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205-126
RECEIVEL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM.. ON SEP 1 6 2015 WEL._..OMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 • Suspended 0 lb.Well C40�CC 20AAC 25.105 20AAC 25.110 Development RIExploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,r.Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 81 6.2(.. l f� 205-126 • 3. Address: 7. Date Spudded: / /' 15. API Number: P.O.Box 196612 Anchorage,AK 99519-6612 8/31/2005 �'Z3 r�j 50-029-20529-01-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number 9/12/2005 PBU 14-11A ' Surface: 1776'FNL,1759'FEL,Sec.09,T10,R14E,UM • 17. Field/Pool(s): 9. KB(ft above MSL): 71.4' Top of Productive Interval: 4857'FNL,2223'FEL,Sec.09,T1ON,R14E,UM GL(ft above MSL): 42.26' PRUDHOE BAY,PRUDHOE OIL • Total Depth: 4705'FNL,3522'FEL,Sec.09,T10N,R14E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 10350'/8840' ADL 028312 ' 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 674727• y- 5938553 • Zone - ASP 4 . 11804'/8909' • TPI: x- 674342 y- 5935463 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 673039 y- 5935585 Zone - ASP 4 None 1900'(Approx.) 5. Directional Survey: Yes 0 (attached) No H 13. Water Deoth.if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) • 7109'/6843' 22 Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary MWD DIR/GR/PWD,MWD DIR/GR/RES/AIM 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20" 94# H-40 31' 111' 31' 111' 32" 300 sx Permafrost 13-3/8" 72# L-80 30' 2652' 30' 2652' 17-1/2" 1640 sx Fondu,400 sx Arctic Set II 9-5/8" 47# L-80 28' 7109' 28' • 6843' 12-1/4" 500 sx Class'G' 7" 26# L-80 26' 10330' 26' 8828' 8-1/2" 168 sx Class'G',480 sx Class'G' 4-1/2" 12.6# L-80 10130' 11804' 8714' 8909' 6-1/8" Uncemented Slotted Liner 24. Open to production or injection? Yes 0 No IZI • 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2"12.6#13Cr80 10145' 10090'/8691' A 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes 0 No - -IYPIET • Per 20 AAC 25.283(i)(2)attach electronic and printed information .�►. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED SEWED SEP 2 42015 - ' 10350' _ Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corn): Press 24 Hour Rate ...♦ Form 10-407 Revised 5/2015 CONTINUED ON PAGE 2 A Submit ORIGINAL only / 28.' „ CORE DATA Conventional Core(s) Yes 0 No RI Sidewall Cores Yes 0 No I 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 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No El • Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach separate sheets to this form,if needed,and submit detailed test information per 20 Sag River 10314' ' 8819' • AAC 25.071. Shublik A 10351' 8840' Shublik B 10400' 8868' Shublik C 10419' 8879' Sadlerochit 10450' 8896' . 45P 10549' 8943' 44P 10650' 8990' Formation at total depth: 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Well Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Sperry,Nathan Email: Nathan.Sperry©bp.com Printed Name: Joe Lastu / Title: Dulling Technologist Signature: Phone: 907-564-4091 Date: q/15/15 +\ V 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. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la. 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 lb.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations 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 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records 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. Item 31.Pursuant to 20 AAC 25.070.attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only 14-11A / L1, Well History (Pre-Rig Sidetrack) gay 7. a.., ,, Fi 4F fir.: �,. T/I/O/00 = 380/100/90/70. Temp = SI. TBG FL (Eline request). AL SI @ casing valve. ALP = 1990 psi. TBG FL @ 300' (4.6 bbl). SV, WV, SSV= C. MV= 0. IA/OA/00 = OTG. NOVP 1620 7/10/2015 hr. (SLB E-LINE CUT TUBING). INITIAL T/I/O = 300/ 100/ 100. RIH W/CCL/2.125" POWER JET CUTTER & CUT 2-7/8" LINER @ 10360'. TIED INTO SLB MEMORY CEMENT BOND LOG DATED 15-APR-2015. FINAL T/I/O = 300/ 100/ 100. WELL LEFT SHUT IN UPON DEPARTURE - 7/11/2015 NOTIFIED DSO OF WELL STATUS. T/I/O/00=SSV/1980/0+/0+, Temp=Sl. PPPOT-T(PASS), pre tree replacement for CTD. PPPOT-T: Stung into test port(0+ psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Single port, unable to pump through void. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 7/13/2015 0 psi in second 15 min (PASS). Bled void to 0 psi. CTU #9 w/1.75" CT Objective: Catch and release liner. MIRU, RIH with BOT fishing BHA, perform extended wt check at 10,000'. RIH and set down on liner top at 10,101' CTMD, PUH and found pickup wt to be 1.5k higher indicating that the liner was on the CT. POOH 100' to 10,000'wt still 1.5k higher. RIH and set down at 10,101', come online with the pumps and release liner. POOH and FP 7/24/2015 well down CTBS with 50/50 meth. T/1/0/00=TWC/15/50/50. RD Upper Tree. RU P SUB With HWO 5X7 SV and TS#5. Torque Flanges to API Specs. PT Flanges. PT MV to SV Verify SV Pass LTT. PT SV and TS#5. RDMO. Final 8/10/2015 T/I/0/00=TWC/150/50/50. T/I/O/00=425/150/50/50. Pre Nordic 2. Set 4""H"TWC#296. PT tree cap to 500 psi. Final WHP's 8/10/2015 TWC/150/50/50. T/I/O/00= ?/130/40/70. Temp = SI. Bleed WHP's to 0 psi (pre CTD). TWC installed in Tbg. No well house, flow line, scaffold, or SSV. IA, OA, &OOA FL near surface. Bled IAP, OAP, & OOAP to 0 psi in 30 minutes(gas). During monitor IAP increased 20 psi, OAP, & OOAP unchanged. Re-bled IAP to 0 psi and held open for 2.5 hours. Monitored for 30 minutes. IAP increased to 0+, OAP unchanged, & OOAP increased to 0+. Final WHP's= ?/0+/0/0+. SV, WV, MV= ?. IA& OA= OTG. 8/12/2015 NOVP. 14:40. North America-ALASKA-BP Page 1 olCr Operation Summary Report Common Well Name:14-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/15/2015 End Date:8/27/2015 X3-0172J-C:(2,993,246.40) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:NORDIC 2 Spud Date/Time:7/4/1981 12:00:00AM Rig Release:9/4/2015 Rig Contractor NORDIC CALISTA UWI:500292052900 Active datum:42.90GL+28.5KB @71.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 8/15/2015 03:00 - 04:00 1.00 RIGU P PRE RELEASE RIG AT 03:00 DISCUSSED PRIOR TO MOVE WITH ALL INVOLVED THE CRITERIA OF OCN#4,WHICH ALLOWS PULLING OFF THE WELL WITH NO BPV INSTALLED.-PHYSICAL BARRIERS IN PLACE(12 X 12 CHOCKS)TO KEEP FROM ROLLING INTO WELL -ESD IN CELLAR MANNED BY NORDIC SUPERINTENDENT AND WAS TESTED PRIOR TO MOVING OFF -RADIO COMMUNICATION WAS VERIFIED PRIOR TO MOVING -AGREED UPON COMMAND"STOP" UNDERSTOOD. '-ALL INVOLVED WERE AWARE OF THE BPV NOT BEING INSTALLED -DISCUSSED ROLES AND RESPONSIBILITIES WITH CREW AND ASSIGNED LOCATIONS AROUND RIG FOR SPOTTING -SITE CONTROL TASKED WITH KEEPING AREA CLEAR OF NON ESSENTIAL PERSONNEL 04:00 - 07:00 3.00 RIGU P PRE PULL OFF WELLAND MOVE TO SIDE OF PAD. PICK UP MATS AROUND WELLAND TIDY UP LOCATION. 07:00 - 14:30 7.50 RIGU P PRE PJSM WITH SECURITY AND RIG CREW FOR MOVING RIG TO DS-14. REVIEW ROUTE HAZARDS AND SPOTTER POSITIONS. PULL RIG OFF J-PAD,RIGHT ONTO SPINE ROAD. MOVE RIG DOWN SPINE ROAD,RIGHT ONTO DS-14 ACCESS ROAD. 14'30 - 16 00 1.50 RIGU P PRE PREP PAD. PJSM. MOVE RIG OVER 14-11. ACCEPT RIG AT 16:00 16:00 - 20:00 4.00 RIGU P PRE DISCUSS TREE CONFIGUTRATION. RU ON 14-11 -PREP FOR LTT IN SWAB/MASTER. NIPPLE UP BOPE -AOGCC JEFF JONES WAIVED WITNESS AT 19:29 20:00 - 21:30 1.50 RIGU P PRE PJSM FOR PICKING UP REEL -PICKED UP REEL INTO REEL HOUSE. (72,000 LBS) -SIMULTANEOUS OPS INCLUDED. GREASE, GET MEASUREMENTS, PREP FOR BOPE TEST 21:30 - 00:00 2.50 RIGU P PRE PJSM FOR P/U INJECTOR/PULLING COIL ACROSS -INSTALL GRAPPLE INTO REEL. PULL TEST -REMOVE SHIPPING BAR -PULL ACROSS TO CHAINS, INCREASE TRACTION. TAKE CONTROL OF PIPE WITH INJECTOR -SWAP OUT PULL BACK CABLE/REMOVE GRAPPLE 8/16/2015 00:00 - 01:00 1.00 RIGU P PRE FINISH PREPPING FOR BOPE TEST. Printed 9/15/2015 10:24:28AM • North America-ALASKA-BP Page 2 z.23 Operation Summary Report Common Well Name: 14-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/15/2015 End Date:8/27/2015 X3-0172J-C:(2,993,246.40) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:NORDIC 2 Spud Date/me:7/4/1981 12:00:00AM Rig Release:9/4/2015 Rig Contractor:NORDIC CALISTA UWI:500292052900 Active datum:42.90GL+28.5KB©71.