31.80 2243.29 2302.34 7.34 15.86 8.04 0.09 8.04 0.33 5975711.26 664481.03 N 70 20 23.796 W 148 39 54.722 2402.45 1.05 30.09 2343.27 2402.32 7.61 17.94 9.30 1.86 9.11 0.28 5975713.06 664482.06 N 70 20 23.813 W 148 39 54.690 2502.45 0.32 15.50 2443.26 2502.31 7.68 19.13 10.08 2.93 9.64 0.74 5975714.14 664482.58 N 70 20 23.824 W 148 39 54.675 2602.45 0.07 7.58 2543.26 2602.31 7.63 19.47 10.26 3.26 9.72 0.25 5975714.47 664482.65 N 70 20 23.827 W 148 39 54.672 2702.45 0.05 5.07 2643.26 2702.31 7.60 19.57 10.30 3.36 9.74 0.02 5975714.57 664482.66 N 70 20 23.828 W 148 39 54.672 2802.45 0.15 85.25 2743.26 2802.31 7.70 19.73 10.44 3.41 9.87 0.15 5975714.63 664482.79 N 70 20 23.829 W 148 39 54.668 2902.45 0.65 97.33 2843.26 2902.31 8.36 20.42 11.08 3.35 10.56 0.50 5975714.58 664483.49 N 70 20 23.828 W 148 39 54.648 3002.45 2.85 97.05 2943.20 3002.25 11.29 23.48 13.92 2.97 13.59 2.20 5975714.27 664486.52 N 70 20 23.824 W 148 39 54.559 3102.45 4.83 97.13 3042.98 3102.03 17.71 30.17 20.35 2.15 20.24 1.98 5975713.59 664493.19 N 70 20 23.816 W 148 39 3202.45 5.72 94.29 3142.55 3201.60 26.46 39.36 29.41 1.25 29.39 0.93 5975712.90 664502.35 N 70 20 23.807 W 148 39 3302.45 8.58 94.06 3241.76 3300.81 38.21 51.81 41.80 0.35 41.80 2.86 5975712.27 664514.78 N 70 20 23.799 W 148 39 53.735 3402.45 10.90 101.66 3340.32 3399.37 54.50 68.70 58.54 -2.09 58.50 2.65 5975710.20 664531.53 N 70 20 23.775 W 148 39 53.247 3502.45 12.60 106.11 3438.22 3497.27 74.58 89.06 78.56 -7.03 78.24 1.93 5975705.69 664551.37 N 70 20 23.726 W 148 39 52.671 3602.45 14.33 107.84 3535.47 3594.52 97.71 112.34 101.45 -13.84 100.50 1.78 5975699.36 664573.78 N 70 20 23.659 W 148 39 52.021 3702.45 17.07 109.04 3631.73 3690.78 124.67 139.39 128.14 -22.43 126.16 2.76 5975691.35 664599.62 N 70 20 23.575 W 148 39 51.271 3802.45 19.43 109.74 3726.69 3785.74 155.90 170.71 159.12 -32.83 155.70 2.37 5975681.59 664629.37 N 70 20 23.472 W 148 39 50.408 3902.45 22.58 109.52 3820.04 3879.09 191.66 206.55 194.70 -44.87 189.46 3.15 5975670.30 664663.38 N 70 20 23.354 W 148 39 49.422 4002.45 25.67 109.74 3911.29 3970.34 232.44 247.42 235.36 -58.60 227.95 3.09 5975657.42 664702.16 N 70 20 23.219 W 148 39 48.298 4102.45 28.87 111.06 4000.17 4059.22 278.19 293.23 280.96 -74.60 270.87 3.26 5975642.37 664745.43 N 70 20 23.061 W 148 39 47.044 4202.45 30.33 111.71 4087.11 4146.16 327.55 342.62 330.12 -92.61 316.86 1.49 5975625.37 _ 664791.80 N 70 20 22.884 W 148 39 45.701 4302.45 31.00 112.42 4173.13 4232.18 378.53 393.62 380.90 -111.78 364.13 0.76 5975607.25 664839.47 N 70 20 22.696 W 148 39 44.320 4402.45 31.23 112.51 4258.74 4317.79 430.20 445.30 432.37 -131.52 411.88 0.23 5975588.55 664887.64 N 70 20 22.502 W 148 39 42.926 4502.45 32.60 113.31 4343.62 4402.67 483.06 498.16 485.04 -152.11 460.57 1.43 5975569.04 664936.77 N 70 20 22.299 W 148 39 41.503 4602.45 33.10 113.95 4427.63 4486.68 537.31 552.40 539.07 -173.85 510.27 0.61 5975548.40 664986.92 N 70 20 22.085 W 148 39 40.052 4702.45 34.07 114.15 4510.94 4569.99 592.62 607.72 594.18 -196.40 560..78 0.98 5975526.97 665037.91 N 70 20 21.863 W 148 39 38.576 4802.45 34.67 114.15 4593.48 4652.53 649.07 664.17 650.45 -219.49 612.29 0.60 5975505.01 665089.92 N 70 20 21.636 W 148 39 2 4902.45 35.83 113.61 4675.14 4734.19 706.78 721.89 708.02 -242.85 665.07 1.20 5975482.81 665143.19 ~ N 70 20 21.406 W 148 39 0 5002.45 36.67 113.12 4755.79 4814.84 765.91 781.02 767.06 -266.30 719.35 0.89 5975460.56 665197.97 N 70 20 21.176 W 148 39 33.945 5102.45 37.75 113.38 4835.43 4894.48 826.38 841.49 827.46 -290.17 774.91 1.09 5975437.91 665254.03 N 70 20 20.941 W 148 39 32.322 5202.45 37.67 113.00 4914.54 4973.59 887.55 902.66 888.56 -314.26 831.13 0.25 5975415.07 665310.77 N 70 20 20.704 W 148 39 30.680 5302.45 37.68 113.51 4993.69 5052.74 948.67 963.78 949.62 -338.39 887.29 0.31 5975392.18 665367.43 N 70 20 20.467 W 148 39 29.040 5402.45 37.17 113.40 5073.10 5132.15 1009.44 1024.55 1010.34 -362.58 943.04 0.51 5975369.22 665423.70 N 70 20 20.229 W 148 39 27.412 5502.45 36.87 114.01 5152.95 5212.00 1069.65 1084.76 1070.49 -386.78 998.17 0.47 5975346.23 665479.34 N 70 20 19.991 W 148 39 25.802 Tie-In Survey 5502.45 36.87 114.01 5152.95 5212.00 1069.65 1084.76 1070.49 -386.78 998.17 0.00 5975346.23 665479.34 N 70 20 19.991 W 148 39 25.802 Top Window (Blind) 5508.00 36.87 113.99 5157.39 5216.44 1072.98 1088.09 1073.81 -388.14 1001.21 0.22 5975344.94 665482.41 N 70 20 19.977 W 148 39 25.713 Bottom Window 5525.00 37.80 111.00 5170.90 5229.95 1083.28 1098.39 1084.12 -392.08 1010.73 11.99 5975341.21 665492.02 N 70 20 19.938 W 148 39 25.435 Inc+Trend 5537.31 36.89 111.00 5180.69 5239.74 1090.74 1105.86 1091.58 -394.76 1017.70 7.39 5975338.69 665499.05 N 70 20 19.912 W 148 39 25.231 5632.79 35.20 111.00 5257.89 5316.94 1146.87 1162.04 1147.76 -414.89 1070.15 1.77 5975319.71 665551.92 N 70 20 19.714 W 148 39 23.699 SurveyEditor Ver SP 2.1 Bld( users) E-05\E-05\E-056\E-056 Generated 4/30/2009 12:49 PM Page 2 of 5 Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Trua Section Departure True North True North ft de de ft ft ft ft ft ft ft de H00 ft ftUS ftUS 5/L/.y/ 33.t5Z 111.UU 033b.3Z v3yv.3/ 1NU./v ICIV.`J/ IGUI.va -43w.ci i icv.4a i.yv vaivovi.vv vvvvvc.vi rv ru cu ia.vcy vv iyo oa cc.ccy 5823.45 33.85 111.00 5415.63 5474.68 1253.86 1269.13 1254.85 -453.27 1170.13 0.03 5975283.54 665652.70 N 70 20 19.336 W 148 39 20.779 5919.82 32.89 108.00 5496.11 5555.16 1306.73 1322.13 1307.82 -470.97 1220.07 1.98 5975266.94 665703.02 N 70 20 19.162 W 148 39 19.320 6015.95 32.77 103.00 5576.91 5635.96 1358.30 1374.22 1359.66 -484.89 1270.26 2.82 5975254.12 665753.50 N 70 20 19.025 W 148 39 17.855 MWD+IFR+MS 6110.79 34.84 98.17 5655.72 5714.77 1409.69 1426.96 1411.55 -494.52 1322.10 3.58 5975245.64 665805.53 N 70 20 18.930 W 148 39 16.341 6206.85 34.07 92.47 5734.95 5794.00 1461.30 1481.28 1464.03 -499.58 1376.15 3.45 5975241.76 665859.68 N 70 20 18.881 W 148 39 14.762 6302.70 34.27 87.57 5814.27 5873.32 1510.66 1535.09 1514.71 -499.59 1429.95 2.88 5975242.93 665913.46 N 70 20 18.880 W 148 39 13.191 6398.43 34.52 81.35 5893.29 5952.34 1557.90 1589.13 1563.90 -494.37 1483.71 3.68 5975249.33 665967.09 N 70 20 18.932 W 148 39 11.620 6414.47 34.36 80.14 5906.52 5965.57 1565.53 1598.20 1571.94 -492.91 1492.66 4.38 5975250.99 665976.01 N 70 20 18.946 W 148 39 11.359 6494.00 33.72 71.89 5972.45 6031.50 1600.83 1642.67 1609.70 -482.20 1535.78 5.86 5975262.64 666018.88 N 70 20 19.051 W 148 39 10.099 6589.18 33.24 57.51 6051.97 6111.02 1635.26 1694.98 1648.43 -459.94 1582.97 8.33 5975285.93 666065.56 N 70 20 19.270 W 148 39 8.721 6684.59 32.53 44.73 6132.19 6191.24 1659.24 1746.63 1678.51 -427.63 1623.13 7.30 5975319.11 666105.00 N 70 20 19.588 W 148 39 6780.15 33.70 33.88 6212.29 6271.34 1673.38 1798.73 1700.71 -387.33 1656.02 6.32 5975360.12 666137.00 N 70 20 19.984 W 148 39 6.587 6876.69 35.63 24.95 6291.75 6350.80 1678.97 1853.56 1716.75 -339.56 1682.83 5.62 5975408.46 666162.75 N 70 20 20.454 W 148 39 5.803 6972.00 38.32 16.45 6367.93 6426.98 1676.09 1910.81 1726.78 -286.01 1702.93 6.06 5975462.44 666181.67 N 70 20 20.980 W 148 39 5.216 7066.14 39.56 6.56 6441.23 6500.28 1663.81 1969.89 1729.74 -228.17 1714.63 6.73 5975520.51 666192.10 N 70 20 21.549 W 148 39 4.874 7162.80 38.72 359.82 6516.23 6575.28 1642.74 2030.86 1726.18 -167.34 1718.05 4.48 5975581.40 666194.18 N 70 20 22.147 W 148 39 4.774 7258.33 37.88 358.30 6591.20 6650.25 1618.30 2090.07 1720.49 -108.14 1717.09 1.32 5975640.56 666191.92 N 70 20 22.730 W 148 39 4.801 7354.87 36.71 358.33 6668.00 6727.05 1593.46 2148.56 1716.08 -49.67 1715.37 1.21 5975698.97 666188.92 N 70 20 23.305 W 148 39 4.851 7448.22 38.65 359.25 6741.88 6800.93 1569.66 2205.62 1714.19 7.37 1714.17 2.16 5975755.97 666186.47 N 70 20 23.866 W 148 39 4.886 7545.33 37.94 358.13 6818.09 6877.14 1544.46 2265.80 1714.13 67.53 1712.80 1.02 5975816.08 666183.78 N 70 20 24.457 W 148 39 4.925 7640.29 40.11 358.22 6891.86 6950.91 1518.93 2325.59 1715.63 127.29 1710.90 2.29 5975875.78 666180.57 N 70 20 25.045 W 148 39 4.981 7736.60 39.18 357.51 6966.02 7025.07 1492.40 2387.03 1719.00 188.70 1708.61 1.07 5975937.12 666176.94 N 70 20 25.649 W 148 39 5.047 7832.12 33.59 5.50 7042.93 7101.98 1471.03 2443.61 1727.33 245.22 1709.83 7.66 5975993.65 666176.92 N 70 20 26.205 W 148 39 5.011 7927.17 30.21 16.04 7123.68 7182.73 1459.83 2493.73 1744.00 294.43 1718.97 6.84 5976043.04 666184.98 N 70 20 26.689 W 148 39 4.744 8022.09 27.11 17.93 7206.96 7266.01 1454.67 2539.25 1764.89 337.97 1732.23 3.40 5976086.86 666197.28 N 70 20 27.117 W 148 39 4.356 8117.67 19.92 19.05 7294.54 7353.59 1451.32 2577.36 1783.94 374.13 1744.27 7.54 5976123.27 666208.52 N 70 20 27.473 W 148 39 4.004 8212.56 16.92 29.33 7384.59 7443.64 1451.50 2607.27 1801.61 401.46 1756.31 4.65 5976150.86 666219.96 N 70 20 27.741 W 148 39 3.652 8308.13 16.31 46.82 7476.22 7535.27 1458.25 2634.40 1822.63 422.78 1772.92 5.25 5976172.53 666236.09 N 70 20 27.951 W 148 3~7 8403.88 15.69 56.48 7568.28 7627.33 1470.64 2660.73 1846.50 439.13 1793.52 2.85 5976189.33 666256.33 N 70 20 28.112 W 148 3 5 8499.93 13.44 63.56 7661.24 7720.29 1484.91 2684.86 1869.63 451.28 1814.35 2.98 5976201.93 666276.89 N 70 20 28.231 W 148 39 1.956 8594.79 11.67 62.91 7753.83 7812.88 1498.11 2705.48 1889.74 460.55 1832.76 1.87 5976211.61 666295.09 N 70 20 28.322 W 148 39 1.418 8691.38 12.79 64.48 7848.23 7907.28 1511.34 2725.94 1909.75 469.61 1851.11 1.21 5976221.07 666313.23 N 70 20 28.411 W 148 39 0.882 8786.96 14.00 64.59 7941.21 8000.26 1525.89 2748.08 1931.47 479.13 1871.10 1.27 5976231.02 666333.01 N 70 20 28.505 W 148 39 0.298 8882.63 13.50 64.46 8034.14 8093.19 1540.84 2770.82 1953.79 488.91 1891.63 0.52 5976241.25 666353.32 N 70 20 28.601 W 148 38 59.699 8976.99 12.18 65.05 8126.13 8185.18 1554.67 2791.79 1974.39 497.86 1910.59 1.41 5976250.61 666372.08 N 70 20 28.689 W 148 38 59.145 9073.92 13.23 63.86 8220.69 8279.74 1568.65 2813.10 1995.32 507.06 1929.82 1.12 5976260.23 666391.10 N 70 20 28.780 W 148 38 58.583 9168.51 12.45 65.32 8312.91 8371.96 1582.47 2834.12 2015.98 516.08 1948.80 0.89 5976269.67 666409.88 N 70 20 28.868 W 148 38 58.028 9264.40 13.43 69.05 8406.37 8465.42 1597.33 2855.59 2037.24 524.38 1968.60 1.34 5976278.40 666429.48 N 70 20 28.950 W 148 38 57.450 9359.53 14.48 69.86 8498.69 8557.74 1613.84 2878.53 2060.07 532.43 1990.08 1.12 5976286.91 666450.78 N 70 20 29.029 W 148 38 56.822 9454.80 14.06 71.17 8591.02 8650.07 1631.03 2902.01 2083.48 540.26 2012.22 0.56 5976295.23 666472.74 N 70 20 29.106 W 148 38 56.176 SurveyEditor Ver SP 2.1 Bld( users) E-05\E-05\E-056\E-05B Generated 4/30/2009 12:49 PM Page 3 of 5 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North ft de de ft ft ft ft ft ft ft de 1100 ft ftUS ftUS ~JD4`J ./~J l4. Ll 0/. 86 6083. 14 B/4L. ly IOY/./G L~LA. LU LIVV. 7/ VYO. JO GUJJ. 7Y V.OV V7/OJVJ. OL 7" @ 9669'md 9603 .65 12. 97 67. 63 8735. 49 8794. 54 1656 .57 2937. 86 2119. 12 553. 17 2045. 65 2.30 5976308. 86 Inc+Trend 9670 .22 12. 83 64. 41 8800. 38 8859. 43 1666 .62 2952. 72 2133. 80 559. 20 2059. 23 1.10 5976315. 20 9681 .64 14. 49 63. 86 8811. 47 8870. 52 1668 .37 2955. 41 2136. 45 560. 38 2061. 65 14.58 5976316. 43 MWD+IFR+MS 9714 .39 21. 54 62. 47 8842. 60 8901. 65 1674 .82 2965. 53 2146. 36 564. 97 2070. 67 21.57 5976321. 21 9746 .08 29. 80 63. 26 8871. 14 8930. 