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) (usft) • 1 01:00 - 07:00 6.00 BOPSUR P PRE PJSM, BEGIN BOPE TEST -PERFORM H2S/RIG EVAC DRILL -CONTINUE TO PLACE EQUIPMENT AS TRAILERS ARRIVE -FILL COIL WITH FRESHWATER 07 00 - 09:30 2.50 BOPSUR P PRE CONTINUE TESTING BOPS. WITNESS WAIVED BY JEFF JONES. TEST VBR AND ANNULAR WITH 3-1/2"AND 12-3/8"TEST JOINT. j TEST GAS ALARMS. RIG EVAC EXERCISE WITH DAY CREW. CONDUCT DRAWDOWN TEST. FUNCTION TEST BOPS FROM DRILLERS AND SLB PANELS. 09:30 - 10:45 1.25 BOPSUR j P PRE MAKEUP INJECTOR FOR INNER REEL VALVE TEST. REVERSE CIRCULATE AND PT INNER REEL 'VALVE AND CT STRIPPER TO 250/3500 PSI. 10:45 - 12:20 1.58 BOPSUR N PRE LEAK FOUND ON VALVE#5 ON THE KILL MANIFOLD. PERFORM LO/TO AND CHANGE OUT PACKING .ON THIS VALVE. TRY TO TEST INNER REEL VALVE AGAIN, STILL LEAKING. OPEN VALVE MMI AND INSPECT,FIND RUBBER SEATS ARE WASHED OUT. PERFORM LO/TO AND REBUILD VALVE MMI. 12:20 - 13:00 0.67 BOPSUR, P PRE 1 TEST INNER REEL VALVE AND CT STRIPPER TO 250/3500 PSI,GOOD. 13:00 - 14:30 1.50 BOPSUR P PRE VALVE CREW CONDUCTS PJSM WITH RIG CREW THEN TORQUES UP TREE BOLTS. 14:30 - 15:20 0.83 RIGU C PRE BP ASSURANCE VERIFICATION DISCUSSION WITH WELLS OPERATING AUTHORITY i I 'RICHARD HARLAND,DRILLER,TOOLPUSHER, WSL AND NORDIC SUPT. DISCUSS SIMOPS WITH DOYON 14,BOP SHEAR TABLE,MGS,AND STATION BILL. 15:20 - 16:30 1.17 RIGU P PRE PJSM THEN LIFT UP INJECTOR,INSTALL BTT COIL CONNECTOR. PULL TEST TO 45K,GOOD. PRESSURE TEST TO 250/3500 PSI,GOOD. 1630 - 17:00 0.50 RIGU P PRE LOAD BTT EQUIPMENT AND BPV LUBRICATOR ONTO RIG. 17:00 - 19:30 , 2.50 RIGU P PRE PJSM WITH BPV CREW. RIG UP BPV LUBRICATOR AND PT 250/3500 PSI,GOOD. MAKE NOTIFICATION TO PAD OP AND DOYON 14 FOR BLEEDING GAS. PULL TWC,460 PSI UNDER IT. • SHUT MASTER VALVE AND BLEED OFF,THEN SHUT SWAB. OFFLOAD BPV LUBRICATOR AND PULLING TOOLS. 19:30 - 21:45 2.25 t RIGU ' P PRE MAKE UP INJECTOR AND PT TOP BOWEN CONNECTION THAT WAS BROKE OUT. PASSED LOW AND HIGH BREAK INJECTOR OFF, INSTALL NIGHT CAP. TEST Printed 9/15/2015 10:2428AM • North America-ALASKA-BP Page 3 aL Operation Summary Report Common Well Name:14-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/15/2015 End Date:8/27/2015 X3-0172J-C:(2,993,246.40) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:NORDIC 2 Spud Date/Time:7/4/1981 12:00:00AM Rig Release:9/4/2015 Rig Contractor:NORDIC CALISTA UWI:500292052900 Active datum:42.90GL+28.5KB a71.40usft(above Mean Sea Level) Date From-To ! Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:45 - 00:00 2.25 RIGU P PRE PJSM, REVIEW PRESSURE CROSSCHECK I I WITH EVERYBODY INVOLVED BEGIN BULLHEAD T/IA/OA/OOA=461/72/6/57 -PUMP 5 BBL METHANOL SPEAR -PUMP 230 BBLS 1%KCL AFTER 60 BBLS I AWAY. WELL ON VAC -PUMP 40 BBLS HI VIS WELL STILL ON VAC -PUMP 150 BBLS OF 1%KCL WI SAFELUBE -PUMPED ALL THE ABOVE AT 4.6 BPM -AFTER FLUIDS AWAY. LINE UP THROUGH CHOKE TO GET A LOSS RATE I-WALK RATE UP FROM 4.6 BPM TO 7.2 BPM WITH NO RETURNS 8/17/2015 00:00 - 00:30 0.50 RIGU N DPRB PRE CALL ODE ABOUT LOSS RATE. SHUT WELL IN WHILE GETTING EVERYTING READY FOR j POLYSWELL. RECEIVE_OCN#1. ODE RECEIVED VERBAL FROM ETL(J.McMULLEN) AND ON CALL WTL ' (R.BURNETT)OPS SUPERINTENDENT GAVE GO AHEAD. PULL SCREENS ON PUMPS. SEND TRUCKS : FOR MORE KCL. LOSS RATE WAS A LOT .HIGHER THAN ANTICIPATED. 00:30 - 0217 1.78 RIGU- N DPRB PRE KCL ARRIVED. MUD ENGINEER ARRIVED. START ADDING i I KCL TO BRING UP TO 6%KCL PILL UP TO YP ' 1©-30LB/100FT2 FLUIDS ARE ALL HERE. 0217 - 06:30 4.22 RIGU N DPRB PRE PJSM, START PUMPING 1%KCL STARTED PUMPING POLYSWELL. WELL SUCKING IT OUT OF PITS QUICKER THAN WE I CAN DUMP. PUMPED A 112 BBL KCL BEHIND. UTILIZED PVT FOR VOLUME. DROP RATE BACK TO.5 BPM(2000/HR HOLE FILL) LET "WM EXPAND. 06.30 - 08:45 2.25 RIGU N DPRB PRE I CONTINUE PUMPING INTO WELL AT 0.5 BPM, WELL IS TAKING ABOUT 1 BPM THROUGH THE PUMP. BLEED OOA FROM 500 TO 200 PSI. BLEED OA FROM 650 PSI TO 100 PSI. 08:45 - 09:15 0.50 RIGU N DPRB PRE PJSM THEN OPEN UP WELL ACROSS TOP TO MGS AND BACK TO PITS. I PUMP ACROSS TOP TO ASSESS LOSS RATE AFTER 1ST POLYSWELL PILL. I OPEN CHOKE,PUMP 174 BBLS IN 24 MIN,NO 1 RETURNS SEEN. 09:15 - 12:30 3.25 RIGU N DPRB PRE REDUCE PUMP RATE TO 0.5 BPM,WELL IS TAKING ABOUT 1 BPM THROUGH THE PUMP. AT 0.77 BPM PUMP RATE WELL IS TAKING ABOUT 1.6 BPM. MIX UP SECOND POLYSWELL PILL AS PER fi OCN#2 LEVEL 1. Printed 9/15/2015 10:24:28AM • • North America-ALASKA-BP Page 4 oQ3 Operation Summary Report Common Well Name:14-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/15/2015 End Date:8/27/2015 X3-0172J-C:(2,993,246.40) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:NORDIC 2 Spud Date/Time:7/4/1981 12:00:00AM Rig Release:9/4/2015 Rig Contractor:NORDIC CALISTA UWI:500292052900 Active datum:42.90GL+28.5K8©71.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:30 - 13:30 1.00 RIGU N DPRB PRE PJSM THEN START MIXING 45 BBLS OF 20#/BBL POLYSWELL IN 6%KCL. PIT#4 AGITATION NOT SUFFICIENT FOR THIS CONCENTRATION,USE ADDITIONAL SURFACE AGITATION. AFTER 13 MIN MIXING START PILL DOWNHOLE. PUMP 45 BBLS FROM PIT#4 AT 3.5 BPM, THEN CHASE WITH 1%KCL. AFTER 80 BBLS AWAY,START SEEING WHP. POLYSWELL NOT AT PERFS YET. DISPLACE 44 BBLS POLYSWELL+113 BBLS 1%KCL AT 7.1 BPM. FINAL WHP AROUND 220 PSI. 13:30 - 14:10 0.67 RIGU N DPRB PRE OPEN CHOKE AND REDUCE RATE TO 0.5 BPM,WAIT FOR POLYSWELL TO TAKE ,EFFECT. CLEAN OUT PIT#4,ESTIMATE OF ABOUT 1 SACK POLYSWELL REMAINING,OUT OF 16 PUMPED. 14:10 - 14:45 0.58 RIGU N DPRB PRE RETURNS SEEN AT SLOW PUMP RATE,0.51/ 0.45 BPM. SWITCH TO NORMAL FLOW PATH AND FLOW CHECK THE WELL. STATIC. REMOVE NIGHT CAP AND WATCH WELL. PREP RIG FLOOR TO P/U FIRST BHA. 14:45 - 17:15 2.50 PULL P DECOMP PJSM THEN M/U BHA#1,FISHING BHA. M/U INJECTOR AND RIH. AT 800 FT,RETURN FLUID DENSITY<8.0 PPG. 10 MIN FLOW CHECK IS DRY,RETURNS LOOK FOAMY. CONTINUE RIH. 17:15 - 18:00 0.75 PULL P DECOMP GETTING SOME POLYSWELL BACK AT 6000 FT. WT CHECK AT 7000 FT IS 36K. WT CHECK AT 8000 FT IS 40K. WT CHECK AT 9000 FT IS 41K. 18:00 - 19:00 1.00 PULL P DECOMP AT 9690 FT START LOSING RETURNS. PICK UP AND FIND LOSS RATE,ABOUT 2.5 BPM. LOST ALL RETURNS 19:00 - 21:00 2.00 PULL N DPRB DECOMP DISCUSS WITH TOWN THE PLAN FORWARD. POOH WITH BHA#1 PUMPING DOWN WELL AT 5.25 BPM WITH NO RETURNS STOP AT 200'. 21:00 - 21:30 0.50 PULL N DPRB DECOMP PJSM, DISCUSS PULLING BHA OUT OF WELL ON 100%LOSSES -DISCUSS WELL CONTROL ROLES DURING OPS -DISCUSS FLUID HANDLING -FLOOR VALVE READY FOR THE PH6 AND WE WILL SHORT CHAIN EVERYTHING OUT AND BREAK DOWN WAS WELL SHUT IN. 21:30 - 21:45 0.25 PULL N DPRB DECOMP REMOVE INJECTOR, PULLED BHA OUT OF WELL SHUT PUMP DOWN AND CLOSE MASTER AND SWAB VALVE. BREAK DOWN BHA Printed 9/15/2015 10:24:28AM • • North America-ALASKA-BP Page 5 03 Operation Summary Report Common Well Name.14-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/15/2015 End Date:8/27/2015 X3-0172J-C:(2,993,246.40) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:NORDIC 2 Spud Date/Time:7/4/1981 12:00:00AM Rig Release:9/4/2015 Rig Contractor NORDIC CALISTA UWI:500292052900 Active datum:42.9OGL+28.5KB @71.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:45 - 00:00 2.25 PULL N DPRB DECOMP PREPARE FOR BATCH MIXING HIGHER VOLUME PILL HAVE DHD SHOOT A FLUID LEVEL-1218' AFTER 2 HOURS NO PUMPING. SHOT AGAIN AFTER 10 MINUTES. -1218' 8/18/2015 00:00 - 01:00 1.00 LCR N DPRB DECOMP STAGE PRODUCT. SPOT ALL EQUIPMENT 01:00 - 03:15 2.25 LCR N DPRB DECOMP PJSM FOR OCN#3 LEVEL 1 POLYSWELL#3 -INJECTIVITY OF 5+BPM. SUCKING THROUGH OUR PUMPS. GAUGE 100 BBLS OFF VAC TRUCK -PUMPED 70 BBLS OF 20 PPB POLYSWELL IN 6%KCL W/POWERVIS L(-30YP) -PUMPED 87 BBLS OF 1%KCL(GAUGE OFF TRUCKS DO TO FLUIDS GETTING SUCKED THROUGH OUR PUMPS) -LEADING EDGE OF POLYSWELL AT 10328'- SHUT PUMPS DOWN AT 02:30 -GIVE POLYSWELL 45 MIN TO SWELL. 