19 1683 .54 2979. 25 2159. 79 571. 21 2082. 89 26.09 5976327. 72 9778 .01 38. 10 62. 45 8897. 60 8956. 65 1694 .84 2997. 07 2177. 23 579. 35 2098. 73 26.03. 5976336. 21 9809 .38 46. 21 61. 66 8920. 84 8979. 89 1707 .96 3018. 10 2197. 77 589. 22 2117. 31 25.91 5976346. 48 9841 .65 54. 97 63. 16 8941. 31 9000. 36 1723 .64 3043. 01 2222. 14 600. 74 2139. 40 27.38 5976358. 48 9873 .62 63. 37 66. 22 8957. 68 9016. 73 1741 .74 3070. 44 2249. 19 612. 43 2164. 20 27.53 5976370. 71 9905 .02 70. 05 69. 26 8970. 09 9029. 14 1761 .88 3099. 26 2277. 83 623. 33 2190. 88 23.05 5976382. 19 9937 .18 75. 83 68. 46 8979. 52 9038. 57 1783 .76 3129. 99 2308. 43 634. 42 2219. 54 18.13 5976393. 91 9967 .37 80. 91 66. 63 8985. 60 9044. 65 1804 .32 3159. 55 2337. 80 645. 71 2246. 86 17.84 5976405. 80 10000 .50 81. 91 65. 89 8990. 55 9049. 60 1826 .59 3192. 31 2370. 27 658. 90 2276. 84 3.74 5976419. 64 10031 .81 81. 50 65. 75 8995. 07 9054. 12 1847 .47 3223. 29 2400. 95 671. 59 2305. 11 1.38 5976432. 94 10064 .35 80. 63 65. 46 9000. 12 9059. 17 1869 .04 3255. 44 2432. 77 684. 87 2334. 38 2.81 5976446. 86 10096 .99 77. 63 66. 43 9006. 28 9065. 33 1890 .69 3287. 49 2464 .54 697. 93 2363. 65 9.64 5976460. 56 10127 .84 79. 59 66. 48 9012. 37 9071. 42 1911 .31 3317. 73 2494. 55 710. 01 2391. 37 6.36 5976473. 25 10160 .14 83. 71 66. 66 9017. 06 9076. 11 1933 .15 3349. 68 2526. 27 722. 72 2420. 69 12.77 5976486. 59 10192 .35 85. 16 66. 14 9020. 18 9079. 23 1955 .00 3381. 74 2558. 10 735. 55 2450. 06 4.78 5976500. 06 10224 .43 90. 59 66 .55 9021. 37 9080. 42 1976 .81 3413. 78 2589 .91 748. 41 2479. 42 16.97 5976513. 56 10256 .02 92. 91 65 .73 9020. 41 9079. 46 1998 .22 3445. 36 2621 .25 761. 18 2508. 29 7.79 5976526. 96 10288 .25 92. 98 65 .84 9018. 75 9077. 80 2019 .89 3477. 54 2653 .17 774. 38 2537. 65 0.40 5976540. 80 10319 .43 93. 63 68 .39 9016. 95 9076. 00 2041 .38 3508. 67 2684 .13 786. 49 2566. 32 8.43 5976553. 53 10351 .56 94. 77 73 .43 9014. 60 9073. 65 2064 .98 3540. 71 2716 .15 796. 96 2596. 59 16.04 5976564. 67 10382 .68 95. 18 73 .19 9011. 90 9070. 95 2088 .69 3571. 72 2747 .15 805. 87 2626. 29 1.53 5976574 .22 10414 .69 93. 09 73 .56 9009. 59 9068. 64 2113 .11 3603. 64 2779 .07 815. 00 2656. 88 6.63 5976584 .03 10446 .78 90. 72 76 .92 9008. 53 9067. 58 2138 .31 3635. 71 2811 .11 823. 17 2687. 89 12.81 5976592 .87 10477 .84 91. 10 76 .51 9008. 03 9067. 08 2163 .20 3666. 77 2842 .10 830. 31 2718. 11 1.80 5976600 .67 10509 .98 92. 64 78 .94 9006. 98 9066. 03 2189 .27 3698. 89 2874 .12 837. 14 2749. 50 8.95 5976608 .18 10542 .13 94. 26 80 .15 9005. 05 9064. 10 2215 .91 3730. 98 2906 .00 842. 96 2781. 06 6.29 5976614 .70 10574 .52 92. 78 80 .98 9003. 06 9062 .11 2243 .06 3763. 31 2938 .06 848. 26 2812. 95 5.24 5976620 .70 10605 .78 90. 02 84 .78 9002. 30 9061 .35 2269 .96 3794. 56 2968 .87 852. 13 2843. 95 15.02 5976625 .25 10638 .20 90. 62 87 .81 9002. 12 9061 .17 2298 .80 3826. 98 3000 .46 854. 23 2876 .30 9.53 5976628 .05 10669 .69 91 .06 88 .93 9001. 65 9060 .70 2327 .32 3858. 46 3030 .90 855. 12 2907 .77 3.82 5976629 .64 10701 .47 90 .51 91 .43 9001. 22 9060 .27 2356 .50 3890. 24 3061 .37 855. 02 2939 .54 8.05 5976630 .23 10733 .49 89 .62 93 .35 9001. 18 9060 .23 2386 .38 3922. 26 3091 .73 853. 69 2971 .53 6.61 5976629 .60 10765 .63 89 .69 95 .89 9001. 38 9060 .43 2416 .80 3954. 40 3121 .82 851. 10 3003 .57 7.91 5976627 .71 10797 .17 89 .01 97 .24 9001. 73 9060 .78 2446 .98 3985. 94 3151 .01 847. 49 3034 .90 4.79 5976624 .80 10828 .87 88 .31 97 .82 9002. 47 9061 .52 2477 .45 4017. 63 3180 .17 843. 34 3066 .31 2.87 5976621 .33 10861 .08 86 .61 102 .67 9003. 90 9062 .95 2508 .77 4049 .80 3209 .21 837. 62 3097 .97 15.94 5976616 .31 OOVY.7Y.L0 IV / V LV L.7.IOV VV IYO JO :1:1.JY i '. 666505.88 N 70 20 29.233 W 148 38 55.199 ~I 666519.32 N 70 20 29.292 W 148 38 54.802 666521.72 N 70 20 29.304 W 148 38 54.731 666530.64 N 70 20 29.349 W 148 38 54.468 666542.71 N 70 20 29.410 W 148 38 54.111 666558.37 N 70 20 29.490 W 148 38 53.648 666576.73 N 70 20 29.587 W 148 38 53.105 666598.55 N 70 20 29.700 W 148 38 52.460 666623.09 N 70 20 29.815 W 148 38 51.735 666649.52 N 70 20 29.922 W 148 38 50.956 666677.93 N 70 20 30.031 W 148 38 666704.99 N 70 20 30.142 W 148 38 49.320 666734.68 N 70 20 30.272 W 148 38 48.444 666762.66 N 70 20 30.397 W 148 38 47.619 666791.63 N 70 20 30.527 W 148 38 46.763 666820.60 N 70 20 30.656 W 148 38 45.908 666848.05 N 70 20 30.774 W 148 38 45.098 666877.08 N 70 20 30.899 W 148 38 44.242 666906.17 N 70 20 31.025 W 148 38 43.383 666935.23 N 70 20 31.152 W 148 38 42.526 666963.81 N 70 20 31.277 W 148 38 41.682 666992.87 N 70 20 31.407 W 148 38 40.825 667021.27 N 70 20 31.526 W 148 38 39.987 667051.30 N 70 20 31.629 W 148 38 39.102 667080.80 N 70 20 31.716 W 148 38 38.235 667111.18 N 70 20 31.806 W 148 38 37.341 667141.99 N 70 20 31.886 W 148 38 36.435 ', 667172.05 N 70 20 31.956 W 148 38 ~2 667203.28 N 70 20 32.023 W 148 38 5 667234.70 N 70 20 32.080 W 148 38 33.713 667266.46 N 70 20 32.132 W 148 38 32.782 667297.37 N 70 20 32.170 W 148 38 31.876 667329.66 N 70 20 32.191 W 148 38 30.931 667361.10 N 70 20 32.200 W 148 38 30.011 667392.87 N 70 20 32.198 W 148 38 29.083 667424.88 N 70 20 32.185 W 148 38 28.149 667456.96 N 70 20 32.160 W 148 38 27.213 667488.36 N 70 20 32.124 W 148 38 26.298 667519.86 N 70 20 32.083 W 148 38 25.380 667551.63 N 70 20 32.027 W 148 38 24.455 SurveyEditor Ver SP 2.1 Bld( users) E-05\E-05\E-05B\E-05B Generated 4/30/2009 12:49 PM Page 4 of 5 Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub•Sea ND TVD Closure DLS Northing Easting Latitude Longitude Depth Ttie Section Departure True North True North ft de de ft ft ft ft ft ft ft de 1700 ft ftUS ftUS 10892.27 87.39 102.67 9005.54 9064.59 2539.37 4080.95 3236.79 830.79 3128.36 2.50 5976610.15 667582.16 N 70 20 31.959 W 148 38 23.568 10924.67 87.39 103.30 9007.01 9066.06 2571.20 4113.32 3265.44 823.51 3159.90 1.94 5976603.57 667613.85 N 70 20 31.888 W 148 38 22.646 10955.57 88.25 103.99 9008.19 9067.24 2601.62 4144.19 3292.67 816.23 3189.90 3.57 5976596.94 667644.00 N 70 20 31.816 W 148 38 21.770 10987.85 90.89 105.23 9008.43 9067.48 2633.51 4176.47 3320.95 808.09 3221.13 9.04 5976589.49 667675.40 N 70 20 31.736 W 148 38 20.858 11019.63 93.34 104.04 9007.26 9066.31 2664.89 4208.23 3348.83 800.07 3251.86 8.57 5976582.14 667706.29 N 70 20 31.657 W 148 38 19.960 11052.06 92.23 103.67 9005.68 9064.73 2696.83 4240.62 3377.55 792.31 3283.31 3.61 5976575.08 667737.90 N 70 20 31.580 W 148 38 19.042 11083.48 90.22 105.54 9005.01 9064.06 2727.87 4272.03 3405.27 784.39 3313.70 8.74 5976567.83 667768.46 N 70 20 31.502 W 148 38 18.154 11115.49 90.72 104.31 9004.75 9063.80 2759.52 4304.04 3433.50 776.14 3344.63 4.15 5976560.27 667799.56 N 70 20 31.421 W 148 38 17.250 11146.86 89.14 105.38 9004.78 9063.83 2790.54 4335.41 3461.26 768.11 3374.95 6.08 5976552.90 667830.05 N 70 20 31.342 W 148 38 16.365 11178.83 89.21 105.32 9005.24 9064.29 2822.19 4367.37 3489.47 759.65 3405.78 0.29 5976545.11 667861.05 N 70 20 31.259 W 148 38 15.464 11211.14 89.32 105.66 9005.66 9064.71 2854.18 4399.68 3518.01 751.02 3436.91 1.11 5976537.17 667892.37 N 70 20 31.174 W 148 38 1~ 11242.81 90.17 106.24 9005.80 9064.85 2885.58 4431.35 3545.93 742.31 3467.36 3.25 5976529.14 667923.00 N 70 20 31.088 W 148 38 1 11274.50 90.69 105.00 9005.56 9064.61 2916.97 4463.04 3574.02 733.78 3497.88 4.24 5976521.28 667953.69 N 70 20 31.004 W 148 38 12.774 11306.69 90.82 105.62 9005.14 9064.19 2948.84 4495.23 3602.69 725.28 3528.92 1.97 5976513.46 667984.92 N 70 20 30.920 W 148 38 11.867 11338.11 88.03 106.64 9005.45 9064.50 2980.00 4526.64 3630.52 716.56 3559.10 9.45 5976505.40 668015.28 N 70 20 30.834 W 148 38 10.986 Last Survey 11387.28 88.39 107.36 9006.99 9066.04 3028.83 4575.79 3673.83 702.19 3606.10 1.64 5976492.07 668062.57 N 70 20 30,693 W 148 38 9.613 TD (Projected) 11440.00 88.39 107.36 9008.47 9067.52 3081.23 4628.49 3720.28 686.46 3656.40 0.00 5976477.45 668113.20 N 70 20 30.538 W 148 38 8.144 Survey Type: Definitive Survey NOTES: CB GYRO MS - (Camera-based gyro multishot -- Traditional optically referenced gyro surveys run on wireline - including "level rotor" gyros and Sperry-Sun SU3. Replaces ex-BP "PGMS" model. ) INC+Trend - (Inclinometer + known azi trend --Inclination only surveys in near-vertical hole-where formation dip and experience enables direction of drift to be predicted. Replaces ex-BP "Inclinometer (azimuth in known quadrant)" model. ) MWD + IFR + MS - (In-field referenced MWD with mutt-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Le~tal Description: Northin~t IY1 fftUS] Eastinst IXl fftUSl Surface : 3926 FSL 502 FEL S6 T11 N R14E UM 5975711.00 664473.00 BHL : 4612 FSL 2123 FEL S5 T11 N R14E UM 5976477.45 668113.20 • SurveyEditor Ver SP 2.1 Bld( users) E-05\E-05\E-05B\E-056 Generated 4/30/2009 12:49 PM Page 5 of 5 TREE = 4" CAMERON WELLHEAD = ACTUATOR - KB. ELEV - 26.82 BF. ELEV = 30.75 KOP = 5500' Max Angle = 95 @ 10383' Datum MD = 9670 Datum TVD = 8800' SS 20", 94#, H-40, CONDUCTOR 106' ID = 19.124" 11-3/4" x 9-5/8" THERMOCASE II 160' 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 2844' Minimum ID = 3.725" @ 9505' XN NIP KOP-Top of whipstock ~ 5500' 9-5/8" EZSV 5524' Jet Cut 5995' Tubing punch 8348' Toc - 8352 4-1/2" OTIS X NIPPLE, ID = 3.813" 8458' 8517' 4-1/2" BAKER PBR SEAL ASSY 8526' 9-5/8" X 4-1/2" BAKER FHL PKR, ID = 4.0" TOP OF 7" LNR 8552' 9368' I-i4-1/2" HES X NIP, ID = 3.813" 9399' ~ 7" x 4-1/2" BKR S-3 PKR 9433' 4-1/2" HES X NIP, ID = 3.813" 9505' 4-1/2" HES XN NIP, ID = 3.725" 9506' Hanger /liner top packer 9518' 4-1/2" WLEG 9518' 4-1/2" TBG, 12.6#, 13CRTCII, TOP OF 2-7/8" LNR 8604' .0152 pbf, ID = 3.958" 9670' 7" CSG 26# L-80 BTGM 9-5/8" CSG, 47#, L-80, ID = 8.681" 9057' I 11159' I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" TD I 11440' I S OTES: ***4-1 /2" CHROMETBG*** 1998' I-14-1/2" X-NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 3486 6193 3481 5782 12 34 KBG2 KBG2 DOME SO BK BK 15 20 04/22/09 04/22/09 PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 94 @ 10330' Note: SIZE SPF INTERVAL Opn/Sqz DATE 2.88 6 10330-10400 04/08/09 2.88 6 10510-10640 04/08/09 2.88 6 10870-10910 04/08/09 2.88 6 10970-11080 04/08/09 2.88 6 11130-11200 04/08/09 2.88 6 11260-11350 04/08/09 DATE REV BY COMMENTS DATE REV BY COMMENTS 04/26/76 ORIGINAL COMPLETION 01/10/89 RWOCOMPLETION 05/19/99 CTD SIDETRACK (E-05A) 04/10/09 N7ES SIDETRACK (E-05B) 04/16/09 TLH CORRECTIONS 04/22/09 SEW/TLH GLV C/O PRUDHOE BAY UNIT WELL: E-056 PERMff No: API No: 50-029-20197-02 SEC 5, T11 N, R14E, 1353' FNL & 502' FEL BP Exploration (Alaska) E-O5B } ~ SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ..................... Prudhoe Bay Well ...................... E-05B API number ................ 50-029-20197-02 Engineer .................: B. Warta Rig :...................... Nabors 7E5 STATE :.................... Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 30.89 ft KB above permanent.......: N/A DF above permanent.......: 59.05 ft ----- Vertical section origin---------------- Latitude (+N/S-).......... 0.00 ft Departure (+E/W-)......... 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 68.57 degrees 7-Apr-2009 00:29:22 Page 1 of 7 Spud date ................: 23-Mar-09 Last survey date.......... 06-Apr-09 Total accepted surveys...: 161 MD of first survey.......: 0.00 ft MD of last survey........: 11440.