03:15 - 06:30 3.25 LCR N DPRB DECOMP COME ONLINE DOWN KILL -PUMP 5.9 BBLS TO BRING UP TO 200#. SHUT PUMP DOWN FOR 10 MIN. PRESSURE DROPPED TO 150# -PUMP 11.8 BBLS TOTAL TO BRING UP TO •500#, SHUT PUMP DOWN. PRESSURE FELL TO 320#. LET SIT ANOTHER 15 MIN. DROPPED TO 260# -PUMP 20 BBLS TOTAL TO BRING TO 630#. THE WELL INJECTING. PUSH SOME MORE POLYSWELL BELOW CUT. PRESSURE FELL TO 400#. -PUMP 30 BBLS TOTAL TO BRING TO 700#. 0.8 BPM COME OFFLINE. DROPPED TO 510# THEN SLOWLY FALLING. FELL TO 350#AND HELD. -PUMP 35 BBLS TOTAL TO BRING TO 740# 0.4 BPM COME OFFLINE. DROPPED TO 600# THEN SLOWLY FALLING. FELL TO 410# HELD. -PUMP 40 BBLS TOTAL TO BRING TO 740#0.4 BPM. COME OFFLINE. DROPPED TO 640#, THEN SLOWLY FALLING CALLED ODE. CALLING 9000'TOP OF POLYSWELL STOPPING POINT OR 1000# SQUEEZE PRESSURE -PUMP 45 BBLS TOTAL TO BRING TO 820#0.5 BPM. COME OFFLINE. DROPPED TO 710#, THEN SLOWLY FALLING. 06:30 - 07:00 0.50 LCR N DPRB DECOMP HAVE PUSHED TOP POLYSWELL TO 8750 FT. WHP IS 322 PSI AND SLOWLY BLEEDING OFF. PUMP 1 BBL AT 0.5 BPM/790 PSI. PUSH TOP POLYSWELL DOWN TO 8816 FT. PRESSURE SLOWLY BLEEDING OFF. 07:00 - 08:40 1.67 LCR N DPRB DECOMP PUMP ANOTHER 1 BBL AT840 PSI,TOP POLYSWELL NOW AT 8882 FT. PRESSURE SLOWLY BLEEDING OFF TO 320 PSI. AT 07:30 PUMP 1 BBL AT 0.5 BPM/830 PSI. TOP POLYSWELL AT 8947 FT. Printed 9/15/2015 10:24:28AM • • North America-ALASKA-BP Page 6 of13 r�/ ', rr,.:. r .r l .,' *. ,. 0;..;;r :=rr• �r /,r* -f0 9 rir.:F`` r• f r+r'/E ,1r /ff rs/'";',`/.',;�,+f`rfj.�t°r"�ii r..,,r'�`:�'/"s�,.�.rsf: 6 s`�i%¢'. ,r/r!>;.f�>;.r9,r`f.���,%?"%,,f/,�r"�, i,'"J�l.�'r�.�,�✓:;/,r>�.�ffr,�k�-, +�%+ir,'s/'rl:r� ;.�;'f`rrl'f,+..,.�.�J,F,,'..s=�fj,,%'s '`:� ,ry,,;�>�;'� Operation Summary Report '� F�-,l „; � rr� � . ;,.rrf '.�>r � r�; Common Well Name:14-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/15/2015 End Date:8/27/2015 X3-0172J-C:(2,993,246.40) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:NORDIC 2 Spud Date/Time:7/4/1981 12:00:00AM Rig Release:9/4/2015 Rig Contractor:NORDIC CALISTA UWI:500292052900 Active datum:42.90GL+28.5KB @71.40usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 08:40 - 09:10 0.50 LCR N DPRB DECOMP WHP AT 240 PSI. PUMP FINAL BBL INTO THE WELL,BRING TOP POLYSWELL DOWN TO 9000 FT. 0.5 BPM/PRESSURE LEVELS OUT AT 760 PSI. AFTER 20 MIN WHP HAS BLED OFF TO 320 1 PSI. BLEED OFF WHP SLOWLY TO ZERO,WELL IS STATIC. REMOVE NIGHT CAP AND WATCH WELL FOR 10 MIN. 09:10 - 10:00 0.83 PULL N DPRB DECOMP 'PJSM THEN M/U BHA#2,LINER FISHING BHA. 'BHA OAL=94.15 FT. 10:00 - 12:00 2.00 PULL N DPRB DECOMP RIH BHA#2. SOME LIGHT RETURNS(<8 PPG)SEEN AT 2800 FT,STOP AND FLOWCHECK 10 MIN. ;TRIP SHEET IS EVEN TO THIS POINT, FLOWCHECK IS DRY. GETTING FOAMY RETURNS SIMILAR TO YESTERDAY. CONTINUE RIH,PUMP 1.5 BPM/940 PSI WHILE RIH. 12:00 - 12:50 0.83 PULL N DPRB DECOMP 1 WT CHECK AT 9000 FT IS 40K. CONTINUE RIH PAST HERE AT 30 FT/MIN, LPUMP 2.0 BPM/1630 PSI. AT 9650 START LOSING RETURNS,PICK UP AND CIRC EXCESS POLYSWELL OUT. OUT RATE DECLINING. 12:50 - 14:50 2.00 'PULL N DPRB DECOMP AT 9250 FT CIRC PRESSURE DECLINES,LOSE ALL RETURNS,LINE UP PUMP DOWN THE KILL LINE. PUMP 3.5 BPM DOWN ANNULUS,1.5 BPM DOWN CT. GET 1.0 BPM BACK FOR A SHORT !TIME THEN GOES AWAY. CAN'T KEEP THE HOLE FULLAT 5.1 BPM, POOH. 14:50 - 15:20 0.50 PULL N DPRB DECOMP TAG STRIPPER,FINISH TOPPING PITS. PUMP DOWN KILL LINE 6.9 BPM GETTING 0.4 BPM BACK. DIAL RATE BACK TO 6.2 BPM. 15:20 - 15:30 0.17 PULL N DPRB DECOMP !PJSM THEN PULL BHA#2 OUT OF WELL. WITH A FULL WELL REDUCE KILL LINE PUMP { RATE TO 2 BPM WHILE REMOVING BHA 15:30 - 16:30 1.00 PULL N DPRB DECOMP INSTALL NIGHT CAP,CONTINUE TO PUMP INTO WELL AT 2.0 BPM. 16:30 - 19:00 2.50 PULL N DPRB DECOMP I DISCUSS WITH ODE,DECIDE TO PUMP A FOURTH POLYSWELL SWEEP.ORDER OUT MORE FLUIDS&PRODUCTS.C/O WITH DAY CREW.PERFORM WALKAROUNDS. 19:00 - 19:30 0.50 PULL N DPRB DECOMP PJSM REGARDING PUMPING POLYSWELL PILL.CONTINUE TO FILL HOLE AT 2BPM/OPSI. 19:30 - 20:50 1.33 PULL N DPRB DECOMP FILL&BATCH UP 2 PODS 35BBLS EACH& CREATE 6%KCL.VIS UP EACH POD TO 30YP. CONTINUE TO FILL HOLE AT 2BPM/OPSI. CONFIRM FLUID VIA MUD ENGINEER.MIX POLYSWELL.BLEED OFF OOA FROM 450PSI TO OPSI-ALL GAS.BLEED DOWN OA FROM 550PSI TO OPSI ALL FLUID—2 BBLS. Printed 9/15/2015 10•24•28AM • North America-ALASKA-BP Page 7 efI3 Operation Summary Report Common Well Name:14-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/15/2015 End Date:8/27/2015 X3-0172J-C:(2,993,246.40) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No. NORDIC 2 Spud Date/Time.7/4/1981 12.00:00AM Rig Release:9/4/2015 Rig Contractor:NORDIC CALISTA UWI:500292052900 Active datum.42.90GL+28.5KB©71.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:50 - 21:30 0.67 PULL N DPRB DECOMP PUMP FIRST POD OF 35BBLS OF 687# POLYSWELL AT 3BPM/OPSI.SIMELTANEOUSLY BATCH UP SECOND POD WITH POLYSWELL. PUMP SECOND POD OF 35BBLS OF 687# POLYSWELL AT 3BPM/OPSI.DISPLACE WITH 96BBLS OF 1%KCL INJECTING-5 BBLS OF POLYSWELL INTO SLOTTED LINER.OBSERVE 500PSI BUMP OF WHP AT FINAL DISPLACEMENT.SHUT DOWN.SHUT IN KILL LINE. 21.30 - 22.00 0.50 PULL N DPRB DECOMP WAIT 30 MIN FOR POLYSWELL TO SWELL. 22:00 - 22:20 0.33 PULL N DPRB DECOMP OPEN KILL LINE.FILL HOLE AT 1BPM FROM PITS.AT 4BBLS AWAY,CAUGHT PRESSURE. SLOWLY BUILD WHP.STOP AT 20BBLS AWAY, WHP 105PSI.BLED DOWN TO OPSI IMMEDIATELY. 22:20 - 22:35 0.25 PULL N DPRB DECOMP WAIT FOR 15MIN. 22:35 - 22:55 0.33 PULL N DPRB DECOMP PUMP AT 1BPM,IMMEDIATELY BUILD UP TO 132PSI.SLOWLY BUILD WHP TO 230PSI, BROKE OVER&FELL TO 130PSI.WITH TOTAL OF 33BBLS AWAY,STOP PUMPING.BLED DOWN TO OPSI IMMEDIATELY. 22:55 - 23:10 0.25 PULL N DPRB DECOMP WAIT FOR 15 MIN. 23:10 - 23:25 0.25 PULL N DPRB DECOMP PUMP AT 1BPM, IMMEDIATELY BUILD UP TO 132PSI.NOT BUILDING ANYMORE WHP.WITH 48BBLS TOTAL INJECTED,STOP&FILL ACROSS THE TOP TO SEE FILL RATE. RETURNS RIGHT AWAY.1.34BPM IN/1.27BPM OUT. 23:25 - 23:35 0.17 PULL N DPRB DECOMP PJSM REGARDING MU FISHING BHA. 23:35 - 00:00 0.42 PULL N DPRB DECOMP PULL NITE CAP.FLOW CHECK-STATIC.MU FISHING BHA.PU INJECOTR&STAB ONTO WELL.ZERO COUNTERS.TEST QTS, 250PSI/3500PSI.LINE UP TO CIRC DOWN COIL.CIRC 1%KCL AT 0.45BPM IN/0.43BPM OUT AT 81 PSI. 8/19/2015 00:00 - 00:15 0.25 PULL N DPRB DECOMP CONTINUE TO MU FISHING BHA.STAB ONTO WELL.PREP TO RIH.CIRC 0.46BPM IN/82 PSI. 0015 - 03:15 3.00 PULL N DPRB DECOMP ADD SAFE LUBE TO SYSTEM.RIH,CIRC 0.43BPM IN/82PSI CTP.STOP AT 2041 FT. FLOW CHECK-OK.ADD DEFOAMER TO PITS. MINOR AMOUNTS OF POLYSWELL COMING OVER THE SHAKER.WT CK AT 8000FT,36K. WT CK AT 8500FT,37K.WT CK AT 9000FT, 41K.SLOWLY LOOSING RETURNS AFTER 9200FT.WT CK AT 9500FT,44K.WT CK AT 10000FT,48K.SLOWLY PUH&PUMP 1.67BPM DOWN COIL&2.4BPM DOWN KILL LINE, 0.4BPM LOSS RATE-3.5BPM LOSS RATE. CONTINUE SAME RATE&RIH.STACK OUT AT 10110FT.LOSS RATE IS-2.5BPM.REPEAT 4 TIMES.FLOW CHECK-NO FLOW. 03:15 - 03.30 0.25 PULL P DECOMP ENGAGE FISH,TOP OF LINER AT 10,116'. SET DOWN 9K.PICK UP TO CONFIRM LATCHED. 03:30 - 05:45 2.25 PULL P DECOMP POH.CIRC 2.4BPM DOWN KILL LINE AND 0.5BPM DOWN COIL.FLOW CHECK AT 9000FT -NO FLOW.LOSS RATE-2.5BPM.CONTINUE TO POH. Printed 9/15/2015 10:24:28AM • • North America-ALASKA-BP Page 8°t, Operation Summary Report Common Well Name:14-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/15/2015 End Date:8/27/2015 X3-0172J-C:(2,993,246.40) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:NORDIC 2 Spud Date/Time:7/4/1981 12:00:00AM Rig Release:9/4/2015 Rig Contractor:NORDIC CALISTA UWI:500292052900 Active datum:42.90GL+28.5KB(jp71.40usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 1 05:45 - 06:30 0.75 PULL P DECOMP !POH TO 50'.FLOW CHECK.POH TO FISH. 06:30 - 08:15 1.75 PULL P DECOMP LAY DOWN FISH:WITH 8 JTS 2-7/8"LINER,10' PUP JT AND 4.1'CUT JOINT,244 FT. JET CUT IS CLEAN. LAY DOWN BOT FISHING TOOLS REMOVE FISH FROM PIPE SHED FOR"NORM" INSPECTION 08:15 - 08:30 0.25 PULL P DECOMP STAB ON INJECTOR.PUMP SLACK BACK. 08:30 - 10:15 1.75 PULL P DECOMP RIG UP HYDRAULIC COIL CUTTER. I"WELL ON FULL LOSES AT 09:00 HRS.TRY FILLING HOLE AT 5 BPM WITH NO SUCCESS" I SLOW PUMP RATE TO 2 BPM DOWN WELL WITH NO RETURNS. CONSULT WITH ODE I AND SUPERINTENDENT. CUT 257'OF COIL DISCUSS FORWARD PLAN WITH ODE, DECIDE TO PUMP A FIFTH POLYSWELL PILL. START PREPPING PITS AND PRODUCT. 