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2008 Magnetic date ............: 28-Mar-2009 Magnetic field strength..: 57708.61 GAMA Magnetic dec (+E/W-)...... 22.81 degrees Magnetic dip .............: 80.95 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G ............... H ............... Dip ............. of G............ of H...........: of Dip.........: Criteria --------- 1002.68 meal 57708.50 GAMA 80.95 degrees (+/-) 2.50 meal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-)...... 22.81 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)..... 22.81 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction r 1 LJ • [(c)2009 IDEAL ID14 OC 07] SCHLUMBERGER Survey Report 7-Apr-2009 00:29:22 Page 2 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (f t) (ft) (f t) (ft) (deg) 100f) type (de g) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 BP_ UNKNOWN 2 2.45 0.00 180.00 2.45 2.45 0.00 0.00 0.00 0.00 0.00 0.00 BP_ LTNKNOWN 3 29.05 0.00 0.00 26.60 29.05 0.00 0.00 0.00 0.00 0.00 0.00 BP_ LTNKNOWN 4 102.45 0.20 187.58 73.40 102.45 -0.06 -0.13 -0.02 0.13 187.58 0.27 BP_ CB GYRO MS 5 202.45 0.33 190.65 100.00 202.45 -0.30 -0.58 -0.09 0.59 189.08 0.13 BP CB GYRO MS 6 302.45 0.12 162.94 100.00 302.45 -0.46 -0.97 -0.12 0.97 186.83 0.23 BP_ CB GYRO MS 7 402.45 0.33 192.27 100.00 402.45 -0.63 -1.35 -0.15 1.36 186.19 0.23 BP CB GYRO MS 8 502.45 0.33 210.14 100.00 502.45 -1.01 -1.88 -0.35 1.91 190.61 0.10 _ BP_ CB GYRO MS • 9 602.45 0.35 177.83 100.00 602.44 -1.34 -2.43 -0.48 2.48 191.28 0.19 BP CB GYRO MS 10 702.45 0.17 187.28 100.00 702.44 -1.51 -2.88 -0.49 2.93 189.68 0.18 BP CB GYRO MS 11 802.45 0.25 150.78 100.00 802.44 -1.55 -3.22 -0.40 3.25 187.15 0.15 BP_ CB GYRO MS 12 902.45 0.18 134.22 100.00 902.44 -1.46 -3.52 -0.19 3.53 183.01 0.09 BP_ CB GYRO MS 13 1002.45 0.17 279.81 100.00 1002.44 -1.52 -3.61 -0.22 3.61 183.48 0.33 BP_ CB GYRO MS 14 1102.45 0.33 200.17 100.00 1102.44 -1.84 -3.85 -0.46 3.88 186.88 0.34 BP_ CB GYRO MS 15 1202.45 0.18 189.96 100.00 1202.44 -2.11 -4.28 -0.59 4.32 187.87 0.16 BP CB GYRO MS 16 1302.45 0.03 111.83 100.00 1302.44 -2.18 -4.44 -0.59 4.48 187.62 0.18 BP_ CB GYRO MS 17 1402.45 0.18 16.98 100.00 1402.44 -2.06 -4.30 -0.52 4.33 186.94 0.18 BP_ CB GYRO MS 18 1502.45 0.25 335.04 100.00 1502.44 -1.97 -3.95 -0.57 3.99 188.20 0.17 BP_ CB GYRO MS 19 1602.45 0.32 45.18 100.00 1602.44 -1.73 -3.56 -0.46 3.59 187.43 0.33 BP_ CB GYRO MS 20 1702.45 0.17 36.65 100.00 1702.44 -1.35 -3.24 -0.18 3.25 183.13 0.15 BP CB GYRO MS 21 1802.45 0.25 87.93 100.00 1802.43 -1.02 -3.12 0.13 3.12 177.62 0.20 BP_ CB GYRO MS 22 1902.45 0.83 94.56 100.00 1902.43 -0.16 -3.16 1.07 3.34 161.33 0.58 BP_ CB GYRO MS 23 2002.45 1.07 105.52 100.00 2002.42 1.24 -3.47 2.69 4.39 142.22 0.30 BP_ CB GYRO MS • 24 2102.45 1.42 60.70 100.00 2102.39 3.21 -3.12 4.67 5.62 123.70 1.00 BP_ CB GYRO MS 25 2202.45 1.33 46.15 100.00 2202.37 5.51 -1.71 6.59 6.81 104.51 0.36 BP CB GYRO MS 26 2302.45 1.33 31.80 100.00 2302.34 7.51 0.09 8.04 8.04 89.39 0.33 BP_ CB GYRO MS 27 2402.45 1.05 30.09 100.00 2402.32 9.16 1.86 9.11 9.30 78.43 0.28 BP_ CB GYRO MS 28 2502.45 0.32 15.50 100.00 2502.31 10.04 2.93 9.64 10.08 73.12 0.74 BP_ CB GYRO MS 29 2602.45 0.07 7.58 100.00 2602.31 10.24 3.26 9.72 10.26 71.49 0.25 BP_ CB GYRO MS 30 2702.45 0.05 5.07 100.00 2702.31 10.29 3.36 9.74 10.30 70.96 0.02 BP CB GYRO MS [(c)2009 IDEAL ID14 OC 07] SCHLUMBERGER Survey Report 7-Apr-2009 00:29:22 Page 3 of 7 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ------- ------- Displ --------- --------- Displ ------- ------- Total -------- -------- At ----- ----- DLS - - ---- ------ ---- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (f t) ------ (ft) -------- (f t) -------- (ft) ------- (ft) --------- (ft) ------- (deg) -------- 100f) ----- - type (deg) ---- ------ --- 31 -------- 2802.45 ------ 0.15 ------- 85.25 ------ 100.00 -------- 2802.31 -------- 10.44 ------- 3.41 --------- 9.87 ------- 10.44 -------- 70.92 ----- 0.15 - BP ---- _CB --- GYRO --- MS 32 2902.45 0.65 97.33 100.00 2902.31 11.06 3.35 10.56 11.08 72.39 0.50 BP _CB GYRO MS 33 3002.45 2.85 97.05 100.00 3002.25 13.74 2.97 13.59 13.92 77.66 2.20 BP _CB GYRO MS 34 3102.45 4.83 97.13 100.00 3102.02 19.62 2.15 20.24 20.35 83.94 1.98 BP _CB GYRO MS 35 3202.45 5.72 94.29 100.00 3201.60 27.81 1.25 29.39 29.41 87.56 0.93 BP _CB GYRO MS 36 3302.45 8.58 94.06 100.00 3300.81 39.04 0.35 41.80 41.80 89.52 2.86 BP _CB GYRO MS 37 3402.45 10.90 101.66 100.00 3399.37 53.70 -2.09 58.50 58.54 92.04 2.65 BP CB GYRO MS 38 3502.45 12.60 106.11 100.00 3497.27 70.27 -7.03 78.24 78.56 95.13 1.93 BP _ _CB GYRO MS • 39 3602.45 14.33 107.84 100.00 3594.52 88.50 -13.84 100.50 101.45 97.84 1.78 BP _CB GYRO MS 40 3702.45 17.07 109.04 100.00 3690.78 109.25 -22.43 126.16 128.14 100.08 2.76 BP CB GYRO MS 41 3802.45 19.43 109.74 100.00 3785.74 132.94 -32.83 155.70 159.12 101.91 2.37 BP _CB GYRO MS 42 3902.45 22.58 109.52 100.00 3879.09 159.96 -44.87 189.46 194.70 103.32 3.15 BP _CB GYRO MS 43 4002.45 25.67 109.74 100.00 3970.34 190.78 -58.60 227.95 235.36 104.42 3.09 BP _CB GYRO MS 44 4102.45 28.87 111.06 100.00 4059.22 224.89 -74.60 270.87 280.96 105.40 3.26 BP _CB GYRO MS 45 4202.45 30.33 111.71 100.00 4146.16 261.12 -92.61 316.86 330.12 106.29 1.49 BP CB GYRO MS 46 4302.45 31.00 112.42 100.00 4232.18 298.11 -111.78 364.13 380.90 107.06 0.76 BP _CB GYRO MS 47 4402.45 31.23 112.51 100.00 4317.79 335.35 -131.52 411.88 432.37 107.71 0.23 BP _CB GYRO MS 48 4502.45 32.60 113.31 100.00 4402.67 373.16 -152.11 460.57 485.04 108.28 1.43 BP _CB GYRO MS 49 4602.45 33.10 113.95 100.00 4486.68 411.47 -173.85 510.27 539.07 108.81 0.61 BP _CB GYRO MS 50 4702.45 34.07 114.15 100.00 4569.99 450.26 -196.40 560.78 594.18 109.30 0.98 BP CB GYRO MS 51 4802.45 34.67 114.15 100.00 4652.53 489.77 -219.49 612.29 650.45 109.72 0.60 BP _CB GYRO MS 52 4902.45 35.83 113.61 100.00 4734.19 530.36 -242.85 665.07 708.02 110.06 1.20 BP _CB GYRO MS 53 5002.45 36.67 113.12 100.00 4814.84 572.32 -266.30 719.35 767.06 110.31 0.89 BP _CB GYRO MS 54 5102.45 37.75 113.38 100.00 4894.48 615.32 -290.17 774.91 827.46 110.53 1.09 BP _CB GYRO MS 55 5202.45 37.67 113.00 100.00 4973.59 658.85 -314.26 831.13 888.56 110.71 0.25 BP CB GYRO MS 56 5302.45 37.68 113.51 100.00 5052.74 702.31 -338.39 887.29 949.62 110.88 0.31 BP _CB GYRO MS 57 5402.45 37.17 113.40 100.00 5132.15 745.37 -362.58 943.04 1010.34 111.03 0.51 BP _CB GYRO MS 58 5502.45 36.87 114.01 100.00 5212.00 787.84 -386.78 998.17 1070.49 111.18 0.47 BP _CB GYRO MS 59 5508.00 36.87 113.99 5.55 5216.44 790.18 -388.14 1001.21 1073.81 111.19 0.22 BP _CB GYRO MS 60 5525.00 37.80 111.00 17.00 5229.95 797.60 -392.08 1010.73 1084.12 111.20 11.99 BP BLI ND [(c)2009 IDEAL ID14 OC 07] SCHLLTMBERGER Survey Report 7-Apr-2009 00:29:22 Page 4 of 7 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ------- ------- Displ --------- --------- Displ ------- ------- Total -------- -------- At ----- ----- DLS - - ---- ------ ---- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- 61 -------- 5537.31 ------ 36.89 ------- 111.00 ------ 12.31 -------- 5239.74 -------- 803.12 ------- -394.76 --------- 1017.70 ------- 1091.58 -------- 111.20 ----- 7.39 - BP ---- ------ _INC+TREND 62 5632.79 35.20 111.00 95.48 5316.94 844.58 -414.89 1070.15 1147.76 111.19 1.77 BP _INC+TREND 63 5727.97 33.82 111.00 95.18 5395.37 884.38 -434.21 1120.49 1201.69 111.18 1.45 BP _INC+TREND 64 5823.45 33.85 111.00 95.48 5474.68 923.62 -453.27 1170.13 1254.85 111.17 0.03 BP _MWD+IFR+MS 65 5919.82 32.89 108.00 96.37 5555.16 963.65 -470.97 1220.07 1307.82 111.11 1.98 BP MWD+IFR+MS 66 6015.95 32.77 103.00 96.13 5635.96 1005.27 -484.89 1270.26 1359.66 110.89 2.82 BP _MWD+IFR+MS 67 6110.79 34.84 98.17 94.84 5714.77 1050.01 -494.52 1322.10 1411.55 110.51 3.58 BP MWD+IFR+MS 68 6206.85 34.07 92.47 96.06 5794.00 1098.48 -499.58 1376.15 1464.03 109.95 3.45 BP _ _MWD+IFR+MS • 69 6302.70 34.27 87.57 95.85 5873.32 1148.56 -499.59 1429.95 1514.71 109.26 2.88 BP _MWD+IFR+MS 70 6398.43 34.52 81.35 95.73 5952.34 1200.51 -494.37 1483.71 1563.90 108.43 3.68 BP MWD+IFR+MS 71 6414.47 34.36 80.14 16.04 5965.57 1209.38 -492.91 1492.66 1571.94 108.27 4.38 BP _MWD+IFR+MS 72 6494.00 33.72 71.89 79.53 6031.50 1253.42 -482.20 1535.78 1609.70 107.43 5.86 BP _MWD+IFR+MS 73 6589.18 33.24 57.51 95.18 6111.02 1305.48 -459.94 1582.97 1648.43 106.20 8.33 BP _MWD+IFR+MS 74 6684.59 32.53 44.73 95.41 6191.24 1354.67 -427.63 1623.13 1678.51 104.76 7.30 BP _MWD+IFR+MS 75 6780.15 33.70 33.88 95.56 6271.34 1400.01 -387.33 1656.02 1700.71 103.16 6.32 BP MWD+IFR+MS 76 6876.69 35.63 24.95 96.54 6350.80 1442.42 -339.56 1682.83 1716.75 101.41 5.62 BP _MWD+IFR+MS 77 6972.00 38.32 16.45 95.31 6426.98 1480.70 -286.01 1702.93 1726.78 99.53 6.06 BP _MWD+IFR+MS 78 7066.14 39.56 6.56 94.14 6500.28 1512.72 -228.17 1714.63 1729.74 97.58 6.73 BP _MWD+IFR+MS 79 7162.80 38.72 359.82 96.66 6575.28 1538.13 -167.34 1718.05 1726.18 95.56 4.48 BP _MWD+IFR+MS 80 7258.33 37.88 358.30 95.53 6650.25 1558.86 -108.14 1717.09 1720.49 93.60 1.32 BP MWD+IFR+MS 81 7354.87 36.71 358.33 96.54 6727.05 1578.63 -49.67 1715.37 1716.08 91.66 1.21 BP _MWD+IFR+MS 82 7448.22 38.65 359.25 93.35 6800.93 1598.35 7.37 1714.17 1714.19 89.75 2.16 BP _MWD+IFR+MS . 83 7545.33 37.94 358.13 97.11 6877.14 1619.06 67.54 1712.80 1714.13 87.74 1.02 BP _MWD+IFR+MS 84 7640.29 40.11 358.22 94.96 6950.91 1639.12 127.29 1710.90 1715.63 85.74 2.29 BP _MWD+IFR+MS 85 7736.60 39.18 357.51 96.31 7025.07 1659.43 188.70 1708.61 1719.00 83.70 1.07 BP MWD+IFR+MS 86 7832.12 33.59 5.50 95.52 7101.98 1681.22 245.22 1709.83 1727.33 81.84 7.66 BP _MWD+IFR+MS 87 7927.17 30.21 16.04 95.05 7182.73 1707.70 294.43 1718.97 1744.01 80.28 6.84 BP _MWD+IFR+MS 88 8022.09 27.11 17.93 94.92 7266.01 1735.95 337.97 1732.23 1764.89 78.96 3.40 BP _MWD+IFR+MS 89 8117.67 19.92 19.05 95.58 7353.59 1760.37 374.13 1744.27 1783.94 77.89 7.54 BP _MWD+IFR+MS 90 8212.56 16.92 29.33 94.89 7443.64 1781.57 401.46 1756.31 1801.61 77.12 4.65 BP _MWD+IFR+MS [(c)2009 IDEAL ID14 OC 07] • SCHLUMBERGER Survey Report 7-Apr-2009 00:29:22 Page 5 of 7 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ------- ------- Displ --------- --------- Displ ------- ------- Total -------- -------- At ----- ----- DLS - - ---- ------ ---- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (f t) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ------- (ft) --------- (ft) ------- (deg) -------- 100f) ----- - type (deg) ---- ------ --- 91 -------- 8308.13 ------ 16.31 ------- 46.82 ------ 95.57 -------- 7535.27 -------- 1804.82 ------- 422.78 --------- 1772.92 ------- 1822.63 -------- 76.59 ----- 5.25 - BP ---- ------ _MWD+IFR+MS 92 8403.88 15.69 56.48 95.75 7627.33 1829.97 439.13 1793.52 1846.50 76.24 2.85 BP _MWD+IFR+MS 93 8499.93 13.44 63.56 96.05 7720.29 1853.79 451.28 1814.35 1869.63 76.03 2.98 BP _MWD+IFR+MS 94 8594.79 11.67 62.91 94.86 7812.88 1874.32 460.55 1832.76 1889.74 75.89 1.87 BP _MWD+IFR+MS 95 8691.38 12.79 64.48 96.59 7907.28 1894.71 469.61 1851.11 1909.75 75.76 1.21 BP _MWD+IFR+MS 96 8786.96 14.00 64.59 95.58 8000.26 1916.80 479.13 1871.10 1931.47 75.64 1.27 BP _MWD+IFR+MS 97 8882.63 13.50 64.46 95.67 8093.18 1939.48 488.91 1891.63 1953.79 75.51 0.52 BP MWD+IFR+MS 98 8976.99 12.18 65.05 94.36 