10:15 - 13 00 2.75 PULL P DECOMP RE HEAD COIL TUBING CONNECTOR. PULL TEST TO 35K AND PRESSURE TEST TO 4000 PSI.PRESURE TEST FAILED.REMOVED j CONNECTOR AND REINSTALLED. GET GOOD PULL TEST AND PRESSURE TEST, 250/3500 PSI. I CONTINUE MIXING POLYSWELL PILL. 13:00 - 14:30 1.50 PULL N DPRB DECOMP DISCUSS DEVIATION FOR OPERATIONS WITH NO FLUID AT SURFACE. j REVIEW PUMP LINE UPS AND CONTINGENCIES WITH WTL,CTD SI, TOOLPUSHER AND WSL. CONDUCT A DRY RUN TO TEST THE PROCESS OF SPLITTING THE PUMPS. 14:30 - 16'30 2.00 PULL C DECOMP INSTALL SCREENS IN PUMP#1 THAT WERE REMOVED FOR PUMPING POLYSWELL. PERFORM TEST OF SPLITTING MUD PUMPS SO THAT KILL LINE RATE USING PUMP#1 WITH GRAVITY FEED CAN BE VERIFIED VIA PVT READINGS INDEPENDENTLY OF PUMP#2 WHICH IS ON THE CHARGE PUMP. LINE UP SUCTION AND HI-PRESSURE VALVES TO PUMP DOWN THE CT WITH PUMP#2, DOWN THE KILL LINE WITH PUMP#1. PUMP 1 BPM WITH PUMP#1 ON GRAVITY FEED,2-3 BPM WITH PUMP#2 ON CHARGE PUMP FROM A VAC TRUCK TO SIMULATE DRILLING CONDITIONS. PIT WATCHER VERIFIES KILL LINE FEED IS 1 BPM,MATCHING PUMP STROKES. SIMULATE PUMPING A SWEEP BY FEEDING PUMP#2 FROM THE PITS FOR 30 BBLS,THEN BACK TO THE TRUCK ALL SYSTEMS WORK AS PLANNED. CONDUCT AAR FOR THE OPERATION. CONDUCT AAR FOR THE POLYSWELL OPERATION. Printed 9/15/2015 10:24.28AM North America-ALASKA-BP Page 9 0Q28 Operation Summary Report Common Well Name: 14-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/15/2015 End Date:8/27/2015 X3-0172J-C:(2,993,246.40) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:NORDIC 2 Spud Date/Time:7/4/1981 12:00:00AM Rig Release:9/4/2015 Rig Contractor:NORDIC CALISTA UWI:500292052900 Active datum:42.90GL+28.5KB @71.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 19:15 2.75 PULL . N HMAN DECOMP POP OFF WELL,FIND THAT CABLE SLACK I HAS BEEN PUMPED OUT OF REEL. NOZZLE WAS USED THAT HAD TOO LARGE A HOLE ON THE BOTTOM,ALLOWING CABLE ;TO COME OUT. I ' I RE-BOOT CABLE AND PUMP SLACK BACK ;INTO REEL. RIG UP HYDRAULIC CUTTER AND CUT 260 FT OF CT. INSTALL CTC.PULL TEST TO 35K& 'PRESSURE TEST 250PSI/4000PSI. 19:15 - 00:00 4.75 PULL P DECOMP ;STAB ONTO WELL.PUMP SLACK FORWARD. 1 TEST WIRE.REHEAD BHI.TEST WIRE. PRESSURE TEST CTC 250PSI/4000PSI.TEST BHI CHECK VALVES.REVIEW OCN#7 WITH 1 ;CREW.PUMP SLACK FORWARD.PUT !INJECTOR OVER BUNG HOLE.PJSM { ;REGARDING WORKING ON PUMP 2.LOTO PUMP 2.INSTALL PUMP 2 SCREEN.ADD SAFE LUBE TO PITS: 8/20/2015 00:00 - 01:05 1.08 PULL N DPRB DECOMP CONTINUE TO INSTALL PUMP SCREEN INTO PUMP 2.UNLOCK PUMP 2.LINE UP PUMPS TO KILL WELL.OPEN WELL.150PSI WHP. .01:05 - 01:30 0.42 CLEAN N DPRB DECOMP KILL WELL WITH 8.4PPG FLUID.PUMP AT 6.2BPM.MAX PRESSURE OF 150PSI WHP. ' i PUMP TOTAL OF 170BBLS.STOP PUMPING, WELL ON VAC.SPLIT PUMPS.LINE UP TO PUMP DOWN KILL LINE WITH PUMP 1. 01:30 - 01:40 0.17 CLEAN P DECOMP ;PJSM REGARDING MU FCO BHA. -rt _ I 01:40 - 02:20 0.67 CLEAN P DECOMP MU FCO BHA.PU INJECTOR&STAB ONTO 1 ;WELL.POWER UP&TEST TOOLS.TEST QTS 250PSI/4000PSI.SET COUNTERS.OPEN EDC. 02:20 - 04:00 1.67 CLEAN P . DECOMP RIH WITH FCO BHA#4.PUMP 8.3PPG W/ SAFELUBE FLUID 1BPM DOWN KILL LINE. PUMP 28PM/1157PSI DOWN COIL.OPSI WHP. 04:00 - 04:25 0.42 CLEAN P DECOMP j LOG DOWN FOR TIE-IN FROM 8940FT. CONTINUE TO PUMP 1BPM DOWN KILL LINE& 12.2BPM/800PSI DOWN COIL.OPSI WHP.PLUS 14FT CORRECTION.SHUT DOWN COIL PUMPS &CLOSE EDC.RESUME PUMPING DOWN COIL,2.16BPM/975PSI. 04:25 - 05:25 1.00 CLEAN P DECOMP RIH,CIRC AT 2.68BPM/1750PSI-CLEAN&DRY TAG TWICE AT 10371 FT.CLEAN UPTO 10330FT.RIH&TAG AT 10371 FT. 05:25 - 05:50 0.42 CLEAN P DECOMP LOG CCL UP FROM 10369FT TO 10000FT. PUMP 2BPM DOWN COIL/894PSI&1 BPM/OPSI DOWN KILL LINE. 05:50 - 07:00 1.17 CLEAN P DECOMP RIH TO 10300FT. PERFORM PUMPING PRESSURE 1 DIAGNOSTICS AS PER OCN#7. 07:00 - 09:20 2.33 CLEAN : P I DECOMP POOH. PUMP 1 BPM EACH DOWN CT AND KILL LINE WHILE POOH. 09:20 - 10:15 0.92 CLEAN N DPRB ! • DECOMP STOP AT 100 FT,LINE UP BOTH PUMPS ON THE KILL LINE PUMP 170 BBLS/30 MIN I SEAWATER. •PERFORM PJSM FOR CHANGE OUT BHA WHILE BULLHEADING. Printed 9/15/2015 10:24:28AM North America-ALASKA-BP Page 10 oak Operation Summary Report Common Well Name:14-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/15/2015 End Date 8/27/2015 X3-0172J-C:(2,993,246.40) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:NORDIC 2 Spud Date/lime:7/4/1981 12:00:00AM Rig Release:9/4/2015 Rig Contractor:NORDIC CALISTA UWI:500292052900 Active datum:42.90GL+28.5KB©71.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:15 - 11:00 0.75 CLEAN P DECOMP TAG STRIPPER. •DIAL IN 1 BPM DOWN THE KILL LINE. ALLOW THE PITWATCHER 10 MIN TO GET STABLE KILL LINE RATE INSTEAD OF A FLOWCHECK. • AFTER PITWATCHER IS SATISFIED WITH • RATE HE INFORMS DRILLER,OK TO BREAK INJECTOR. REMOVE INJECTOR AND PULL ASIDE. CONDUCT KICK DRILL,PITWATCHER CALLS • DRILLER AND INFORMS HIM THE KILL LINE PUMP JUST WENT DOWN. DRILLER SECURES WELL AS PER STANDING •ORDERS,PULLS BHA OUT AND SIMULATES • CLOSING BLIND RAMS. WELL SECURE IN 1 MINUTE. CONTINUE BHA CHANGE,MILL IS 3.79 NO-GO, NO WEAR. I PICK UP BHA#5,DRIFT ASSEMBLY. BHA OAL=61.29 FT. • 11:00 - 13:40 2.67 CLEAN P DECOMP 'M/U RISER AND PT QTS,READY BHI TOOL FOR RIH. RIH BHA#5. rTIE-IN DEPTH,CORRECT+4 FT. TAG 10373 FT. 13:40 - 15:00 1.33 CLEAN P DECOMP POOH WITH DRIFT BHA. . L /1.1 BPM DOWN CT. BLEEDPUMP OOA FROM 450LINE PSI TO 120 PSI. CONTINUE11 POOH. BPMKIL 15:00 - 17.30 2.50 CLEAN N j SFAL DECOMP LEAK SEEN ON INJECTOR. STOP POOH AND INVESTIGATE. LEAK IS ON INJECTOR HIGH PRESSURE PIPING,SLB MOBILISE MECHANICS FROM DEADHORSE. PJSM WITH DRILLER AND SLB SUPERVISOR FOR CLOSING BOPS. CLOSE UPPER PIPE/SLIP RAMS. MANUALLY LOCK RAMS. PUMP 1 BPM DOWN KILL LINE INTO WELL WHILE REPAIR TAKES PLACE. PERFORM LO/TO OF POWER PACK AND SCRS FOR REPAIR. 17:30 - 18:30 1.00 CLEAN P ' DECOMP POOH.PUMP 1BPM/OPSI DOWN KILL LINE. PUMP 1.25BPM/425PSI DOWN COIL.PJSM REGARDING KILLING WELL WHILE POH. 18:30 - 19:10 0.67 CLEAN N DPRB j DECOMP KILL WELL.3BPM/OPSI DOWN KILL LINE. 3BPM/1400PSI DOWN COIL THRU EDC. 19:10 20:20 1.17 CLEAN P W DECOMP PJSM REGARDING LD BHA&MU HIP STOCK BHA.PU INJECTOR&STAB ONTO WELL. POWER UP&TEST TOOLS.TEST QTS 250PSI/4000PSI.OPEN EDC.SET COUNTERS. 20:20 - 22:50 2.50 WHIP P WEXIT RIH.PUMP 1BPM/OPSI DOWN KILL LINE. PUMP 0.75BPM/8OPSI DOWN COIL.AT 8400FT,REDUCE TO 0.5BPM/OPSI DOWN KIL LINE&1.5BPM/271PSI DOWN COIL TO FILL/CATCH FLUID IN COIL,KEEPING RATE LESS THAN 2BPM PAST PACKER WS. 2250 - 23:50 1.00 WHIP P WEXIT LOG DOWN FOR TIE-IN FROM 8950FT.PUMP 0.5BPM/OPSI DOWN KIL LINE&1.5BPM/250PSI DOWN COIL.PUH&RE-LOG. PLUS 36FT CORRECTION.. Printed 9/15/2015 10:2428AM ' North America-ALASKA-BP Page 11 oLg3- Operation Summary Report Common Well Name: 14-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/15/2015 End Date:8/27/2015 X3-0172J-C:(2,993,246.40) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:NORDIC 2 Spud Date/Time:7/4/1981 12:00:OOAM Rig Release:9/4/2015 Rig Contractor:NORDIC CALISTA UWI:500292052900 Active datum:42.90GL+28.5KB @71.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) x23:50 - 00:00 0.17 WHIP P WEXIT 'CONTINUE TO RIH.PUMP 0.5BPM/OPSI DOWN I KIL LINE&1.5BPM/250PSI DOWN COIL. 8/21/2015 00:00 - 00:40 1 0.67 i WHIP i P 1 WEXIT ,CONTINUE TO RIH.PUMP 0.5BPM/OPSI DOWN j 1 '•KIL LINE&1.5BPM/250PSI DOWN COIL.WT j !CHECK AT 10315FT,46K,RIW=28K. 'ORIENTATE 45LOHS.TAG AT 10371 FT.PUH TO 00:40 - 00:45 0.08 WHIP P WEXIT ,CLOSE EDC.SET WS WITH TOP AT 10345FT.- 1100PSI TO SHEAR.SET 4K DOWN. 00:45 - 02:50 2.08 WHIP P WEXIT I PON.ROUTE RETURNS TO TT WHILE FILLING HOLE/POH.PUMP 1.64BPM/OPSI DOWN KIL LINE&1.5BPM/194PSI DOWN COIL.CLOSE CHOKE,8OBBLS PUMPED STILL NO RETURNS.PUMP 1.0BPM/OPSI DOWN KIL I 'LINE&1.5BPM/250PSI DOWN COIL WHILE POH. 02:50 - 03:20 0.50 KILLW N DPRB ' WEXIT I W KILL WELL.3BPM/OPSI DON KILL LINE. I I I I 3BPM/2500PSI DOWN COIL THRU TOOL. PJSM REGARDING HANDLING BHA WHILE KILLING THE-WELL.REDUCE RATE TO !i I i 1BPM/OPSI DOWN KILL LINE. 03:20 - 04:40 1.33 WHIP -P I I WEXIT POP OFF WELL.BREAK OFF TOOL.PLACE 1 INJECTOR OVER BUNG HOLE.STAND BACK I -BHI COIL TRAC TOOL.LD XO.LD WHIP STOCK SETTING BHA.OFF LOAD SAME.HOIST BOT EXTREME MUD MOTOR TO RF&DIAL UP TO 1 1 DEGREE AKO.MU WINDOW MILLING BHA. PU INJECTOR&STAB ONTO WELL.POWER UP& TEST TOOLS.TEST QTS 250PSI/4000PSI. L_- OPEN EDC.SET COUNTERS. 