8185.18 1960.40 497.86 1910.59 1974.39 75.39 1.41 BP _ _MWD+IFR+MS • 99 9073.92 13.23 63.86 96.93 8279.74 1981.66 507.06 1929.82 1995.32 75.28 1.12 BP _MWD+IFR+MS 100 9168.51 12.45 65.32 94.59 8371.96 2002.63 516.08 1948.80 2015.98 75.17 0.89 BP MWD+IFR+MS 101 9264.40 13.43 69.05 95.89 8465.42 2024.09 524.38 1968.60 2037.24 75.08 1.34 BP _MWD+IFR+MS 102 9359.53 14.48 69.86 95.13 8557.74 2047.03 532.43 1990.08 2060.07 75.02 1.12 BP _MWD+IFR+MS 103 9454.80 14.06 71.17 95.27 8650.07 2070.49 540.26 2012.22 2083.48 74.97 0.56 BP _MWD+IFR+MS 104 9549.79 14.21 67.88 94.99 8742.19 2093.68 548.38 2033.94 2106.57 74.91 0.86 BP _MWD+IFR+MS 105 9603.65 12.97 67.63 53.86 8794.54 2106.33 553.17 2045.65 2119.12 74.87 2.30 BP _MWD+IFR+MS 106 9670.22 12.83 64.41 66.57 8859.43 2121.17 559.20 2059.23 2133.80 74.81 1.10 BP _INC+TREND 107 9681.64 14.49 63.86 11.42 8870.52 2123.86 560.38 2061.65 2136.45 74.79 14.58 BP _INC+TREND 108 9714.39 21.54 62.47 32.75 8901.65 2133.94 564.97 2070.67 2146.36 74.74 21.57 BP _MWD+IFR+MS 109 9746.08 29.80 63.26 31.69 8930.19 2147.59 571.21 2082.89 2159.79 74.66 26.09 BP _MWD+IFR+MS 110 9778.01 38.10 62.45 31.93 8956.65 2165.31 579.35 2098.73 2177.23 74.57 26.03 BP _MWD+IFR+MS 111 9809.38 46.21 61.66 31.37 8979.89 2186.21 589.22 2117.31 2197.77 74.45 25.91 BP _MWD+IFR+MS 112 9841.65 54.97 63.16 32.27 9000.35 2210.98 600.74 2139.40 2222.14 74.32 27.38 BP _MWD+IFR+MS 113 9873.62 63.37 66.22 31.97 9016.73 2238.34 612.43 2164.20 2249.19 74.20 27.53 BP _MWD+IFR+MS • 114 9905.02 70.05 69.26 31.40 9029.14 2267.16 623.33 2190.88 2277.83 74.12 23.06 BP _MWD+IFR+MS 115 9937.18 75.83 68.46 32.16 9038.57 2297.89 634.42 2219.54 2308.43 74.05 18.13 BP MWD+IFR+MS 116 9967.37 80.91 66.63 30.19 9044.65 2327.44 645.71 2246.86 2337.80 73.97 17.84 BP _MWD+IFR+MS 117 10000.50 81.91 65.89 33.13 9049.60 2360.17 658.90 2276.84 2370.27 73.86 3.74 BP _MWD+IFR+MS 118 10031.81 81.50 65.75 31.31 9054.12 2391.12 671.59 2305.11 2400.95 73.76 1.38 BP _MWD+IFR+MS 119 10064.35 80.63 65.46 32.54 9059.17 2423.22 684.87 2334.38 2432.77 73.65 2.81 BP _MWD+IFR+MS 120 10096.99 77.63 66.43 32.64 9065.33 2455.24 697.93 2363.65 2464.54 73.55 9.64 BP _MWD+IFR+MS [(c)2009 IDEAL ID14 OC 07] SCHLUMBERGER Survey Report 7-Apr-2009 00:29:22 Page 6 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (f t) (deg) (deg) (f t) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 121 10127.84 79.59 66.48 30.85 9071.42 2485.46 710.01 2391.37 2494.55 73.46 6.36 BP _MWD+IFR+MS 122 10160.14 83.71 66.66 32.30 9076.11 2517.39 722.72 2420.69 2526.27 73.38 12.77 BP _MWD+IFR+MS 123 10192.35 85.16 66.14 32.21 9079.23 2549.42 735.55 2450.06 2558.10 73.29 4.78 BP _MWD+IFR+MS 124 10224.43 90.59 66.55 32.08 9080.42 2581.44 748.41 2479.42 2589.91 73.20 16.97 BP _MWD+IFR+MS 125 10256.02 92.91 65.73 31.59 9079.46 2612.99 761.18 2508.29 2621.25 73.12 7.79 BP MWD+IFR+MS 126 10288.25 92.98 65.84 32.23 9077.80 2645.14 774.38 2537.65 2653.17 73.03 0.40 BP _MWD+IFR+MS 127 10319.43 93.63 68.39 31.18 9076.00 2676.25 786.49 2566.32 2684.13 72.96 8.43 BP _MWD+IFR+MS 128 10351.56 94.77 73.43 32.13 9073.65 2708.26 796.96 2596.59 2716.15 72.94 16.04 BP _MWD+IFR+MS 129 10382.68 95.18 73.19 31.12 9070.95 2739.16 805.87 2626.29 2747.15 72.94 1.53 BP _MWD+IFR+MS 130 10414.69 93.09 73.56 32.01 9068.64 2770.97 815.00 2656.88 2779.07 72.95 6.63 BP MWD+IFR+MS 131 10446.78 90.72 76.92 32.09 9067.57 2802.82 823.17 2687.89 2811.11 72.97 12.81 BP _MWD+IFR+MS 132 10477.84 91.10 76.51 31.06 9067.08 2833.56 830.31 2718.11 2842.10 73.01 1.80 BP _MWD+IFR+MS 133 10509.98 92.64 78.94 32.14 9066.03 2865.27 837.14 2749.50 2874.12 73.07 8.95 BP _MWD+IFR+MS 134 10542.13 94.26 80.15 32.15 9064.10 2896.77 842.96 2781.06 2906.00 73.14 6.29 BP _MWD+IFR+MS 135 10574.52 92.78. 80.98 32.39 9062.11 2928.40 848.26 2812.95 2938.06 73.22 5.24 BP MWD+IFR+MS 136 10605.78 90.02 84.78 31.26 9061.34 2958.67 852.13 2843.95 2968.87 73.32 15.02 BP _MWD+IFR+MS 137 10638.20 90.62 87.81 32.42 9061.16 2989.55 854.23 2876.30 3000.46 73.46 9.53 BP _MWD+IFR+MS 138 10669.69 91.06 88.93 31.49 9060.70 3019.17 855.12 2907.77 3030.90 73.61 3.82 BP _MWD+IFR+MS 139 10701.47 90.51 91.43 31.78 9060.27 3048.71 855.02 2939.54 3061.37 73.78 8.05 BP _MWD+IFR+MS 140 10733.49 89.62 93.35 32.02 9060.23 3078.00 853.69 2971.53 3091.73 73.97 6.61 BP MWD+IFR+MS 141 10765.63 89.69 95.89 32.14 9060.42 3106.87 851.10 3003.57 3121.82 74.18 7.91 BP _MWD+IFR+MS 142 10797.17 89.01 97.24 31.54 9060.78 3134.72 847.49 3034.90 3151.01 74.40 4.79 BP _MWD+IFR+MS 143 10828.87 88.31 97.82 31.70 9061.52 3162.45 843.34 3066.31 3180.17 74.62 2.87 BP _MWD+IFR+MS 144 10861.08 86.61 102.67 32.21 9062.95 3189.83 837.62 3097.97 3209.21 74.87 15.94 BP _MWD+IFR+MS 145 10892.27 87.39 102.67 31.19 9064.58 3215.62 830.79 3128.36 3236.79 75.13 2.50 BP MWD+IFR+MS 146 10924.67 87.39 103.30 32.40 9066.06 3242.32 823.51 3159.90 3265.44 75.39 1.94 BP _MWD+IFR+MS 147 10955.57 88.25 103.99 30.90 9067.23 3267.59 816.23 3189.90 3292.67 75.65 3.57 BP _MWD+IFR+MS 148 10987.85 90.89 105.23 32.28 9067.48 3293.69 808.09 3221.13 3320.95 75.92 9.04 BP _MWD+IFR+MS 149 11019.63 93.34 104.04 31.78 9066.30 3319.35 800.07 3251.86 3348.83 76.18 8.57 BP _MWD+IFR+MS 150 11052.06 92.23 103.67 32.43 9064.73 3345.80 792.31 3283.31 3377.55 76.43 3.61 BP MWD+IFR+MS • C~ [(c)2009 IDEAL ID14 OC 07] SCHLUMBERGER Survey Report 7-Apr-2009 00:29:22 Page 7 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/w- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 151 11083.48 90.22 105.54 31.42 9064.05 3371.20 784.39 3313.70 3405.27 76.68 8.74 BP _MWD+IFR+MS 152 11115.49 90.72 104.31 32.01 9063.79 3396.97 776.14 3344.63 3433.50 76.94 4.15 BP _MWD+IFR+MS 153 11146.86 89.14 105.38 31.37 9063.83 3422.26 768.11 3374.95 3461.26 77.18 6.08 BP _MWD+IFR+MS 154 11178.83 89.21 105.32 31.97 9064.29 3447.87 759.65 3405.78 3489.47 77.43 0.29 BP _MWD+IFR+MS 155 11211.14 89.32 105.66 32.31 9064.70 3473.69 751.02 3436.91 3518.01 77.67 1.11 BP MWD+IFR+MS 156 11242.81 90.17 106.24 31.67 9064.84 3498.86 742.32 3467.36 3545.93 77.92 3.25 BP _MWD+IFR+MS 157 11274.50 90.69 105.00 31.69 9064.61 3524.15 733.78 3497.88 3574.02 78.15 4.24 BP MWD+IFR+MS 158 11306.69 90.82 105.62 32.19 9064.18 3549.94 725.28 3528.93 3602.69 78.39 1.97 BP _ _MWD+IFR+MS 159 11338.11 88.03 106.64 31.42 9064.50 3574.85 716.56 3559.10 3630.52 78.62 9.45 BP _MWD+IFR+MS 160 11387.28 88.39 107.36 49.17 9066.03 3613.35 702.19 3606.10 3673.83 78.98 1.64 BP MWD+IFR+MS 161 11440.00 88.39 107.36 52.72 9067.52 3654.42 686.46 3656.40 3720.28 79.37 0.00 Projected TD [(c)2009 IDEAL ID14 OC 07] Schlumber er 9 Drilling & Measurements MWD/LWD Log Product Delivery Customer BPXA Dispatched To: Christine Mahnken (AOGCC) Well No E-056 Date Dispatched: 24-Mar-09 Installation/Rig 7ES Dispatched By: Paul Wyman LWD Log Delivery V2.1, 03-06-06 Data No Of Prints No of Floppies Surveys 2 1 Please sign and return to: ,lames H. Jonnson Received By: '~ v-c~.~~ ~~4 BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99506 Fax:907-564-4005 e-mail address: johnsojhC~lbp.com i • Slal~~ 0~ 1~~~~;~ti~C~Gi ALASSA OIL A1~TD GAS CO1~T5ERQA~'IO1~T CODiAII55IO1~ Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU E-05B BP Exploration Alaska Inc. Permit No: 209-021 Surface Location: 1353' FNL, 502' FEL, SEC. 06, T11N, R14E, UM Bottomhole Location: 687' FNL, 3067' FWL, SEC. 05, T11N, R14E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). SincerelyQ T Cathy . Foerster ~. Com 'ssioner DATED this ~J day of February, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~}, ~~ STATE OF ALASKA ~,~iG'v -^~~cQ' ~y~i/'~1"-~(~ ALAS~OIL AND GAS CONSERVATION COMMON ~ ~~~r~ ~~~~ ,~;~_~~ PERMIT TO DRILL FEB ~- 2o AAC 2s.oos ~~"~~~ . n r~P t`nns. liommisstinn 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone ~8S i w ~tsgposed for: ^ Coal a ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU E-05B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11233' TVD 9074' 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028304 Oil Pool 1353 FNL, 502 FEL, SEC. O6, T11 N, R14E, UM Top of Productive Horizon: 813' FNL, 1504' FWL, SEC. 05, T11 N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: March 8, 2009 Total Depth: 687' FNL, 3067' FWL, SEC. 05, T11N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 6,100' 4b. Location of Well (State Base Plane Coordinates): Surface: x-664473 y-5975711 Zone-ASP4 10. KB Elevation Plan ~ (Height above GL): ~ feet 15. Distance to Nearest Well within Pool: 1,~' 16. Deviated Wells: Kickoff Depth: 5500 feet Maximum Hole An le: 90 d rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3866 Surface: 2991 1 in Pr r m: S ecificatio n T in De th - o om n ' of m n .f. r s ks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data -1/2" 7" 26# -80 BT -M 4161' S 11' 804' 84 i e r e 1 7 ' 1/8" 4-1/ " 12. L- 0 IBT-M 1 7 ' 9361' 8 11 9 74' 75 las ' 19. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 11226' Total Depth TVD (ft): Plugs (measured): 8991' None Effective Depth MD (ft): 11159' Effective Depth TVD (ft): 8992' Junk (measured): None Casing Len th Size Cement Volume MD TV Conductor /Structural ~ 1 ' Surface 244' 1 8" 4 P rm fr ' Intermediate 9 57' 1 90 7' 19 ' P Liner 11 T' ft ' - 96 1' 77 1' - 73 ' finer 2 22' -7/ " 1 la ' - 112 77 ' - 1' Perforation Depth MD (ft): 10106' - 11100' Perforation Depth TVD (ft): 898T - 8991' 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that th for oing is true and correct. Contact Jovy Roach, 564-4352 Printed Name Gr Title Engineering Team Leader Prepared By Name/Number: Si nature Phone 564-4191 Date 2 d 6 Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill N mb r. 0~0 Oo?/ API Number: 50-029-20197-02-00 Permit Approval See cover letter for p e: L ' D th r it ments Conditions of Approval: ~ e-r,,~ If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ,._/ ~vl~ ~"'~ ~ ~+l-~~~~•- Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes tss No H S Measures: ~ ~~~~~~ ~\ ~,~,~~~,~,~4n~v~~- ~.~~~,~ z G~Yes ^ No Directional Survey Req'd: Cd~Yes ^ No Other: ~~~~~~ ~-~~ o~ ~-.~ ~ c~cC~'~E.+.~`rc ~ ~ O ~~~.~J.C:~~~ ~,~~~~~ APPROVED BY THE COMMISSION Date ~ ~ ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ .p ~ ~ ~ ~ ~ / Submit In Duplicate t; E J ~'i% ,r`, ` ", ~~ dw ~« I~ To: Alaska Oil & Gas Conservation Commission From: Jovy Roach, ODE Date: February 9, 2009 Re: E-05B Sidetrack Permit to Drill The E-05B well is scheduled to be drilled by Nabors Rig 7ES which is currently scheduled to move onto the location ~ March 8, 2009. The plan is to exit the parent E-05A wellbore from the 9-5/8" casing at ~ 5500' MD with an 8-1/2" BHA. The 8-1/2" hole will then be drilled to the top of the Sag River formation where a 7" liner will be run and fully cemented with 150' of liner lap. A 6-1/8" hole will then be drilled building to horizontal in the Ivishak Zone 2. The planned well then runs horizontally for approximately 1000' to a final well TD at 11,233' MD. A solid 4- 1/2" production liner will be run, cemented in place, and perforated on drillpipe. A 4-1/2" completion will be run. Well History: At current operating conditions the well is uncompetitive and receives very little on-time. All producible sands have been accessed up to 20' tvd below the GOC. With gas so close to open perforations and no available gas shut off options it has been determined that this well is ready for sidetrack. Due to the high cement top in the well it has been eliminated as a CST option and a RST provides us with an opportunity to bring an additional wellbore into the E/K Graben. Please note the following Well Summary as detailed on the next few pages. E-05B Permit to Drill Application Page 1 Planned Well Summary Horizontal Well E-05B Type Sidetrack Objective Zone 2 Producer API Number: 50-029-20197-xx Current Status E-05A Shut-in Estimated Start Date: 8-Mar-2009 Time to Com lete: 22 Da s Surface Northin Eastin Offsets TRS Location 5,975,711 664,473 1353' FNL / 4387' FWL 11 N, 14E, 6 Northin Eastin Target 5,976,295 666,465 Locations 5.976.580 667.111 TVDss Offsets TRS -8575 813' FNL / 1504' FWL 11 N, 14E, 5 -9015 543' FNL / 2157' FWL 11 N, 14E, 5 Bottom Northin Eastin TVDss Offsets TRS Location 5,976,456 668,024 -9015 687' FNL / 3067' FWL 11 N, 14E, 5 Planned KOP: 5500'MD / 5151'TVDss Planned TD: 11233'MD / 9015' TVDss Rig: Nabors 7ES KBE: 28.5' BFE: 30.0' Directional - Schlumberger (P4) KOP: 5500' MD Maximum Hole Angle: 38.8° in the 8-1/2" intermediate section 90.0° in the 6-1 /8" roduction section Close Approach Wells: All wells except K-106 pass major risk criteria for close approach. K-10 V1 is the closest well at 519' ctr-ctr with -55' of allowable deviation at planned depth of 11079' MD. K-10B and all associated plugbacks pass minor risk at 1:200. Surve Pro ram: MWD Standard + IFR / MS Nearest Pro ert Line: 6,100' (North) to the PBU property line Nearest Well within Pool: E-01A at 1066' Contacts Drilling Engineer Geologist Pad Engineer Name Phone # Jovy Roach 564-4352 Doug Stoner 564-5652 Jacki Randall 564-4590 E-mail iovy. roach @ bp.com cole.abelC«~bp.com iacki.randall C«~ bp.com E-05B Permit to Drill Application Page 2 Formation Markers (Based on SOR) Estimated Formation To s Formation TVDss Planned MD SVl -4135 UG4 -4600 UG3 -4870 UGl -5378 5779 WS2 -5951 6429 WSl -6155 6662 CM3 -6332 6872 CM2 -7302 8026 CMl ` -7447 8177 THRZ -7548 8280 BHRZ -7775 8514 TJF -7876 8617 TJE -7990 8734 TJD -8264 9016 TJC -8420 9176 TJB -8556 9316 TSGR -8746 9511 TSHA -8798 9566 TSAD -8845 9618 TCGL -8943 9749 BCGL -8986 9833 fault (into Z2B1) HOT 21TS -9002 -9015 -9024 9881 10300 Casina/Tubina Proaram Hole Size Csg / Tb O.D. Wt/Ft Grade Conn Burst si Collapse si Length Top MD /TVDrkb Bottom MD /TVDrkb 8-'/z" 7" 26# L-80 BTC-M 7,240 5,410 4161' 5350' / 5090' 9511' / 8804' 6-1 /8" 4'/z" 12.6# L-80 IBT-M 7,500 8,430 1872' 9361' / 8659' 11233' / 9074 Tubin 4'/z" 12.6# 13Cr-80 Vam To 10,160 10,530 9349' Surface 9349' / 8650' E-05B Permit to Drill Application Page 3 Mud Proaram Whi stock Millin Mud Pro erties: LSND Whip Stock Window 9-5/8", 47# Densit PV YP API FL HTHP FL MBT PH 9.0 16-30 30-35 <6.0 N/C N/C 9.0-10 Intermediate Mud Pro erties: LSND 8-1/2" hole section Depth Interval Density (ppg) PV YP API FL HTHP FL MBT PH 5500' - 8080' 9.0 - 9.5 10-18 20-30 <6.0 N/C <12 9.0-10 8080'- 9511' HRZ to Sa 9 9 12-22 20-25 4.0-6.0 <10.0 <15 9.0-10 Production Mud Pro erties: FLOPRO SF Reservoir Drill-in Fluid 6-1/8" hole section De th Interval Densit PV YP LSVR API FI H MBT 9511' -11233' 8.4 - 8.5 8-12 22-28 >20,000 6.0-8.0 9.0-9.5 < 3 Loaaina Proaram 8-1/2" Intermediate: Sample Catchers - as required by Geology Drillin Dir/GR/Res/PWD Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - as required by Geology Drillin Dir/GR/Res/Neu/Den Open Hole: None Cased Hole: None Cement Proaram Casin Size: 7" 26#, L-80 Intermediate Liner Basis: Lead: 3011' of 7" x 8-1 /2" o en hole + 40% excess 150' of liner la + 200' DP excess Tail: 1000' of 7" x 8-1/2" open hole with 40% excess, plus 80' shoe track Tail TOC: 8511' MD Total Cement Volume: Spacer 30 bbls of Viscosified Spacer @ 10.5 ppg (Mud Push II) Lead 104 bbls, 584 cu ft, 175 sks, 11.0 Lite Crete, Yield = 3.33 cuft/sk Tail 35 bbls, 197 cu ft, 167 sks 15.8 Class G, Yield = 1.16 cuft/sk Tem BHST = 194° F at TOC, BHCT TBD b Schlumber er Casin Size 4.5" 12.6#, L-80 Production Liner Basis: Lead: None Tail: 1722' of open hole with 40% excess, 80' shoe track, 150' 4-'/2" x 6-1/8" liner lap, and 200' of 7" x 4" DP excess. Tail TOC: 9361' MD (TOL) Total Cement Volume• Spacer 30 bbls of Viscosified Spacer @ 12.0 ppg (Mud Push II) Lead None Tail 49 bbls, 275 cuft, 237 sks 15.8 Ib/ al Class G, Yield = 1.16 cuft/sk Tem BHST = 195° F, BHCT TBD b Schlumber er E-056 Permit to Drill Application Page 4 Surface and Anti-Collision Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. At surface E-01 to the north and E-101 to the south are nearest at 100' and 50' centers, respectively. Close Approach Shut-in Wells: All wells except K-10B and its associated plugbacks pass major risk criteria. All K-10 wellbores pass minor risk at 1:200. K-10 V1 is the closest well at 519' ctr-ctr distance with -55 ft of allowable deviation at a planned depth of 11079' MD. See TCR worksheet for reference. Hydrogen Sulfide B-Pad is not designated as an H2S site. Recent H2S data from the pad is as follows: Date of Wr.ll Name N2C T,vvPl RParlinu Parent Well #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Other Relevant H2S Data E-OSA 10 m 9/17/2000 E-101 36 m 10/2/2008 E-OlA 10 m 4/18/2008 E-34 14 m 8/28/2008 E-38 7 m 3/31/2008 E-1.02 120 m 911.6/2008 E-pad is not a high H2S pad but has high H2S on Midnight Sun E100 series wells. Note: E-OS surface location is next to E-101. Faults The proposed E-05B well lies in a low risk province of the field for lost circulation at faults as documented by the WURD team. Eleven loss circulation events were encountered in the Kingak and Ivishak sections in 10 of the surrounding 27 wells (37%), as detailed below. Eight of these were in the lowermost Kingak (associated with faults) and the Sag River (not associated with faulting). The wellplan is specifically designed to avoid crossing any faults until the intermediate casing string is set at top Sag River. For this purpose, the target size for the Sag River intermediate target is 75 feet. A Kingak age fault will be crossed in the Shublik interval near 9500 ft MD. Loss circulation risk at this fault is moderate and costs are included. The planned well drops in over the top of a large fault that helps to form the southern boundary of the E-K graben, and then turns and parallels this fault, staying about 325 feet north of it. Landing at this point, however, causes the well to cross another northeast-southwest trending fault in upper Zone 2 near 9800 ft MD. Additional faults are present in the Kingak 185 feet south of the well and in Zone 2 about 350 feet beyond the end of the planned well. Polygon lines are hardlines on all sides except the North side and the well cannot be extended beyond the end of the polygon. Loss Circulation Events Well Type Loss (bbl) MD SSTVD Formation Fault? E-02 Rig 200 9100 -8198 Kingak Yes (cementing) E-09 Rig 50 10234 -8342 Kingak Yes (conditioning) E-11 A Rig 100 10975 -8566 Kingak Yes (cementing) E-12 Rig 100 8815 -8673 Sag River No (casing) E-16 Rig 380 8777 -8711 Sag River No E-26A Rig 733 9690 -8729 Sag River No E-29 Rig 1000 11161 -8404 Kingak No (casing) E-34 Rig 30 9715 -8684 Sag River No (tripping) K-07C Rig 13 10820 -8834 Zone 1 Yes (perfing) K-19 Rig 30 8605 -8526 Zone 4 No K-19 Rig 20 9245 -8911 Zone 1 Yes (casing) E-05B Permit to Drill Application Page 5 Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP regular test frequency for N-18A will be 14 days during drilling phase and 7 days during decompletion and surface casing work. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum antici ated BHP 3866 si @ 8746' TVDss 8.5 EMW Maximum surface ressure 2991 si .10 si/ft as radient to surface 74 bbl over 10.3 ppg LOT assuming 8.5 pore pressure, 9.9 mud weight, Kick tolerance and 4" drill i e Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin Test 3500 si surface ressure Inte rit Test - 8-1/2" hole FIT/LOT after drillin 20' from middle of window Production Interval Maximum antici ated BHP 3300 si C~ 8800' TVDss 7.2 EMW Maximum surface ressure 2420 si .10 si/ft as radient to surface Kick tolerance Infinite with a 8.8 FIT Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin "Liner Test 3500 si surface ressure Inte rit Test - 6-1/8" hole FIT/LOT after drillin 20' of new hole Planned com letion fluids 8.5 Seawater / 7.2 Diesel Other Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20 AAC 25.285 (f) {1) regarding the initial testing of the BOPE as follows when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the three-ram drilling BOP stack. Disposal No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject (GNI) at DS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: All Class II liquid waste (including drilling muds and/or brines that have been downhole) are to be hauled to GNI at DS-04 for injection. For the disposal of Class I wastes, contact the GPB Environmental Advisors (659-5893) for the appropriate disposal method at Pad 3 or GNI. NOTE: Generally, Class I solids will be directed to the GNI on DS-04 and Class I liquids will be directed to Pad 3. E-05B Permit to Drill Application Page 6 i ~ Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Ivishak in this fault block is expected to be under-pressured at 7.2 ppg EMW, based on offset well pressures. All casing strings will be tested to 3500 psi, in accordance with the RP for Prudhoe production well casing tests. II. Lost Circulation /Faults The proposed E-05B well lies in a low risk province of the field for lost circulation at faults as documented by the WURD team. Eleven loss circulation events were encountered in the Kingak and Ivishak sections in 10 of the surrounding 27 wells (37%), as detailed below. Eight of these were in the lowermost Kingak (associated with faults) and the Sag River (not associated with faulting). The wellplan is specifically designed to avoid crossing any faults until the intermediate casing string is set at top Sag River. For this purpose, the target size for the Sag River intermediate target is 75 feet. A Kingak age fault will be crossed in the Shublik interval near 9500 ft MD. Loss circulation risk at this fault is moderate and costs are included. The planned well drops in over the top of a large fault that helps to form the southern boundary of the E-K graben, and then turns and parallels this fault, staying about 325 feet north of it. Landing at this point, however, causes the well to cross another northeast-southwest trending fault in upper Zone 2 near 9800 ft MD. Additional faults are present in the Kingak 185 feet south of the well and in Zone 2 about 350 feet beyond the end of the planned well. Polygon lines are hardlines on all sides except the North side and the well cannot be extended beyond the end of the polygon. III. Kick Tolerance /Integrity Testing A. The Kick Tolerance for the intermediate section is 74 bbl and that for the production section is infinite with planned mud weights. The FIT/LOTs will prove up adequate formation strength for expected ECD's. B. Integrity Testing Test Point Test De th Test tyke EMW Ib/ al 9 5/8' window 20-ft minimum from the 9 5/8° window LOT 10.3 minimum 7" shoe 20-ft minimum from the 7" shoe FIT 8.8 minimum IV. Stuck Pipe A. Hole cleaning and differential sticking tendency will