0440 - 06:30 i 1.83 WHIP P WEXIT RIH.PUMP 1BPM/OPSI DOWN KILL LINE. ___ _ PUMP 0.75BPM/80PSI DOWN COIL. 0630 - 07:00 0.50 WHIP I P WEXIT TIE IN DEPTH FROM 8950 FT. 07'00 - 08:30 1.50 WHIP N SFAL WEXIT GR MARKERS NOT SEEN,PICKUP TO 8850 FT AND RE-LOG. j ( I CORRECT+59 FT. CONTINUE RIH. 08:30 - 09:20 0.83 I WHIP N SFAL WEXIT TAG AT 10324 FT,ABOUT 20 FT HIGH. PICK UP AND DIAGNOSE DEPTH CONTROL ISSUES. RE-CHECK GR CORRELATION,OK. PICK UP AND CHECK MANUAL COUNTER AGAINST CTDS DEPTH,READINGS DIVERGE ' 6 FT AFTER POOH 1200 FT. - - 09:20 - 11:00 1.67 WHIP N SFAL WEXIT I CHANGE OUT DEPTH ENCODER. 11-00 - 12:30 1.50 WHIP N SEAL T WEXIT TIE-IN DEPTH FROM 8860 FT. CORRECT FT. TAG WHIPSTOCK AT 10338 FT. 12:30 - 14:00 1.50 STWHIP P WEXIT START TIME MILLING WINDOWAT 10337.0 FT. V1 PUMP 2.6 BPM DOWN CT FROM TRUCK, • CURRENTLY ROUND TRIPPING 5 TRUCKS. k4+-11 g PUMP 1 BPM DOWN CT ANNULUS VIA KILL LINE FROM PITS,MONITORED FROM PVT STRAPS. 14:00 - 16:30 2.50 STWHIP P I WEXIT CONTINUE MILLING WINDOW AT 10337.8 FT. MILLING SLOWLY TO TRY AND KEEP THE 'BENT MOTOR ON THE RAMP AS LONG AS POSSIBLE. - I •MILL TO 10338.70 FT. Printed 9/15/2015 10.24:28AM North America-ALASKA-BP Page 12 ot$5' Operation Summary Report Common Well Name:14-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/15/2015 End Date:8/27/2015 X3-0172J-C:(2,993,246.40) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:NORDIC 2 Spud Date/Time:7/4/1981 12:00:00AM Rig Release:9/4/2015 Rig Contractor:NORDIC CALISTA UWI:500292052900 Active datum:42.90GL+28.5KB©71.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 23:35 7.08 STWHIP P WEXIT CONTINUE MILLING FROM 10338.7 FT.PUMP 8.3PPG SEAWATER AT 1BPM/OPSI DOWN KILL LINE.PUMP 8.3PPG SEAWATER AT 2.6BPM/1721PSI DOWN COIL. MILL WINDOWAT 1FT/HR.7.52PPG ECD. PUMP 290BBLS OF VISCOSIFIED FLUID DOWN COIL-NO CHANGE IN RETURNS. POSSIBLE EXIT AT 10343FT. 23:35 - 00:00 0.42 STWHIP P WEXIT MILL 9FT OF RAT HOLE FROM 10344FTAT 10-30FT/HR. PUMP 8.3PPG SEAWATER AT 1BPM/OPSI DOWN KILL LINE.PUMP 8.3PPG SEAWATER AT 2.68BPM/1521 PSI DOWN COIL. 8/22/2015 00:00 - 01:00 1.00 STWHIP P WEXIT CONTINUE TO MILL RAT HOLE FROM 10344FT AT 10-30FT/HR. PUMP 8.3PPG SEAWATER AT 1 BPM/OPSI DOWN KILL LINE.PUMP 8.3PPG SEAWATER AT 2.68BPM/1521 PSI DOWN COIL. MILL TO 10354FT. 01:00 - 02:30 1.50 STWHIP P WEXIT DRESS WINDOW AT 1FT/MIN,3 TIMES UP/DOWN.PUMP 8.3PPG SEAWATER AT 1BPM/OPSI DOWN KILL LINE.PUMP 8.3PPG SEAWATER AT 2.68BPM/1521PSI DOWN COIL. DRY DRIFT WINDOW-CLEAN. 02:30 - 04:30 2.00 STWHIP P WEXIT POH.PUMP 8.3PPG SEAWATER AT 1BPM/OPSI DOWN KILL LINE.PUMP 8.3PPG SEAWATER AT 1.53BPM/350PSI DOWN COIL. 04:30 - 05:00 0.50 KILLW N DPRB WEXIT KILL WELL.3BPM/OPSI DOWN KILL LINE. 3BPM/2250PSI DOWN COIL THRU TOOL. PJSM REGARDING HANDLING BHA WHILE KILLING THE WELL.REDUCE RATE TO 1BPM/OPSI DOWN KILL LINE. 05:00 - 05:30 0.50 STWHIP P WEXIT PUMP 8.3PPG SEAWATER AT 1BPM/OPSI DOWN KILL LINE.POP OFF WELL.BREAK OFF TOOL.PLACE INJECTOR OVER BUNG HOLE. LD BHI COIL TRAC TOOL.MILLS WERE 3.79" NO-GO. 05:30 - 06:00 0.50 BOPSUR P PROD1 SD KILL LINE PUMP.SHUT IN WELL.PU TEST JOINT.PERFORM WEEKLY BOPE FUNCTION TEST USING RIG FLOOR PANEL.LD TEST JOINT.INSTALL NITE CAP.OPEN WELL.PUMP 8.3PPG SEAWATER AT 1 BPM/OPSI DOWN KILL LINE. 06:00 - 07:20 1.33 DRILL N DPRB PROD1 POSITIVE WHP ABOUT 5 PSI AFTER BEING SHUT IN ABOUT 30 MIN FOR FUNCTION TEST. NOTIFY ODE AND CTD SI. PUMP 170 BBLS/6 BPM WELL ON VAC. 07:20 - 08:20 1.00 DRILL N WAIT PROD1 CONTINUE FILLING 1 BPM,WAIT FOR HARDLINE CREW TO COME OUT AND INSTALL PUMP IN MANIFOLD FOR NEXT BOP TEST. 08:20 - 08:40 0.33 DRILL P PROD1 PJSM FOR M/U BHA. SHORT CHAIN TOP PORTION OF BHA,M/U BIT TO MOTOR. 08:40 - 10:20 1.67 DRILL C PROD1 HARDLINE CREW ARRIVES,REVIEW JSAAND INSTALL PUMP IN SUB. PT 4250 PSI,GOOD. 10:20 - 11:00 0.67 DRILL P PROD1 PJSM THEN M/U BUILD BHA#8. VERIFY FILL RATE WITH PITWATCHER. 1.76 DEG ULS MOTOR WITH 3.75 X 4.25 HCC BIT,RES INCLUDED. BHA OAL=80.43 FT. Printed 9/15/2015 10:24:28AM North America-ALASKA-BP Page 13-422.3- Operation Summary Report Common Well Name:14-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/15/2015 End Date:8/27/2015 X3-0172J-C:(2,993,246.40) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:NORDIC 2 Spud Date/Time:7/4/1981 12:00:OOAM Rig Release:9/4/2015 Rig Contractor:NORDIC CALISTA UWI:500292052900 Active datum:42.90GL+28.5KB @71.40usft(above Mean Sea Level) Date j From-To Hrs Task Code NPT NPT Depth j Phase Description of Operations (hr) (usft) 11:00 - 13:50 2.83 DRILL P PROD1 •RIH WITH BHA#8. PUMP 1 BPM DOWN KILL LINE,1.9 BPM 'DOWN CT WHILE RIH. STOP AT 8700 FT,DEPTH APPEARS OFF. •PARAFIN LIKE MATERIAL OFF THE CT IS COATING THE DEPTH ENCODER WHEEL, !INCREASING ITS DIAMETER SLIGHTLY AND 'THROWING OFF THE DEPTH MEASURE. TIE-IN DEPTH,CORRECT+135 FT. 13:50 - 14:30 0.67 DRILL N DPRB f PROD1 DISCUSS DEPTH ISSUES WITH ODE,GEO AND BHI. DECIDE TO TIE-IN DEPTH CLOSER TO TD THEN DRILL PAST THE RA AND RE-LOG TO TIE-IN THE RA. DISCUSS WITH MI ENGINEER GETTING DEEP CLEAN PRODUCT OUT TO HELP KEEP THE PIPE CLEAN COMING OOH. TIE-IN DEPTH FROM 10030 FT. CORRECT+6 FT. 14:30 - 15:20 0.83 DRILL P PROD1 RIH,CLOSE EDC. LOG DOWN FROM 10325 FT TO TD. FIND TD AT 10365 FT. PICK UP IS CLEAN 43K. 15:20 - 23:25 8.08 DRILL P ' PROD1 DRILL FROM 10364 FT AT 55 DEG INCLINATION. •ROP 0-50 FT/HR WITH 1-5K DWOB PUMP 8.5PPG 3%KCL W/0.6%SAFELUBE AT 1BPM/OPSI DOWN KILL LINE.PUMP 8.5PPG '3%KCL W/0.6%SAFELUBE AT 3.00BPM/2400PSI DOWN COIL. 1 FREE SPIN IS-2000PSI W/-500PSI MW. ECD=7.45 PPG. PUMP 10BBL SWEEPS OF 8.5PPG DRILLING MUD DOWN BACKSIDE AS NEEEDED. DRILL TO 10440FT. 23:25 - 23:30 0.08 DRILL P PROD1 11MPER TO THE WINDOW. PUMP 8.5PPG 3%KCL W/0.6%SAFELUBE AT 1BPM/OPSI DOWN KILL LINE.PUMP 8.5PPG j 3%KCL W/0.6%SAFELUBE AT ! 3.00BPM/2400PSI DOWN COIL. 23:30 - 00:00 0.50 DRILL P ! PROD1 I LOG DOWN FOR TIE-IN FROM 10287FT. PUMP 8.5PPG 3%KCL W/0.6%SAFELUBE AT 1BPM/OPSI DOWN KILL LINE.PUMP 8.5PPG 3%KCL W/0.6%SAFELUBE AT 0.7BPM/2400PSI DOWN COIL IN OPEN HOLE& NO PUMP RATE ACROSS WS. 8/23/2015 00:00 - 01:15 1.25 DRILL P PROD1 LOG DOWN FOR TIE-IN FROM 10300FT.TAG AT 10357FT.PICK UP&WORK THROUGH WS- CLEAN.RE-LOG. PUMP 8.5PPG 3%KCL W/0.6%SAFELUBE AT 1 BPM/OPSI DOWN KILL LINE.PUMP 8.5PPG 3%KCL W/0.6%SAFELUBE AT 0.7BPM/2400PSI DOWN COIL IN OPEN HOLE& • NO PUMP RATE ACROSS WS. +1 FT CORRECTION. "'CORRECTED TOP OF WINDOW IS 10350'. Printed 9/15/2015 10.24:28AM - ETY .I V1�-fLl SAD- GRAY 14-1 1 A NOTES: EP '( CHROMETBG**""' LO SSL EGLE> @10098'(18' ACTUATOR- BAKER C L 1 OKB ��_ 71, SHALLOWER P82 MEM GRI CCL LOG ON 114/17/11)"*` BF.ELEV= LiI KOP= 5200' "CONDUCTOR, - ?/ Max Angle= 91`@ 11610 -# ' 2221' -14-1/2"FES X NP,D=3.813" Datum NO= 10406 — _' Datum TVD= 8800'SS D- GAS LFT MANDRELS 13-3/8"CSG,72#,L-80 R3 BTC,D=12.347" H 2651' ST MD TVD DEV TY FE VLV LATCH PORT DATE ►'1' ►'1. 