be of concern. Watch for signs of tight hole and short trip /back ream as required to avoid stuck pipe. VI. Hydrogen Sulfide A. E-PAD is not designated as an H2S site, although high H2S levels have been recorded on the Midnight Sun E100 series well. Note: Surface location of the planned well E-058 is next to Midnight Sun well E- 101. The maximum recorded level on this pad is 120 ppm on E-102 on 9/16/2008. VII. Anti-Collision Issues A. All wells except K-10B and its associated plugbacks pass major risk criteria. All K-10 wellbores pass minor risk at 1:200. K-10 V1 is the closest well at 519' ctr-ctr distance with -55 ft of allowable deviation at a planned depth of 11079' MD. See TCR worksheet for reference. CONSULT THE E-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION E-056 Permit to Drill Application Page 7 Operations Summary Scope of Worts. - Cut and pull existing 4-1/2" completion between the production packer and the sliding sleeve. - Run USIT log on 9-5/8" casing. - Cut and pull 9-5/8" casing. Run new 9-5/8" casing with casing patch and cement to surface. Replace 9-5/8" packoff. - Run new 4-1/2" 13-CR80 tubing with stacker packer completion. Notify the field AOGCC representative with intent to plug and abandon. Pre-Riq Work: F 1 Perform in'ectivit test. DONE 1/10/09 F 2 Pending infectivity results, bullhead P & A the perforations in the E-05B wellbore with 15.8 ppg - 7 bbl Class G cement. Min TOC at 10,000' MD, max TOC is 8525' MD. Test to 2500 si. S 3 Drift for 'et cut, to TOC, MIT to 2500 si. E/F 4 A) Log GR from 9500' MD to surface. B) Punch tubing at ~ 8478' MD in the middle of the first full joint above the X nipple. Reference tubing tally 1-10-89. C) Circulate the well to seawater through the tubing cut. D) Freeze protect the IA and tubing with diesel to -2,200'. E) Jet cut the 4-1/2", 12.6#, L-80 tubing in the middle of a full joint at ~ 6000' MD. F) CMIT-TxIA to 3500 psi for 30 min. MIT-OA (13-3/8" surface casing) to 2000 psi for 30 min. Bleed all casin and annulus ressures to zero. W 5 PPPOT - IC 9-5/8" 5,000 si, PPPOT-T 4-1/2" 5,000 si. Function all lock-down screws. W 6 Set BPV in tubin han er. Secure well. O 7 Remove well house. Level the ad. Provide total well re cost on the handover form. Riq Operations: 1. MI / RU. Pull BPV. 2. Circulate out diesel freeze protection and displace the well to seawater. Install TWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull TWC. 4. MIT-OA to 2000 psi for 30 min charted. 5. R/U. RIH and pull 4'h" tubing. ~p~6. MU 8-1/2" clean-out assembly and clean-out the 9-5/8" casing down to the top of tubing stub. °°'3p~ 7. With E-line, set 9-5/8" EZSV to allow fora 5500' MD whip-stock KOP (max hole angle 37.68 degrees at 5300' MD). Pressure test casing. 8. With EZSV as barrier, change-out 9-5/8" pack-offs (pull pack-offs thru BOP stack if possible). Test packoff. 9. P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whipstock and set on EZSV. Shear off of whi -stock. ----- isp ace t e we I to L ND milling fluid. Mill the window and 20' new formation. Perform LOT. 11. RIH w/ 8'/2" DIR/GR/Res drilling assembly and drill to top Sag River. Weight up as necessary for shale stability in the Kingak and HRZ. 12. Short trip to window. Circulate, POH. 13. Run and cement 7" 26# L-80 BTC-M drilling liner. ~~~ 14. RIH with build section BHA: 6-1/8" bit /motor assembly with GR/Res/Den/Neu to landing collar. 15. Test liner and casing to 3500 psi. Drill shoe tract. !~'`~ 16. Displace the well to 8.4 ppg Flo-Pro SF drilling fluid. Drill 20' formation; perform FIT. 17. Drill ahead ~ 900' building to horizontal landing point at - 10300 MD in Zone 2. POOH for bit and BHA change. 18. MU 6-1/8" BHA with DIR/GR/RES/NEU/DEN. RIH and MAD pass build section. Drill ahead - 900' in the horizontal as per plan to estimated TD of --11206'MD. 19. Circulate, short trip, spot liner running pill, POOH. 20. Run and cement a 4'h", 12.6#, L-80 IBT-M solid production liner through the 6-1/8" hole section and 150' into the 7" intermediate casing. Set liner top packer and displace well to clean seawater above the liner top. Test liner to 3500 psi for 30 min charted. Note: A perf pill will be left in the 4-1/2"liner. E-05B Permit to Drill Application Page 8 ~ ~ 21. RIH with DPC pert guns. Perf intervals to be determined from LWD logs. Plan to perforate overbalanced, ~ 800' of perfs. POOH, LD DP and pert guns. 22. R/U and run 4 1/2", 12.6#, 13-Cr-80 VamTop completion tubing. Land tubing, RILDS. 23. Reverse circulate inhibited seawater to the packer depth. 24. Drop ball & rod and set packer and individually test the tubing and annulus to 3,500 psi 30 minutes. Record each test. 25. Shear the DCK valve and pump each way to confirm shear. 26. Set a TWC and test to 1000 psi. 27. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. Pull TWC w/lubricator. 28. Freeze protect the well to 2,200' 29. Install BPV and secure the well. RDMO. Post-Rig Work: 1. Install well house and instrumentation. 2. Pull BPV. 3. Slickline pull ball and rod / RHC plug from landing nipple below the production packer. 4. Slickline Install gas lift valves. Estimated Pre-rig Start Date: 2/8/2009 Estimated Spud Date: 3/8/2009 Drilling Engineer: Jovy Roach (907) 242 - 6259 Production Engineer: Jacki Randall (907) 564 - 4590 Geologist: Doug Stoner (907) 564 - 5652 ATTACH: Current Schematic Proposed Schematic E-05B Permit to Drill Application Page 9 TREE _ 6" CMJ Wl3LHEAD = MCEVOY ACtUATOR= OTIS KB. ELEV = 56.56' BF. ELEV = 28.3' KOP = 3400' 'Max Angle = 95 @ 10477 Datum MD = 9848' Datum TV D = 8800' SS I 13-3/8" CSG, 72#, L-80, ID = 12.347" I Minimum ID = 2.37" @ 8604' TOP 2-7/8" LNR E-OSA C 2056' I-I4-1/2" CAMCO SSSV LANDING NIP, ID = 3.813" $45~-i4-1/2" OTIS X NIPPLE, ID = 3.813" 8517 4-1/2" BAKER PBR SEAL ASSY 8526' I-I9-518" X 4-1/2" BAKER FHL PKR, ID = 4.0" I TOP OF 7" LNR I OF 2-7/8" LNR i--i $~' I 9-5/8" CSG, 47#, L-80, ID = 8.681" I TOP OF WHIPSTOCK I-i 9691' 3819' I 4-1/2" OTC XA SLIDING SLV, ID = 3.813" (BEHIND 2-7/8" LNR) MILLOUT WINDOW THROUGH BOTH 7" 8 4-1/2" FROM 9691' - 9715' 9705' HWHIPSTOCK PKR 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 9970 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10089' PERFORATION SUMMARY REF LOG: SPERRY SUN NM/D-GR ON 05/17/99 ANGLEATTOPPERF:71 @ 10106' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2 4 10106 - 10156 O 01 /22/04 2 4 10170 - 10250 O 05/20/99 2 4 10340 - 10439 O 05/20/99 2 4 10490 - 10660 O 05/20/99 2 4 10720 - 11000 O 05/20/99 2 4 11050 - 11100 O 05/20/99 9820' I-iCIBP PBTD ~- j 11159' ~ 2-7/8" LNR, 6.16#, L-80 STL, .00579 bpf, ID = 2.441" 11226' DATE REV BY COMMENTS DATE REV BY COMMENTS 04/26/76 ORIGINAL COMPLETION 11/02/07 JSR~fLH PERF CORRECTIONS (1999) 05119/99 SIDETRACKCOMPLETION 07/16/01 RN/TP CORRECTIONS 07/11/03 CMO/TLP MAX ANGLE CORRECTION 09/17/03 CMO/TLP PERF ANGLE CORRECTION 01/22/04 KCF/KK ADPERF PRUDHOE BAY UNff WELL: E-05A PERMff No: 1990300 API No: 50-029-20197-01 SEC 5, 711 N, R14E, 1353' FNL & 502' FEL BP 6cploration (Alaska) TREE= 4"CAMERON WB.LHEAD = MCEVOY ACfiUATOR = _OTIS KB. ELEV = 56.56' BF. ELEV = 28.3' KOP = 5500' Max Angle = 90 ~ 10291' Datum MD = 9555' Datum TV D = 8800' SS Proposed E-05B S NOTES: ~4-1/2" X-NIP, ID = 3.813" ~ Minimum ID = 3.725" a~ xxxx' XN NIP KOP -Top of w hipstock 5500' 9-5/8" EZSV 5524' 13-318" CSG, 72#, L-80, ID = 12.34T' 2844' 5350' Hanger /liner top packer Jet Cut 6000' 9192' 4-1/2" HES X NIP, ID = 3.813" 4-1/2" OTIS X NIPPLE, ID = 3.813" 8458' 8252' 7" x 4-1/2" BKR S-3 PKR Tubing punch $478' 0000 m 9279' 4-1/2" HES X NIP, ID = 3.813" 851T 4-1/2" BAKER PBR SEAL ASSY 9339' 4-1/2" HES XN NIP, ID = 3.725" 9349' WLEG 8526' 9-5/8" X 4-1 /2" BAKER FHL PKR, ID = 4.0" 9349' 4-1/2" TBG, 12.6# 13Cr-80 TOP OF 7" LNR 8552' ' 9361' Hanger /liner top packer 9511' 7" CSG 26# L-80 BTGM TOP OF 2-7/8" LNR $604' ,. 9-5/8" CSG, 47#, L-80, ID = 8.681" 9057' Banned TOC 10,000' PBTD 11159' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: SIZE SPF INTERVAL Opn/Sqz DATE 11233' 4-1/2" LNR, 12.6#, L-80 IBT-M DATE REV BY COMMENTS DATE REV BY COMMENTS 04126/76 ORIGINAL COMPLETION fl1;10i8fl f7`JV~„ ~;OMPLEfION fl511999 CT's "5I;IETRACK 01/28/09 JER Proposed ST PRUDHOE BAY UNff WELL: E-OSB PERMff No: API No: 50-029-20197-02 SEC 5, T11 N, R14E, 1353' FNL & 502' FEL BP Exploration (Alaska) by . Schlumberger E-05B (P4) Proposal Report Date: January 22, 2009 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 68.570° Field: Structure 1 Slot: Prudhoe Bay Unit - WOA E-PAD / E-05 ~ ~~ ~y Vertical Section Origin: TVD Reference Datum: N 0.000 ft, E 0.000 ft Rotary Table Well: E-05 ~ ''~ TVD Reference Elevation: 58.5 ft relative to MSL Borehole: Plan E-05B ~;~' ~a Sea Bed 1 Ground Level Elevation: 30.000 ft relative to MSL UWIIAPI#: 500292019702 Magnetic Declination: 22.810° Survey Name 1 Date: E-056 (P4) I January 22, 2009 Total Field Strength: 57707.209 nT Tort 1 AHD I DDI 1 ERD ratio: 248.673° 14329.86 ft / 6.125 10.477 Magnetic Dip: 80.945° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: March 25, 2009 Location LaUlong: N 70.33994309, W 148.66526563 Magnetic Declination Model: BGGM 2008 Location Grid WE YIX: N 5975711.000 ftUS, E 664473.000 ftUS North Reference: True NoAh Grid Convergence Angle: +1.25695225° Total Corr Mag North -> True North: +22,810° Grid Scale Factor: 0.99993073 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting La titude Lo ngitude Depth Section Tool Face Difficulty ft d de ft ft ft ft ft de de 1100 8 Index ftUS ftUS fie-In Survey 5401.90 37.17 113.40 5073.10 5131.60 745. 37 -362.58 943.04 129.47R 0.51 4.71 5975369. 22 665423.70 N 70. 33895240 W 148. 6576143E fop Whipstock 5500.00 36.88 114.00 5151.43 5209.93 787. 04 -386.32 997.13 HS 0.47 4.74 5975346. 67 665478.29 N 70. 33888752 W 148. 6571755E 3ase Whipstock 5516.00 38.80 114.00 5164.06 5222.56 793. 93 -390.31 1006.09 --- 12.00 4.76 5975342. 88 665487.34 N 70. 33887661 W 148. 65710281 :rv 4/100 5529.00 38.80 114.00 5174.19 5232.69 799. 65 -393.62 1013.53 134.66E 0.00 4.76 5975339. 73 665494.85 N 70. 33886756 W 148 .65704244 5600.00 36.85 110.63 5230.28 5288.78 831. 07 -410.17 1053.78 132.00E 4.00 4.80 5975324. 07 665535.45 N 70. 33882233 W 148 .6567158E 5700.00 34.28 105.35 5311.64 5370.14 875. 90 -428.20 1109.03 127.70E 4.00 4.86 5975307. 26 665591.07 N 70. 33877307 W 148 .65626771 JG1 5779.43 32.42 100.66 5378.00 5436.50 911. 87 -438.06 1151.54 123.78E 4.00 4.90 5975298. 34 665633.79 N 70. 33874611 W 148. 65592281 5800.00 31.97 99.36 5395.40 5453.90 921 .22 -439.97 1162.33 122.68E 4.00 4.91 5975296. 67 665644.62 N 70. 33874090 W 148 .6558352E 5900.00 29.98 92.62 5481.16 5539.66 966 .80 -445.42 1213.43 116.90E 4.00 4.95 5975292. 34 665695.83 N 70. 33872598 W 148 .6554206:: 6000.00 28.38 85.10 5568.50 5627.00 1012 .42 -444.53 1262.09 110.33E 4.00 5.00 5975294. 30 665744.45 N 70. 33872840 W 148 .6550258E 6100.00 27.23 76.88 5656.99 5715.49 1057 .86 -437.30 1308.06 103.05E 4.00 5.04 5975302. 53 665790.25 N 70. 33874812 W 14 8528E 6200.00 26.59 68.14 5746.20 5804.70 1102 .89 -423.77 1351.13 95.26E 4.00 5.07 5975317. 00 665833.00 N 70. 33878506 W 148 .6 43034 6300.00 26.50 59.19 5835.69 5894.19 1147 .29 -404.00 1391.07 87.25E 4.00 5.11 5975337. 64 665872.50 N 70. 33883905 W 148 .65397931 6400.00 26.97 50.35 5925.04 5983.54 1190 .86 -378.09 1427.71 79.35E 4.00 5.14 5975364. 