5 3166 3166 1 KGB-2 DMY BK 0 04/14/15 ESTIMATED TOC(TACK) --I -3150 �1� • * 4 4743 4743 0 KGB-2 DMY BK 0 04/14/15 ►:4� ,•• 3 6112 6021 33 KGB-2 DMY BK 0 08/15/10 7'1133K CSG,47#,L-80 TC11 XO TO L-80 BTC --I 3607' ►11 L* 11 2 7320 7004 44 KGB-2 DMY BK 0 04/13/10 .1/ 11 1 8822 8004 57 KGB-2 DMY BK 0 04/13/10 Minimum ID =2.370" @ 10117' �1j 11 3-112" X 2-7/8" LINER XO iV 1� 6930' 693—[ ED BKR PORTTIEBACK SEAL ASSY,D=6.16" r TISK CSG,26#,L-80 BTC-M, 6929' I V '� 6930' H7"X 9-5/8'BKR C-2 ZKP LTP,0=6.28' .0383 bpf,D=6.276' %-4 6945' -I9-5/8"X 7" BKR HMC LNR HGR,D=6.29" 9-5/8'CSG,47#,L-80 BTC(NPPON),D=8.681" - -7109 — 9-5/8"MLLOUT WINDOW(14-11A) 7109'-7125' 10067' -14-1/2"FES X NP,D=3.813" 10088' H7"X 4-1/2"BKR S-3 PKR,D=3.875" I I 10111' -14-1/2"HES MVP,113=3.813" 10130' -17"X 5"BKR ZXP LTPw RIEBK SLV,D=4.41" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, -f 10143' , 10131' J4-1/2"HES XN NP,D=3.80'(MUD 08/03/10) .0152 bpf,D=3.958" I P, 10143' 1-I4-1/2"WLEG,D=3.958-1 7 LNR 26#,L-80 BTC-M,.0383 bpf,D=6.276' -{ 10330' _\ HM 10152' -7"X 4-1/2"BKR C LNR HGR,D=4.41" 4-1/2"WHIPSTOCK(08/21/15) H 10350' 10159' -5'X 4-1/2"XO, D=3.96" — 2-7/8"JET CUT LNR(07111/15) -I 10360' _„ 4-112'MONOBOREWHPSTOCK(08/19/10) - 10370' _ PERFORATION SUu?NARY 4-1/2'MLLOUT WINDOW(14-11AL1) 10368'-10377' REF LOG: SPE RRY SUN MWD DGR 08/29/05 ANGLE ATTOP PERF: @ (II- Note:Refer to Production DB for historical perf data SIZE SPF NTSRVAL n/: SHOT SQZ I \ \ \ 14-11A \ 2-7/8” 6 10325-10328 0 03/21/10 2-7/8" 6 10328-10348 0 03/21/10 4-1/2" SLID 10412-10650 0 09/14/05 I I PBTD 11785' \ 4-1/2" SLID 11146-11802 0 09/14/05 \ \ \ 14-11AL1 ',Will 2-7/8" SLID 10617-11172 0 08/25/10 2-7/8' SLID 11417-11785 0 08/25/10 I I ��. 2-7/8"LNR,6.16#,L-80 SIL, 11818' ew ,•••.•j .0058 bpf,0=2.441" 4-1/2"LNR, 12.6#,L-80 BTC/eT-M, -j 11804' .•:•.4 .0152 bpf,ID=3.958' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/04/81 PKR 191 ORIGINAL COMPLETION 09/04/14 WKWJMD PULL LATCH(08/30/14) WEI: 14-11A 09/15/05 N2ES SIDETRACK(14-11A) 04/22/15 JLS/JMD GLV GO(04/14/15) PERMIT No: 2051260,2100940 08/25/10 NORDIC 2 CTD SIDETRACK(14-11AL1) 07/11/15 GTW/PJC JET CUT 2-7/8"LNR AR No: 50-029-20529-01,(60) 09/19/10 MK/PJC FINAL DRLG CORRECTIONS 07/21/15 PJC REFORMAT-PRE RIG CLEANUP SEC 9,T10N,R14E, 1776'FNL&'1760'FEL 04/23/11 MSS/PJC SET LIP SNAP LATCH(4/18/11) 09/01/15 TR/JMD REMOVED LNR/SET WS 11/06/13 TM/M) CORRECTED MFI D BP Exploration(Alaska) ., of ry • (---- -- \����� - 4, THE STATE Alaska Oil and Gas s �, of L K / , Conservation Commission i -# 333 West Seventh Avenue F GOVERNOR BILL WALKER Anchorage Alaska 99501-3572 Main. 907 279 1433 (4,ALASItt)' ED 1t I� 0 - '2.c3 5 Fax 907.276 7542 SC j� i J V V www.aogcc alaska go John McMullen Engineering Team Leader ` BP Exploration(Alaska), Inc. -Q0 °-# 1 .:;..„----------- P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 14-11A Sundry Number: 315-289 Dear Mr. McMullen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 3 L05.080, within 20 days after written notice of this decision,or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ial SZ-1/4— Cathy . Foerster Chair DATED this 2day of May, 2015 Encl. STATE OF ALASKA .C; ALAS..,,OIL AND GAS CONSERVATION COMM,,,3ION APPLICATION FOR SUNDRY APPROVAL MAY 12 2015 20 AAC 25.280 J -5 f 2--T / / 1. Type of Request. AO G C C ❑Abandon • ®Plug for Redd! 0 Perforate New Pool 0 Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate ❑Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic 205-126 • 3. Address: ®Development 0 Service 6. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-20529-01-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 14-11A • Will planned perforations require a Spacing Exception? 0 Yes-121 No 9. Property Designatior 10.Field/Pool(s): ADL 028312 ' Prudhoe Bay/Prudhoe Bay • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured) 11804' • 9 U.3. i3'1. 11804' ' �2231Jg869�jA- ,S None None Casing LengthSize MD ND S Burst Collapse Structural Conductor 80' 20" 31'- 111' 31'- 111' 1530 520 Surface 2621' 13-3/8" 30'-2652' 30'-2652' 4930 2670 Intermediate 7081' 9-5/8" 28'-7109' 28'-6843' _ 6870 4760 Production 10304' 7" 26'- 10330' 26'-8828' 7240 5410 Liner 1674' 4-1/2" 10130'- 11804' 8714'-8909' 8430 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft). 10325-10348',Slotted 10412'-11802' 8825'-8838',Slotted 8875'-8909' 4-1/2" 12.6# 13Cr80 10145' Packers and SSSV Type. 4-1/2"Baker S-3 Packer Packers and SSSV 10090'/8691' MD(ft)and ND(ft): 12. Attachments. 13.Well Class after proposed work: ®Description Summary of Proposal ®BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic ®Development 0 Service 14. Estimated Date for 15 Well Status after proposed work: Commencing Operation. July 1 2015 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval. Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative. 0 WAG 0 SPLUG ®Suspended - 17. I hereby certify that the for-go.•• is tr e an• •rrect to the best of my knowledge. Contact: Nathan Sperry,564-4258 rt parr/ Printed Name' JohTitle. Engineering Team Leader E il: athan Sperry@bp.com ��/ /� Signature Phone: 564-4711 Date: l� �� Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: . 6 ^2<t<C( i ❑Plug Integrity BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: 1 e)p ¢CS t- fie, 25-i, ohs, (✓fr2 psP Is 244Z7, 5;J 4-ii k-n-//C/Y' 171 e r/-G vi ttr 7t / 7`.e7 ZJ-Ci ,O ' - /-1-6ftki Gt. f-cp/L -_ p <<1-2zl .1f-4_pprvri,--ca' prc 2 24-A-C 25—, Giz (-- L) Spacing Exception Required? 0 Yes [/No Subsequent Form Required. j _ z G 7_ / �,l � APPROVED BY Approved By: / COMMISSIONER THE COMMISSION Date: S -Z7 — /' F 03 'fit viaGicmisAiror12 months from the date of approval Submit In Duplicate To: Alaska Oil & Gas Conservation Commission From: Nathan Sperry bp CTD Engineer Date: May 8th, 2015 Re: 14-11A Sundry Approval Sundry approval is requested to plug the 14-11A and 14-11AL1 perforations and slotted liner as part of the drilling and completion of proposed 14-11B coiled tubing sidetrack. History and current status: 14-11A was a Zone 4 producer drilled and completed in 2005. The 14-11AL1 Zone 4 lateral was added in 2010. The 14-11AL1 leg encountered several faults that brought water into the parent well and made the laterals uncompetitive. All wellwork options have been exhausted and the well is no longer competitive. Proposed plan: 14-11 B will exit from well 14-11A by the Nordic 1 Coiled Tubing Drilling rig on or around August 1st, 2015. The 14-11B sidetrack will exit through the existing 4-1/2" liner and kick off in the Shublik, and target Zone 4 reserves. The proposed sidetrack is a -2,600' horizontal Ivishak Zone 4 producer, which will access a -33 acre reserves target off of drillsite 14. The lateral will be completed with a 3-1/2" X 3-1/4"X 2-7/8" chrome liner which will be fully cemented and perforated. This Sundry covers plugging the existing 14-11A and AL1 perforations and slotted lienr via the 14-11B liner cement lob or a liner top packer set post rig with slick line if liner lap test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. 7-4€ �l p/ockCti"O 4 fr,O/- J(�/'l,, r,/ /ester g( re C7rC//. 1,ter lac rye ��fc o,l frod ,�.� d (' ro fo _ A q ,,,,atri crit- I" access o..1 9? %. i4 ,'S l,�e�/ 4gf cwrei i kit 411, �� file r Qv )r,',rr valve at a f';Dom, 7* Y we!t (a re d ' '��o`'%/v P1119,* ',� c 0,e00ce co froom' The fa's/ Pre-Rig Work(scheduled to begin July 1St,2015) 1. E Cut existing 2-7/8"AL1 liner at the window. 2. C Catch and release liner. 3. V Pre-CTD tree work. 4. V Set TWC. 5. 0 Remove wellhouse and level pad. Rig Work(scheduled to begin August 1st, 2015) 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (MASP 2,442 psi) 2. Pull TWC. Bullhead kill well. 3. Fish liner. 4. Drift and caliper to 10,370' MD. 5. Set 4-1/2" packer WS at 10,350' MD 45 deg LOHS. 6. Mill 3.80"window and 10' of rathole. 7. Drill build: 4.25" OH, 340' (20 deg DLS planned). 8. Drill lateral: 4.25"OH, 2,260' (12 deg DLS planned). 9. Run 3-1/2" x 3-1/4"X 2-7/8" Chrome liner leaving TOL at-10,095' MD. 10. Pump primary cement job: 33 bbls, 15.8 ppg, TOC at TOL * 11. Perform liner cleanout and GR/CCL log. 12. Perform liner lap test to 2,400 psi 13. Perforate liner based on log interpretation (-500'). 14. Freeze protect well to 2,500' MD. 15. Set TWC; RDMO. Post-Rig Work 1. 0 Re-install wellhouse, flow line and pull TWC 2. S Set 45KB liner top packer if needed * 3. S Set GLV's *Approved alternate plug placement per 20 AAC 25.112(i) Nathan Sperry CTD Engineer 564-4258 CC: Well File Joe Lastufka TREE= FMC I1/1a LHFAD= GRAY 14-11A �YSL '(U.__JNI @1 1 I0CTUA_EV= 72'= BAKER oK6.�EvLl SHALLOWER PER MEM GRI CCL LOG ON 04/17/111**' BF ELEV= KOP= 5200' Max Angle= 91"@11610' ' 2221' H4-1/2"HES X NP,D=3.813" Datum NU= 10406 Datum TVD= 8800'SS 3150' HEST TOP OF TEBACK CMT 13-3/8"CSG,72#,L-80,D=12.347" — 2651' GAS LFT MANDRELS IV V. ST MD 1 TVD DEV TYPE 1 VLV LATCH PORT DATE 11 !