34 665908.56 N 70. 33890980 W 148 .6536820E NS2 6429.16 27.21 47.84 5951.00 6009.50 1203. 37 -369.40 1437.74 77.12E 4.00 5.15 5975373. 25 665918.39 N 70. 33893354 W 148. 65360064 6500.00 27.96 41.94 6013.80 6072.30 1233 .37 -346.17 1460.85 71.89E 4.00 5.18 5975396 .98 665940.99 N 70. 33899699 W 148 .65341310 6600.00 29.43 34.19 6101.55 6160.05 1274 .63 -308.39 1490.34 65.08E 4.00 5.21 5975435 .39 665969.64 N 70. 33910018 W 148 .65317375 NS1 6661.71 30.55 29.78 6155.00 6213.50 1299. 37 -282.24 1506.65 61.27E 4.00 5.23 5975461. 90 665985.37. N 70. 33917164 W 148. 65304139 6700.00 31.31 27.20 6187.84 6246.34 1314 .42 -264.94 1516.03 59.05E 4.00 5.24 5975479 .40 665994.37 N 70 .33921888 W 148 .6529652E 6800.00 33.53 20.98 6272.28 6330.78 1352 .56 -216.02 1537.80 53.80E 4.00 5.27 5975528 .77 666015.06 N 70 .33935250 W 148 .65278854 ~M3 6872.39 35.30 16.93 6332.00 6390.50 1379. 03 -177.34 1551.05 50.46E 4.00 5.30 5975567. 74 666027.46 N 70. 33945817 W 148. 65268096 6900.00 36.02 15.48 6354.44 6412.94 1388 .86 -161.88 1555.55 49.28E 4.00 5.31 5975583 .29 666031.61 N 70 .33950040 W 148 .6526444£ =nd Crv 6936.95 37.00 13.62 6384.14 6442.64 1401 .77 -140.61 1561.07 --- 4.00 5.32 5975604 .68 666036.66 N 70 .33955853 W 148 .65259961 :rv 4/100 7472.95 37.00 13.62 6812.24 6870.74 1587 .01 172.86 1637.03 159.04R 0.00 5.39 5975919 .71 666105.73 N 70 .34041484 W 148 .6519827E 7500.00 35.99 14.28 6833.98 6892.48 1596 .32 188.47 1640.91 158.51 R 4.00 5.40 5975935 .40 666109.26 N 70 .34045748 W 148 .6519512 i WeIlDesign Ver SP 2.1 Bld( doc40x 100) E-05\E-05\Plan E-05B\E-056 (P4) Generated 1/22/2009 8:49 AM Pape 1 of 2 Comments Measured Depth (ft) Inclination (deg) Azimuth (deg) SuaSea TVD (ft) TVD (ft) Vertical Section (ft) NS Ift) EW (ft) Mag 1 Grav Tool Face (deg) DLS (deg1100ft) Directional Difficulty Index Northing (ftUS) Easting (ftUS) Latitude Longitude 7600.00 32. 29 17.02 6916 .74 6975. 24 1630.10 242.50 1655 .98 156.24R 4.00 5.43 5975989. 75 666123 .15 N 70. 34060509 W 148 .6518288E 7700.00 28. 67 20.38 7002 .91 7061. 41 1662.71 290.55 1672 .16 153.35R 4.00 5.45 5976038. 14 666138 .27 N 70. 34073635 W 148 .6516974E 7800.00 25. 16 24.60 7092 .07 7150. 57 1694.02 332.39 1689 .37 149.58R 4.00 5.48 5976080. 34 666154 .55 N 70. 34085062 W 148 .6515577E 7900.00 21. 80 30.06 7183 .79 7242. 29 1723.85 367.79 1707 .53 144.57R 4.00 5.50 5976116. 13 666171 .93 N 70. 34094734 W 148 .6514103E 8000.00 18. 67 37.32 7277 .62 7336 .12 1752.08 396.60 1726 .54 137.76R 4.00 5.52. 5976145. 35 666190 .30 N 70. 34102604 W 148 .65125607 :M2 8025.68 17. 93 39.56 7302. 00 7360. 50 1759.05 402.92 1731. 55 135.63R 4.00 5.52 5976151. 78 666195. 17 N 70. 34104329 W 148. 65121542 8100.00 15. 93 47.15 7373 .11 7431 .61 1778.55 418.68 1746 .31 128.37R 4.00 5.54 5976167. 85 666209 .58 N 70. 34108633 W 148 .65109551 ~M1 8176.52 14. 23 56.96 7447. 00 7505. 50 1797.55 430.95 1761. 90 118.90R 4.00 5.55 5976180. 47 666224. 90 N 70. 34111985 W 148. 65096907 8200.00 13. 80 60.40 7469 .78 7528 .28 1803.15 433.91 1766 .76 115.55R 4.00 5.55 5976183. 53 666229 .69 N 70. 34112793 W 148 .6509296E =nd Crv 8235.48 13. 25 66.00 7504 .28 7562 .78 1811.40 437.65 1774 .15 --- 4.00 5.56 5976187. 43 666237 .00 N 70. 34113815 W 148 .6508696° rHRZ 8280.39 13. 25 66.00 7548. 00 7606. 50 1821.68 441.84 1783. 55 -- 0.00 5.56 5976191. 83 666246. 31 N 70. 34114958 W 148. 9334 3HRZ 8513.60 13. 25 66.00 7775. 00 7833. 50 1875.08 463.58 1832. 39 -- 0.00 5.57 5976214. 63 666294. 65 N 70. 34120894 W 148 .9707 rJF 8617.37 13. 25 66.00 7876. 00 7934. 50 1898.84 473.26 1854. 11 - 0.00 5.57 5976224. 78 666316. 15 N 70. 34123536 W 148. 65 22076 rJE 8734.48 13. 25 66.00 7990. 00 8048. 50 1925.65 484.17 1878. 63 -- 0.00 5.58 5976236. 23 666340. 43 N 70. 34126517 W 148. 65002175 rJD 9015.98 13. 25 66.00 8264. 00 8322. 50 1990.11 510.42 1937. 57 - 0.00 5.59 5976263. 76 666398. 77 N 70. 34133682 W 148. 64954343 TJC 9176.24 13. 25 66.00 8420. 00 8478. 50 2026.80 525.36 1971. 13 -- 0.00 5.59 5976279. 43 666431. 99 N 70. 34137761 W 148. 64927110 1-JB 9315.96 13. 25 66.00 8556. 00 8614. 50 2058.79 538.38 2000. 39 -- 0.00 5.60 5976293. 09 666460. 95 N 70. 34141317 W 148. 64903368 .-058 Tgt 1 9335.48 13. 25 66.00 8575 .00 8633 .50 2063.26 540.20 2004 .47 --- 0.00 5.60 5976295. 00 666465 .00 N 70. 34141814 W 148 .64900051 ~" Csg Pt 9511.15 13. 25 66.00 8745. 99 8804. 49 2103.49 556.58 2041. 26 -- 0.00 5.61 5976312. 18 666501. 41 N 70. 34146285 W 148. 64870202 rSAG 9511.16 13. 25 66.00 8746. 00 8804. 50 2103.49 556.58 2041. 26 - 0.00 5.61 5976312. 18 666501. 41 N 70. 34146285 W 148. 64870200 Irv 16.75/100 9516.48 13 .25 66.00 8751 .18 8809 .68 2104.71 557.07 2042 .37 HS 0.00 5.61 5976312 .70 666502 .52 N 70. 34146421 W 148 .6486929E rSHU 9565.58 21. 47 66.04 8798. 00 8856. 50 2119.33 563.02 2055. 75 HS 16.75 5.63 5976318. 94 666515. 76 N 70. 34148045 W 148. 64858441 9600.00 27 .24 66.06 8829 .35 8887 .85 2133.51 568.78 2068 .72 HS 16.75 5.65 5976324 .98 666528 .60 N 70. 34149617 W 148 .64847917 1•SAD 9617.85 30. 23 66.06 8845. 00 8903. 50 2142.08 572.27 2076. 56 HS 16.75 5.66 5976328. 64 666536. 36 N 70. 34150568 W 148. 64841550 9700.00 43 .99 66.08 8910 .35 8968 .85 2191.48 592.32 2121 .75 HS 16.75 5.71 5976349 .67 666581 .10 N 70. 34156043 W 148 .64804874 TCGL 9748.91 52. 18 66.09 8943. 00 9001. 50 2227.81 607.06 2155. 00 HS 16.75 5.74 5976365. 14 666614. 01 N 70. 34160068 W 148. 64777893 9800.00 60 .74 66.09 8971 .20 9029 .70 2270.31 624.30 2193 .89 HS 16.75 5.76 5976383 .23 666652 .51 N 70 .34164775 W 148 .64746331 3CGL 9833.21 66. 30 66.10 8986. 00 9044. 50 2300.00 636.34 2221. 05 HS 16.75 5.78 5976395. 86 666679. 40 N 70. 34168063 W 148. 64724287 ?281 9880.65 74. 25 66.10 9002. 00 9060. 50 2344.58 654.43 2261. 85 HS 16.75 5.81 5976414. 83 666719. 79 N 70. 34172999 W 1481176 9900.00 77 .49 66.10 9006 .72 9065 .22 2363.32 662.03 2279 .00 HS 16.75 5.82 5976422 .81 666736 .77 N 70 .34175074 W 14 725f =nd Crv 9974.49 89 .97 66.11 9014 .84 9073 .34 2437.15 691.96 2346 .57 --- 16.75 5:86 5976454 .22 666803 .66 N 70 .34183246 W 148 .6462242E Irv 10/100 10168.60 89 .97 66.11 9014 .96 9073 .46 2631.08 770.58 2524 .04 89.86R 0.00 5.89 5976536 .71 666979 .35 N 70 .34204709 W 148 .64478394 10200.00 89 .97 69..25 9014 .98 9073 .48 2662.48 782.51 2553 .08 89.86R 10.00 5.90 5976549 .27 667008 .12 N 70 .34207965 W 148 .64454821 10300.00 90 .00 79.25 9015 .00 9073 .50 2761.86 809.62 2649 .20 89.86R 10.00 5.94 5976578 .48 667103 .62 N 70 .34215363 W 148 .64376814 .-056 Tgt 2 10307.54 90 .00 80.00 9015 .00 9073 .50 2769.25 810.98 2656 .62 90.OOR 10.00 5.94 5976580 .00 667111 .00 N 70 .34215733 W 148 .6437079£ 10400.00 90 .00 89.25 9015.00 9073 .50 2858.02 819.64 2748 .57 90.OOR 10.00 5.98 5976590 .67 667202 .74 N 70 .34218089 W 148 .6429617E 10500.00 90 .00 99.25 9015 .00 9073 .50 2948.03 812.24 2848.17 90.OOR 10.00 6.01 5976585 .46 667302 .47 N 70 .34216058 W 148 .6421535E =nd Crv 10522.16 90 .00 101.46 9015 .00 9073 .50 2966.86 808.26 2869 .97 --- 10.00 6.02 5976581 .96 667324 .35 N 70 .34214968 W 148 .6419766£ (D / 4-1/2" Lnr 11233.11 90 .00 101.46 9015.00 9073 .50 3563.84 666.97 3566.74 --- 0.00 6.12 5976456 .00 668024 .00 N 70 .34176288 W 148 .6363231E _eaal Description: Northing IY) IftUSI Eastin~t IX) fftUSl Surface : 3926 FSL 502 FEL S6 T11 N R14E UM 5975711.00 664473. 00 E-05B Tgt 1 : 4466 FSL 3776 FEL S5 T11 N R14E UM 5976295.00 666465. 00 E-056 Tgt 2 : 4737 FSL 3123 FEL S5 T11 N R14E UM 5976580.00 667111. 00 TD / BHL : 4592 FSL 2213 FEL S5 T11 N R14E UM 5976456.00 668024. 00 WeIlDesipn Ver SP 2.1 Bld( doc40x 100) E-05\E-05\Plan E-056\E-056 (P4) Generated 1/22/2009 8:49 AM Page 2 of 2 uN • ~ Schlumberger WELL E-056 (P4) FIELD Prudhoe Bay Unit - WOA STRUCTURE E-PAD Magn .+a a e s ctc r m e.. ~.~ ace I oca ion N4D22 Alaska Stale Planes. Zone 04, US Feet rt t Miscellaneous :- c- ~ti',1.%O XUS Grtl COnv ~12fifi95225' Slot EOfi NDReI: Radry Tabb (3B.50flaDOVe MSL) - - Scak Fad 09999302298 Plen. E-03B (P4t Sevy Data: Janwry 22.2009 600 1200 1800 2400 3000 3600 4800 5400 6000 6600 0 0 C m m ~ 7200 D 7800 8400 9000 -os Tiean Survey Top Whipstock Base Whipstock crv at bo ................<................ .................:..................................:..................................c...................................i..................................i................... _.._.._.._ _ _.._.._.._ ~.r.._.._ _ -.._.._.._.._.._.._.._ _ ._.._.._.._..-..-..-.._ _..-.._.._.._.._.._..-.._ _.._.._.._.._.._.._.._. _ _.._.._.._. a..a..~a..a•.~+v: a•.~a•.~~v: a:~a•.-a•.~r.~a•.:•• ..a..a..a..a..a..a•:{nv:rxav:a•.~s•.~i•.~a•.~a•.~r.>'a•.~a•.~a•.~a•::a•.~~v:av:x:uT'ay~w•.~a•.ti+av:a•.~r.~a•.:~atvi'~ti••": s•.~i•.~a•.~ -..-..-..-..1..-..-..-..-..-..-..-..-.. ~..- .-..-.{-..-..-..-..-..-..-..-..-.y-..-..-..-..-..-..-..-..-1.-..-..-..-..-..-..-..-.. ~..-..-..-..-.. End CN crv atoo .............................................................................. ... '.................................. i.....................................................................i................... -----------y -------------------------~---------------~------~-- ---- ---.._.._.._.._.._.:_.._.._.._.._.._.._.._.._:._.._.._.._.._.._.._.._..~.._.._.._.._.._ ~OSB P4 -05 End Crv i t:nd Crv TD 1 d-1@" Lnr Crv 10N 00 E-056 Tgt 2 4800 5400 6000 6600 7200 7800 8400 9000 600 1200 1800 2400 3000 3600 Vertical Section (ft) Azim = 68.57°, Scale = 1(in):600(ft) Origin = 0 N/-S, 0 E/-V by Schlumherger ~" E-058 (P4) FIELD Prudhoe Bay Unit - WOA STRUCTURE E-PAD Magnetic Pa nrtreters Surface Location NAD3J Ala ske Stele Planes, Zone 00, US Foet Miscellaneous Motlel: BGGM 2008 Dip: 80945' Date: MarcM1 25, 2009 Lat. N)03023.J95 NorlNing: 59JSJ 11.00 ftUS Grd DOnv.