• 5 3166 3166 1 KGB-2 DOME BK 16 08/31/10 Minimum ID =2.370" @ 10117' .14 •• 4 4743 4743 0 KGB-2 SO BK 20 08/31/10 3-1/2" X 2-7/8" XO 1�� .1 3 6112 6021 33 KGB-2 DMY BK 0 08/15/10 11*1 *• 2 7320 7004 44 KGB-2 DMY BK 0 04/13/10 t�� �` 1 8822 80041 57 KGB-2 DMY BK 0 04/13/10 6930' H7"BKR FORTED TEBACK SEAL ASSY,D=6.16' I 7"TEBACK CSG,26#,L-80 — 6930' I a 6930' —H 7"X 9-5/8"BKR C-2 ZKP LTP,D=6,29" TC-WBTC-M,D=6.276" 1 —'' 6945' H 9-5/8"X 7" BKR HMC LNR HGR,D=6.276" 9-5/8"CSG,47#,SOO-95 BTC,D=8.681" H 7109' I— 9-5/8"MILLOtJT WINDOW(14-11A) 7109'-7125' I 10067' —4-1/2"HES X NP,ID=3 813" 10088' —17"X 4-1/2"BKR S-3 RCR D=3.875" /y /v - - 10116' -I3-1/2"DEPLOY SLV,D=2.970"(SEE SAFTEY NOTE) L 10111' I--4-1/2"1-ES X NP,0=3.813"(BEHIND LNit) 10117' H3-1/2"X 2-7/8"LNR XO,D=2.370" -r 10130'1H-7-X 5"BKR ZXP LTP w/TEBK SLV,D=4.411 4-1/2"TBG, 12,6#,13CR-80 VAM TOP, —10143' I 1{3131' H4-1/2"I CS XN NP,ID=3.80"(MLLED 08/03/10) .0152 bpf,0=3.958" 10143' H4-1/2"WLEG,D=3.958" BEHIND 7"LNR 26#,L-80 BTC-M, I— 10330' CT LNR .0383 bpf,D=6.276" , \ 10152' I—7"X 4-1/2"BKR HMC LNR HGR,D=4.41" 4-1/2"MONOBORE WHIPSTOCK(06/19/10) H 10370' , 10159' --{5"X 4 1/2"XO, D=3.96' PERFORATION SUIWARY j REF LOG: SPURN' SUN MWD DGR 08/29/05 4-1/2"MLLOUT WINDOW(14-11AL1) 10369'-10377' ANGLE AT TOP PERF: @ Note:Refer to Production DB for historical pert data 11111, SZE SPF INTERVAL OpnlSgz SI-OT SOZ \ 14-11A \ 2-7/8" 6 10325- 10328 0 03/21110 I I \ \ 2-7/8" 6 10328- 10348 0 03/21/10 \ 4-1/2" SLID 10412- 10650 0 09/14/05 I , 4-1/2" SLTD 11146- 11802 0 09/14/05 I I �Tp� 14 11AL7 Il Il \ MEM 2-7/8" SLTD 10617- 11172 O 08/25/10 14-11A \ \ \ 2-718" SLID 11417- 11785 0 08/25/10 2-7/8"LNR,6.16#,L-80 STL, 11818' �i. 4-1/2"LNR,12.6#,L-80 BTC/BT-M, — 11804' V4! 0058 bpf,D=2.441" 0158 bpf,D=3.958" •..•.*: DATE REV BY COMMEMS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/04/81 PKR 191 ORIGINAL COMPLETION 09/19/10 MK/PJC FINAL DRLG CORRECTIONS WELL: 14-11A 09/16105 NZEB SIDETRACK(14-11A) 04123/11 MSS/PJC SET LW SNAP LATCH(4/18/11) PERMIT No: 2051260,2100940 08/26/10 NORDIC 2 CTD SIDETRACK(14-11AL1) 11/06/13 TMIJMD CX RRE-CT )MIND AR No: 50-029-20529-01,(61) 08/29/10 PJC DRL.G DRAFT CORRECTIONS 09/04/14 WKFRJMD PULL LATCH(08/30/14) SEC 9,T1ON,R14E,1760'FEL &1776'RV_ 09/01/10 CSR/PJC PERF CORRECTIONS — 09/01/10 JLJ/AGR GLV GO(08/31/10) 1 BP Exploration(Alaska) TREE= FMC W43l�1D- -_ GRAY i slily CFROMETBG LOT03: WELL YSLffi/Ela 10098'(18' ACTUATOR= BAKERC L 1 OKE.ELEV= —, 72, SHALLOWER PER MEM GRI CCL LOG ON 04/17/11)""" �______._.____ Kole _._____-____. 5200' /I/ Max Angle 91'611610' 1 2221' H4-1/2"HIS X NP,D=3.813" Datum MD= 10406 Datum TVD= 8800'SS 3150' HEST TOP OF TIEBACK CMT 13-3/8"CSG,72#,L-80,ID=12.347' - 2651' GAS LFT MANDRELS S �1 ST MD ND DEV TYPE VLV LATCH RORT DATE yid 5 3166 3166 1 KGB 2 D�A1' BK T 0 04/14/15 Minimum ID =2.370" @ 10117' )��1 4 4743 4743 0 KGB 2 DMY BK 0 04114115 3-1/2" X 2-7/8" XO ):S: 3 6112 6021 33 KGB-2 DIY' BK 0 08/15/10 T — 1��+ 2 7320 7004 44 KGB-2 l7MY BK 0 04/13/10 �'� 1 8822 8004 57 KGB-2 DMY BK 0 04/13/10 ►114 i 1 6930' --17"BKR PORTED TACK SEAL ASSY,D=6.16" 17"TEBACK CSG,2i,L-80 H 6930' '�j i 6830' r X 9-5/8'BKR C-2 ZKP LW,D=6.29" ITC-11/BTC-M,D=6.276' J 0 6945' H9-5/8"X r BKR HMC LNR HGR,D=6.276" 9-5/8"CSG,47#,SOO-95 BTC,D=8.681" - T109' — 9-5/8"MILLOUT WINDOW(14-11A) 7109'-7125' i 1006T H4-10"HES X NP,D=3.813" 10088' --17-X 4-1/2'BKR S-3 PKR,ID=3.875" 10116' —3.70'DEPLOY SLV,13=2.970'(SEESAFTEY NOTE) 10111' j-4-112"HES X143,D L)=3.813"(BB LM4) 10117' -3-12"X 2-7/8"LNR XO,D=2.370' 10130' J-{TX 5"BKR ZXPLIP wfrE BKSLV,D=4.41' 1412"TBG,12.6#,13CR 80 VAM TOP, 10143' I 10131' H4-1/2"NEB XN NP,D=3.80'(MLLED 08/03/10) 1.0152 bpf,1 =3.958" 10143' --14-1/2'WLEG,D=3.958' BEHIND 7"LMR,26#,L-80 BTC-M, 10330' ` I CT LNR .0383 bpf,D=6.276" 10152' I T X 4-1/2"BKR HMC LP HGR,D=4.41' 4-1/2"MONOBORE WHPSTOCK(08/19/10) H 10370' 10159' 1-15'X 4-1/2"XO, 13=3.96' PERFORATION SUMMARY REF LOG: SP62FZ1'SUN MWD DGR 08/29/05 4-1/2'PI LOUT VMNDOW(14-11AL1) 10369'-10377' ANGLE AT TOP PE RE Note:Refer to Reduction DB for historical pert data Ill I Est.cut depth at TOWS. RA tag fSIZEI SPF MT3NAL 10pn/Sqz SHOT 1 SOZ \ should be 9'deeper than TOWS. 14-11A \ j 2-7/8" i 6 10325-10328 0 03/21/10 ( \ \ 2-7/8' 6 10326-10348 0 03/21/10 \ ���� j 41/2" SLID 10412-10650 0 09/14105 4-1/2" SLID 11146-11802 0 09/14/05 I ( PBTD 11785' 14-11AL1 2-7/8" SLID 10617-11172 0 08/25/10 1411A \ \ \ 2-7/8" SLID 11417-11785 0 08/25/10 � 1 't". 14.ia' 2-7/8"LNR,6.16#,L-80 SIL, 11818' ` s, �� ;o 1412"LNR,12.65,L-80 BTCJBT--M, --{11804' .0058 bpf,I)=2.441" .0158 bpf,D=3.958" DATE REV BY OOALUITS DATE REV BY COMMENTS PRUDHOE BAY LMT 108/04/81 Pi R 191 ORIGINAL COMPLETION 09/19/10 MK/PJC MAL DRLG CORRECTIONS WELL.: 14-11A 109/16/05 N2B5 SIDETRACK(14-11A) 04/23/11 MSS/PJC SET LW SNAP LATCH(4118/11) FAIT No: 2051260,2100940 08/26/10 NORDIC 2 CTD SIDETRACK(1411AL1) 11/06/13 TPNJMD CORRECTED MN D AR Pb: 50-029-20529-01, 08/29/10 PJC DRLG DRAFT CORRECTIONS 09/04/14 WIF/JMD PULL LATCH(08/30/14) SEC 9,Ti ON,R14E,176d Fa&1776'FNI- 09/01/10 CSR/PJC PERF CORRECTIONS 04/22/15 JLS/JMD GLV 00(04/14115) 109/01/10 JLJ/AGR GLV CJO(08/31/10) BP Exploration(Alaska) TREE= FMC VVaLHE AD= GRAY 14-1 1 SAFETY NOTES: Wt3L ANGLE>70'a 10459''"' " ACTUATOR= BAKER C CHROME TBG'""" OKB.ELEV= 72' BF.ELEV= KOP= 5200' Max Angle= 91 Q 11610' , 2221' —4-1/2'HES X NP,D=3.813" Datum MD= 10406 'Datum TVD= -8800'SS 3150' HEST TOP OFTEBACKCMT 13-3/8'CSG,72#,L-80,D=12.347" j— 2651• GAS LFT MAN 7Rfl S v4 ST MD ND DEV TYPE VLV LATCH FORT DATE ii::: U , 5 3166 3166 1 KGB-2 DM'( BK 0 04/14115 9. 4 4743 4743 0 KGB-2 DAY BK 0 04114!15 ;. 3 6112 6021 33 KGB-2 01441 BK 0 08115/10 .. �� 2 7320 7004 44 KGB-2 DAY BK 0 04/13/10 1 8822 8004 57 KGB-2 DMY BK _ 0 04/13/10 �� 6830' H 7"BKR PORTED TEBACK SEAL ASSY,D=6.16" 1 7'TIEBACK CSG,26#,L-80 6930' 6830' —i 7"X 9-5/8'BKR C-2 ZKP LW,D=629" 1 (TGIYBTGM,D=6.276' I _ 6946' H9-5/8"X 7" BKR HMC LNR HGR,D=6.276" 9-5/8"CSG,47#,SOO-95 BTC,D=8.681" H 7109' 1— 9-5/8"FALLOUT WINDOW(14-11A) 7109'-7125' 10087' H4-1/2"HES X NP,D=3.813" 10088' --17"X 4-1/2"BKR S-3 PKR,D=3.875"1 4-1/2"TBG,12.6#,13CR 80 VAM TOP, —I 10143' .0152 bpf,13=3.958' 10111' -14-1/2'HES XNP,D=3.813" r LNR,26#,L-80 BTC-M, I- 10330' TOL at 10.095'MD TOC to TOL. .0383 bpf,D=6.276' J —10.13-1—r-1-17"X 5"BKR ZXP LTP w/7ti33K SLV,D=4.41"1 i 10131' —14-1/2"FES XN PP,D=3.80"(MLLED 08/03/10) u 10143' —f 4-1/2"WLEG,D=3.958' BEHIND 4-1/2"packer WS set with TOWS at 10,350'MD �I T LNR �l 10162' --17"X 41/2"BKR HMC LNR HGR,D=4.41" 4-1/2'MONOBORE VVHPSTOCK(08/19/10) — 10370' L, 10168' Hy X 4-1/2"XO, D=3-96' -3-1/2"x 3-1/4"XO at 10,115' PERFORATION SUMMARY REF LOG: SPERRY SUN MWD DGR 08/29/05 ANGLE AT TOP PERE -3-1/4"x 2-7/8" 2-7/8" 13Cr to Note:Refer to Production DB for historical pert data lib. XO at 10,675' 12,950'MD TD �` SIZE SPF I Iff AL IOpn/Sqz SHOT SOZ \ 14-11A \ 2-7/8" 6 10325-10328 0 03/21/10 II - \ 2-7/8" 6 10328-10348 0 03/21/10 \ 4112" SLID 10412-10650 0 09/14/05 4-1/2" SLID 11146-11802 0 09/14/05 pgm J 14-11AL1 \ �— 2-7/8" SLID 10617-11172 0 0825/10 'V'.1 \ \ \ \ 2-7/8" SLID 11417-11785 0 08/25/10 I A. 2-7/8"LNR,6.16#,L-80 SIL, I 1181W ,00- 4-12"LNR,12.6#,L-80 BTC/BT-M, I— 11804' .0058 bpf,D=2.441" .0158 bpf,D=3.958" J DATE REV BY COMMENTS �I DATE REV BY COt& 'ITS PRIAHOE BAY LH 08/04/81 PKR 191 ORIGINAL COMPLETION 09/19/10 MK/PJC FINAL DRLG CORRECTIONS WELL: 14-11A 09/16/05 N2E5 SIDETRACK(14-11A) 0423/11 MSS/PJC SET LIP SNAP LATCH(4/18/11) FERMI Pb_ 2051260,2100940 08/26/10 NORDIC CTD SIDETRACK(14-11AL1) 11/06/13_TMJMD CORRECTS:I MIN D API Pb: 50-029-20529-01, 082CMG9/10 PJC OG DRAFT CORRECTIONS 1 09/04/14WKP/JMD PULL LATCH(08/30/14) SEC 9,T1ON,R14E,1760'FE &1776'FPL 09/01/10 CSR/P3C PERF C CTIONS 104/22/15 JLS/JMD GLV 00(04/14/15) 09/01/10 GLV 00(08/31/10) 1i BP Exploration(Alaska) I© I;,,"2' .1 ,— $ a-I "' rc O C m O //� Q b 8 g 2 52 Y 9 1111 m al011 u u c 3 1 .1. 