+125695225" Slof. E-OS TVO ReI'. Roury TaEle (58.50 X aEOVe MSL) Maq Dec. +33.810' FS 5])012 nT Lon: VaY 48395495fi Eas4nfl: fi644]3.00 flU5 Scale Fad. 0.999930]298 Plan. E-OSB (P4) Brvy Date January 23, 2009 800 1200 1600 2000 2400 2800 3200 3600 800 n n n Z 0 400 0 v c u m U ~ 0 V V V -400 00 1200 1600 2000 2400 2800 3200 3600 «< ~/ Scale = 1(in):400(ft) E »> 800 400 0 -400 BP Alaska . Anticollision Report Company: BP Amoco Date: 1/22/2009 Time: 09:02:49 Page: 1 Field: Prudhoe Bay Reference Site: PB E Pad Co-ordinate(NE) Reference: Well: E-05, True North Reference ~i'ell: E-05 Vertical (TV D) Reference: E-056 Plan 58.5 Reference Wellpath: E-058 Plan __ Db: Oracle _ _ GLOBAL SCAN APPLIED: All wellpath s within 200'+ 100/1000 of reference -There are >[I'@I>t~oeells in thisRliii~lpal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 5500.00 to 11233.11 ft Scan Method: Trav Cylinder North Maximum Radius: 1320.46 ft Erro r Surface: Ellipse + Casing -- _ - - f- Survey Program for Definitive Wellpath - I Date: 1/2 2/2009 Validated: No Version: 2 Planned From To Survey Toolcode Tool N ame ~ ~' ft ft I~ 101.90 5401.90 E-05 Srvy1 CB GYRO MS (101.90- CB-GYRO-MS _ Camera based gyro multishot ~I 5401.90 9511.00 Planned: Plan #4 E-05B V1 MWD+IFR +MS MWD +IFR + Multi Station 9511.00 11233.11 Planned: Plan #4 E-05B V1 MWD+IFR +MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in __ 2844.00 2843.86 13.375 __ 18.500 13 3/8" ~ 5500.00 5209.93 9.625 12.250 9 5/8" i 9511.16 8804.50 7.000 8.500 7" '` 11233.11 9073.50 4.500 6.125 4 112" Summary r <________________-- Offset Wellpath -- -------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB E Pad E-01 E-01 V1 10084.01 9785.00 1038.83 449.84 588.99 Pass: Major Risk 'I PB E Pad E-01 E-01 A V4 10041.96 9520.00 1065.97 421.57 644.39 Pass: Major Risk ~! PB E Pad E-01 E-01AP61 V1 10047.32 9560.00 1065.89 431.08 634.81 Pass: Major Risk PB E Pad E-02A E-02A V2 Out of range '~ PB E Pad E-02APB1 E-02APB1 V6 Out of range PB E Pad E-02 E-02 V1 Out of range PB E Pad E-03 E-03 V3 Out of range PB E Pad E-03 E-03A V3 Out of range PB E Pad E-04A E-04A V3 Out of range I PB E Pad E-04 E-04 V1 Out of range I PB E Pad E-05 E-OS V1 5691.64 5690.00 6.11 303.27 -297.16 FAIL: Major Risk ~, PB E Pad E-05 E-05A V1 5691.64 5690.00 6.11 303.27 -297.16 FAIL: Major Risk '~ PB E Pad E-05 E-05AP61 V1 5691.64 5690.00 6.11 303.27 -297.16 FAIL: Major Risk PB E Pad E-06A E-06A V4 Out of range PB E Pad E-06 E-06 V1 Out of range i ~ PB E Pad E-09 E-09 V3 7193.26 6910.00 1298.54 382.55 915.99 Pass: Major Risk PB E Pad E-09 E-09A V1 7193.40 6915.00 1298.53 382.55 915.99 Pass: Major Risk PB E Pad E-09 E-09AP61 V1 7193.40 6915.00 1298.53 382.55 915.99 Pass: Major Risk PB E Pad E-09 E-096 V5 7193.40 6915.00 1298.53 382.55 915.99 Pass: Major Risk PB E Pad E-101 E-101 V4 Out of range PB E Pad E-103 E-103 V7 Out of range PB E Pad E-103 E-103P61 V15 Out of range PB E Pad E-14A E-14A V2 5520.90 5620.00 965.14 200.15 764.99 Pass: Major Risk PB E Pad E-14 E-14 V1 5520.90 5620.00 965.14 200.15 764.99 Pass: Major Risk PB E Pad E-15 E-15 V3 Out of range PB E Pad E-15 E-15A V2 Out of range PB E Pad E-15 E-15AP61 V2 Out of range PB E Pad E-15 E-15AP62 V2 Out of range ~' PB E Pad E-15 E-156 V2 Out of range PB E Pad E-15 E-15BP61 V2 Out of range i PB E Pad E-15 E-15C V9 Out of range PB E Pad E-16 E-16 V1 5500.00 5850.00 1085.16 88.06 997.10 Pass: Major Risk PB E Pad E-17 E-17 V1 5525.45 5150.00 1112.82 118.39 994.43 Pass: Major Risk PB E Pad E-17 E-17A V3 5525.45 5150.00 1112.82 118.39 994.43 Pass: Major Risk i PB E Pad E-21 E-21 V5 Out of range PB E Pad E-21 E-21A V1 Out of range PB E Pad E-21 E-21 B V2 Out of range PB E Pad E-24 E-24 V1 Out of range PB E Pad E-24 E-24A V1 Out of range i PB E Pad E-24 E-24AP61 V1 Out of range ,~ BP Alaska i Anticollision Report Company: BP Amoco Date: 1/22/2009 Time: 09:02:49 Field: Prudhoe Bay Reference Site: PB E Pad Co-ordinate(NE) Reference: Well: E-05, True North Reference Well: E-05 Vertical (TVD) Reference: E-056 Plan 58.5 Reference Wellpath: E-056 Plan Summary Page: 2 Db: Orade <- -- - Offset Wellpath - - > Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB E Pad E-24 E-24APB2 V1 Out of range PB E Pad E-24 E-246 V1 Out of range PB E Pad E-25 E-25 V2 Out of range PB E Pad E-26 E-26 V4 9044.97 8955.00 1250.34 191.04 1059.29 Pass: Major Risk PB E Pad E-26 E-26A V4 8604.20 8495.00 1164.83 177.56 987.27 Pass: Major Risk PB E Pad E-29 E-29 V1 Out of range PB E Pad E-29 E-29A V2 Out of range PB E Pad E-31 E-31 V6 5521.70 5700.00 1195.05 190.44 1004.61 Pass: Major Risk PB E Pad E-31 E-31 A V31 5522.51 5695.00 1195.37 190.50 1004.86 Pass: Major Risk ~~, PB E Pad E-33 E-33 V1 Out of range I PB E Pad E-33 E-33A V2 Out of range PB E Pad E-34 E-34 V1 10350.00 9895.00 1248.59 253.22 995.37 Pass: Major Risk PB E Pad E-34 Plan 6, E-34L1 VO Plan 10319.80 9980.00 1205.35 254.59 950.76 Pass: Major Risk 'I PB E Pad E-35 E-35 V2 Out of range PB E Pad E-35 E-35A V5 Out of range PB E Pad E-35 E-35P61 V3 Out of range PB E Pad E-36 E-36 V1 Out of range '. PB E Pad E-36 E-36A VS Out of range PB E Pad E-38 E-38 V1 9392.40 10041.00 903.73 107.93 795.80 Pass: Major Risk PB E Pad E-38P61 E-38P61 V1 9235.07 9871.00 1006.45 87.93 918.53 Pass: Major Risk ~ PB E Pad E-38PB2 E-38P62 V1 9306.12 9856.00 1026.18 85.74 940.44 Pass: Major Risk PB K Pad K-10 K-10 V1 11078.95 9910.00 519.03 574.33 -55.30 FA-L: Major Risk PB K Pad K-10 K-10A V7 11156.52 9735.00 551.74 521.18 30.57 Pass: Major Risk PB K Pad K-10 K-10AP61 V1 11233.97 9865.00 526.27 551.11 -24.83 FAIL: Major Risk PB K Pad K-10 K-10AP62 V1 11231.33 9860.00 525.11 550.40 -25.29 FAIL: Major Risk ~~ PB K Pad K-10 K-10AP63 V2 11218.78 9845.00 536.79 548.91 -12.11 FAIL: Major Risk PB K Pad K-10 K-106 V3 11080.34 9755.00 531.20 504.46 26.74 Pass: Major Risk PB K Pad K-19 K-19A V1 11229.76 11630.00 905.76 306.75 599.01 Pass: Major Risk Field: Prudhoe Bay Site: PB E Pad Well: E-05 Wellpath: E-OSB Plan 300 200 100 I00 200 300 From KOP to TD Scan interval 100 ft Scale 1:100 K-10, K-10APB1,2,3, Fail Majc Travelling Cylinder Azimuth (TFO+AZq [deg] vs Centre to Centre Separation [ I OOR/in] Field: Prudhoe Bay Site: PB E Pad Well: E-05 Wellpath: E-OSB Plan From KOP to TD Scan interval 100 ft Scale 1:100 K-10, K-10APB1,2,3,A Pass Risk 1:200 300 200 100 100 200 300 t tsu Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [100Nin] EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 r~ 6000000 5950000 5900000 5850000 400000 500000 600000 700000 800000 Alaska Department of Natural Resources Land Administration System Page 1 ofx' • ~ C . ~:' .~ ..:~~ ., . ' ,° ~ F la?s f~w~or€2r's Search State Cabins ~~'~II~~ ~~SCl41CCs~S . A~S~~ ®~ C~S~~' tltlll'1'le~r~/' File T e ADL File Number: 28304 ~ printable Case File_Summary YP See Township, Range, Section and Acreage? ~„ New Search Yes ~°°= No ._..___ ~_~_ _.. i._AS ~entr I Case Abstract I Case Detail I Land Abstract ~' , 1~~1e: aDi, ?~30-I '''' Search for Status.. Plat Updates ;~~ of 0~!1 I!2009 Custor~~er: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 1 966 1 2/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995 1 966 1 2 Case Tvpe: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Statzrs Dute: 09/l4/1965 Total Acres: 2469.000 Date Initiated: 05/28/ 1965 Offrce of Pri~z~ary Rcsponsibility.~ DOG DN OIL AND GAS Last Transaction Date: 12/04/2006 Case S~rhtyhe : NS NORTH SLOPE Lust Transaction: AA-NRB ASSIGNMENT APPROVED 11~Ieric/icm: l! Toti~~n~~hrf~: OllN R<a~,~-: 014E Section: 0~ S~ectionAcres: 640 Search Plats llrrl~lhm.~ l_i 7uu~n~Frij~: O11N l~crn~c~: 014E S'r~c~iun.~ U~; ~'ectionAcrcr~.~ 593 [~ICi'/[~lUll: ~ ~ ~Ult'1),1'{]lj>: n I ~ ~ Ri717'~'C: OI4E ~SC'C/IUil.~ O i aeeti0l'1 !~C'rC,~'.' ~~~~) 11Ie~~i~li~nt: [J Tom~1~{ti~~ (t I I N Range: OI4E S~'~~tron.~ O~ ~~ectionAcrr~~~." G4(} Legal Description 0~-28-196 *'~*SALB NOTICE LEGAL DESCRIPTION*** Cl~{-125 IIN I ~tE UILI ~. 6, ?. ~ ?469.00 U- 3- 7 Last updated on 02/11/2009. http://dnr.alaska.gov/proj ects/las/Case_Summary.cfm?FileType=ADL&FileNumber=2830... 2/11 /2009 • TRANSMITTAL LETTER CHECKLIST WELL NAME ~8~~ DS/' PTD# a20 9 Ova /_ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~i~!.~/,JyOE !~ ~y POOL: ~,~'~,/,/,D~OE_ /~iQy ~/G Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -~) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 / 1112008 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL -640150 _ Well Name: PRUDHOE BAY UNIT E_-056 _ Program DEV __ Well bore seg PTD#:209021D Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV I PEND GeoArea 890 Unit 11650 On/Off Shore On _ Annular Disposal -- Administration 1 Permit fee attached_ - - - . - .. - - - NA 2 Lease number appropriate_ _ _ _ _ _ Yes _ _ _ _ _ _ - _ - _ _ _ _ _ _ _ 3 Uniquewell_nameandnumber_____ ____________________ _________Yes___ -- __ 4 Well located in_a_define_d pool _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 Well located proper distance from drilling unit_boundary_ - - - - . - - Yes ----------------- 6 Well located proper distance from otherwells_ Yes 7 Sufficientacreage_avail_ablein_drillingunit______________ ______ ___________ Yes__--- --_____ -_--_____- -_ i 8 Ifdeyiated,is_wellboreplat_included______________ _________ ___________Y_es_--- - 9 Ope[atoronlyaffectedparty-------- ------------------- ----------. Yes----- ---------------------.- j 10 Ope[ator has_appropriate_ bond in force _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . - - - _ _ _ _ Yes - - - - _ _ Blanket Bond #6194193. _ _ _ _ _ 11 Permit_ can be issued without conservation order- - _ Yes .. - - - - - - Appr Date 12 Permit_ can be issued without administrative. approval Yes - - - - - -------------------------- 13 Can permit be approved before 15-day wait_ _ _ - Y_es ACS 2!1112009 14 Well located within area and_strata authorized by Injection Order# (put_1O# in_comments)_(For- NA_ 15 All wells-within 114_mik; area_of review )dentified (For sen!ice well only) _ _ - . - NA_ - - . - 16 Pre-produced injector; duration of pre-production Less than 3 months- (For service well only) NA 17 Nonconven, gas conforms to AS31,D5,030Q.t.A),(j.2.A-D) - - - - - . - - NA_ 18 Conductorstring_provided______________ _______________ _ NA__.- - --- _Conductor-set_inE-05(176-015),__.__._______ Engineering 19 Surface casing protects allknown USDWs - - - . - - NA_ - - - - . All aquifers exempted, AEO1. - 20 CMT_vol adequate to circulate-on conductor & su_rf_csg NA- - - Surface casing set in E-05. 21 CMT_v_ol adeguate_to tie-in_long string to_surf csg_ - NA_ Production_ casing set in_E-05. -New_p_roduction liner will be full cement_ed._ y 22 CMT_will cover-all known_productive horizons- - - Yes - . - - - - - ------------------------- 23 Casing designs adequate for C, T, B &. permaf[ost_ Yes - - - - - - 24 Adequate tankage_or reserve pit _ Yes - - . - Rig equipped with steel pits. No reserve pit planned._ All waste_to approved disposal well(s). - 25 If.a-re-drill, has.a 10-403 for abandonment been approved _ _ _ _ _ - _ - Yes _ _ _ _ _ _ 309-007 _ , 26 Adequate wellbole separation_proposed_ Yes Proximity analysis performed. Traveling cylinder path calculated, Close approach in reservoir. ' 27 If.diverter required, does it meet regulations__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ BOP stack will alread _ be_in lace, _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ y p Appr Date 28 Drilling fluid_ program schematic_& equip list_adequate_ . - - - - Y_es - - . - - -Maximum expecte formation pressure 8.5 EMW-in 8.5"hole. and 7,2_EMW in-zone. _ MWs planned up to_9.9 & 8,5_ TEM 2113/2009 29 BOPEs,.do the-y meet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ - - - 30 BO_PE_press rating appropriate; test to (pu_t psig in comments).. - - - - Y_es - MA$p calculated at 2991 psi, 3500_psi_ BOP testproposed, - - . 31 Choke_manifold complies w/APiRP-53 (May 84)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . - - - Yes - _ _ - - . - _ _ _ 32 Work will occur without operation shutdown___________________ __________ Yes____- - 33 Is presence_of H2S gas probable- Yes - - - - - - H2S is reported_at E_pad._ Mud should preclud_e_H2S_on rig.. Rig has sensors and_ala_rms._ ----- 34 Mechanical_condition of wells within AOR verified (For service well Only) NA 35 Permit can be issued w/o hyd[ogen_ sulfide measures No_ - -- -- - Max level H2S oq Pad_is 120ppm for well_ E-102-(9116!08), Geology 36 Data presented on_ potential overpressure zones_ - - NA Appr Date X37 Seismic_analysis of shallow gas_zones NA - ACS 2!1112009 38 Seabed condition curve if off-shore y( ) NA , - - . - 39 Contact name/phone for weekly-progress reports[exploratoryonly]_____- -____--__- Yes-____ __Jo-vyROach-564-4352._-_---___----------------------------- - Geologic Engineering P Commissioner: Date: Commissioner: Date is ner ~ Date Z' ~~~ z -~,~.~ /3~ D