60 E ,. X i'�!i' 1 1 1 P °° I< I< i O —ill 0 E 4 . MI kw kJ 1 II I VV1 a O ^� I_ m s 1 (J O m _I I t o 1I. II ' I II : i_==' ii * I O 111 ^11 I Y 1111 III L.L. iii i 1 0 a ' 0 - 0 . m x Z I Y• I11I d 111 4 Q I v Y • II I g I u1 III Z I 1 m O I ��., U 1.i > > WE W1Y I11 I11 Jtip ;0 1,1 : __ WLL 11 • 111 I ildia. Flii ■ I II CICO V 1 n 71 : l a _i5 O Iii LLIY i I Ci 92U .12 O �t c __ ii._ Q h ti _ V/ a1 J I &1 Q o (.) 12 E 1 U_ I 1 & 13 m I Ce I m y o O o , IEC- N 1i1 v a pilE I Zi1 LI - C 00 4 I M 0 K S., .1 e' I ¢ ED 111 I 1 rvo 112 I • I ® EE ' Q Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the Patricia or Steve / ' upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Patricia or Steve work) the initial reviewer will cross out that erroneous entry and initial it on r / both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states"Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change Jenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. I o Www c L� ta- C7 m tio U Cj, _f 8 N rp `u QJ t� n3 lO W Y U > (N. o u v m U a) ra FAY 0 Q L N m a 2 cx to a v o N 0F- a L s C Z O0 ''' F- >- 0 K Y O o 0. U in > N o c O , -a t Ln — • O} Q Q m Q "3 �a Q Q c`c Y@ W L -a fO a v o m o r; a CO N tO c.•) tf) O) N O c G) 0a) 0_ — 0 u 'O E O >. U a- 1. > N ra = a) (0 0 0 0 0 0 0 0 0 0 04-, U L L O- W J J J J J J J J J r0 a1 U }: W W W W W W W W W m e ro -Q O .-+ F- LL LL LL LL LL LL LL LL LL An a) E -0 ' o Q J J J J J J J J J — - O = a) U) Q Q Q Q Q Q Q Q Q C O C Z Z 2 Z Z Z Z 2 2 u 13 v 0 LL LL LL LL LL LL LL LL LL a)) c v a) (0U a OU Fy�� E ( o 0 U — Q 1 p c o .0 C v 0 " @ as a) a ,-.7- ,—. r-. O V + — E IlD V F J J r < a) .O UU > �_ 5 T W N LL 3 m F- F- m N yr: br C L o D D O p U p 2 2 0 ,� J u.- a LL W LL (A m W — N g F O y CO co a X X W T1 f. .yLLI -D W 0 0 8 � a - :; GI ° '" Wo >- r Zc 44 71 00 t' U lc 00. J J J O J J O O J \ Z 2 2 2 2 Z F ) e).-- --)Pm — -trvWf vVi W W W W0 2 2 01 IP T >, >. >. >. >. T a' Z � mmmmmmm CL z 0 ° 0000000 0 ® p (n L L L L L L `� J In -o "0 a 10 a -8 -0 O L W C 0 7 7 7 7 0 7 tJ la �r) LL 0. O. aaa aaa Y 0 o0 >' CV X v) a 0 4.....0, °. LO M O tOaO N V CO U WR 0 N N N 0 0 N NCDN co0 0 cp 0Q U000200 IOC Q Q M 0 Q M t0 N U E Uil W p 000 04 c 41) alet x (co 0 0 O O N 0 O N 0 (0 0 0 o O U 0 O 0 0 O U N CO O O O N (0 O aO M \ v• M O G) N 0 N CO OZ C E CO N 0 CO N N CO )n N) N M N N 0 0 0 M to O N N N N N N N N N N U n O O O O O) O) O W O) O = p N N N N N N N N N �+ Q1 O O O O O O O O O ` cu O O O O O O O O O In l[) to to to N c() N 1() 0 a) C. 00 C a U L) Q� E a) CO a� v > v {f a - Q D a0 co m N r. m Q N (0 a) Y a 01 OD M Z u) M N e- N E d F- (Cp a Q N ', J J a (9 o a Z v m v , x co c 0 CID (�od � /n F`- a a Q • 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. p`ZQ~ - ,~ p~ ~ Well History File Identifier Organizing (done> RESCAN `Color Items: V~reyscale Items: ^ Poor Quality Originals: ^ Other ,.o,aea iuuimuiiiiuu D{GITAL DATA iskettes, No. ~- ^ Other, No/Type: Re,~a~~e~~ iuiuiiiuliuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: /s/ Project Proofing III IIIIIIIIIII 11 III BY: Maria Date: ~, ~ D /s/ Scanning Preparation ~ x 30 = ~ ~ + ~ -- TOTAL PAGES ~~ (Count does not include cover sheet) BY: ~ Maria Date: ~, a„I ~ ~ ~ ~ /s/ ~, Production Scanning ' + IIIIIII~IIIIII VIII Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ a„~ ~~ ~ ~ /s/ / V Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO ~ r BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 11 I II !I II ~ II it 1 I Ill ReScanned II I II ~I II I I III I I III BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III II'I III 10/6/2005 Well History File Cover Page.doc SchU~mherger Alaska Data & Consulting Services 2525 Gambell Street, Suhe 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description Date BL D3-37 09AKA0188 OH MWDA-WD EDIT - t 02/14/10 2 1 07-238 09AKA0078 OH MWDA-WD EDIT 01/10/10 2 1 V-123 BBKA-00002 CH EDIT PDC SCMT 01!15/10 1 04-02 06.12A X-04 B74B-00099 AP3O-00081 BBSK-00012 INJECTION PROFILE .' PRODUCTION PROFILE LDL ~ 03/23/10 03/21!10 -03/14/10 1 1 1 1 1 1 03-28 14-11A 15-31B 89RH-00017 83S0-00050 AP3O-00082 PRODUCTION LOG - PERF RECORD & FL BHP ~ LDL ~- 03/18/10 /20/10 03/22/10 1 1 1 1 1 1 03-t0 14-07 03-11 12-26 P2-22 P2-22 69RH-00018 8146-00098 89RH-00019 ANHV-00121 BBSK-00011 BBSK-00011 INJEC ION PROFILE PERF RECORD & FLOWING BHP INJECTION PROFILE - PRODUCTION.PROFILE - USIT CORROSION DATA - USIT CEMENT DATA 03/21/10 03/22/10 03/22/10 03A8/10 03/11/10 03/11/10 1 1 / 1 1 1 1 i 1 1 1 1 - 03-28 B9RH-00017 CBL - 8 03/19/10 1 1 15-30A BSJN-00045 SCMT - 03/22/10 1 1 MPS-08 BBUO-00009 USIT - 03/12/10 1 Y PLEASE ACKNOWLEf]GF wFr` ato7 av crruru r_ wren oeruoruar_ nun ....,,.. ~...,. ~,.. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. 03/25/10 . _,~~a .... .. ~: :s ~... :...k N0.5481 Company: State of Alaska n ~,) (-} ~ ~",y ') (1 a (~ Alaska Oil & Gas Cons Comm f 9 I \ a.+' / U Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ,. b° ~: ~. Color CD .~AR4f°I' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2638 c~ '1 STATE OF ALASKA - ALASKA AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 62ECEIVED MAR ~ 1 2010 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ ther O Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ ~ pa~ ~ Time Extt V~1pW1la.s~ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ ~DCIIL~189~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development 0 Exploratory ^ 205-1260 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorage, AK 99519-6612 50-029-20529-01-00 8. Property Designation (Lease N mber) : 9. Well Name and Numbe ` ADLO-028312 PBU 14-11A 10. Field/Pool(s): PRUDH OE BAY FIELDy PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11804 feet Plugs (measured) None feet true vertical 8908.7 feet Juhk (measured) None feet Effective Depth measured 11804 feet Packer (measured) 10888 true vertical 8908.7 feet (true verticap 8690 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 94# H-40 SURFACE - 110 SURFACE - 110 1530 520 Surface 2651 13-3/8" 72# L-80 SURFACE - 2651 SURFACE - 2651 4930 2670 Intermediate 6843 9-5/8" 47# L-80/SOO-9: SURFACE - 7109 SURFACE - 6843 6870 4760 Production Liner 10306 7" 26# L-80 24 - 10330 24 - 8828 7240 5410 Liner 1674 4-1/2"12.6# L-80 10130 - 11804 8714 - 9032 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1 /2" 12.6# 13CR80 SURFACE - 10143 SURFACE - 8722 Packers and SSSV (type, measured and true vertical depth) 7"X4-1/2" BKR S-3 PKR 10888 8690 12. Stimulation or cement squeeze summary: Intervals treated (measured): ryry 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: 233 495 4130 262 Subsequent to operation: 186 822 4482 258 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ 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 Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 3/31/2010 ruins Iu-wuw QfC VISCU I/GUU.7 . `~y~'~V.. A~U (- ~, ']O'~(~ `-=~G~~ ~A ~ 1r ou i u vn n~ai viuy 14-11A 205-126 PERF ATTACWMENT Sw Name O eration Date Perf O eratton Code Meas De th To Meas De th Base Tvd De th To Tvd De th Base 14-11A 9114105 SL 10,412. 10,650. 8,874.54 8,888.88 14-11A 8114105 SL 11,146. 11,802.; 9,005.86 $,908.06 14-11A 3121110 APF 10 325. 10,32$. 8 825.46 $,$27.15 14-11A 3121110 APF 10,328. 10 348. 8,827.15 8,838.39 AB ABANDONED PER PERF APF ADD PERF RPF REPERf BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED M[R MECHANICAL ISOLATED REMOVED S(~Z SQUEEZE MtS MECWANICAL ISOLATED STC STRADDLE PACK CLOSED MLK MECWANICAL LEAK STO STRADDLE RACK OPEN ~ OW OPEN WOLF ~ • ., ~ • 14-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/20/2010""*WELL FLOWING ON ARRIVAL""* (E-LINE: FLOWING BOTTOM HOLE ~ PRESSURE AND UNDERBALANCED ADPERFS) ~ =WELL SHUT IN DURING MEETING WITH PAD OP INITIAL T/I/O: 1100/2000/0 PSI LOG JEWELRY PASS FOR GUN CORRELATIONS. LOG STOP COUNT AND WATCH FOR PRESSURE TO STABILIZE, GAINING 1 PSI PER MINUTE. '`**** CONTINUE AWGRS ON 21-MAR-10 ***** 3/21/2010'`'`*"" CONTINUE AWGRS FROM 20-MAR-10 ***** ***WELL FLOWING ON ARRIVAL"*" (E-LINE: FLOWING BOTTOM HOLE PRESSURE AND UNDERBALANCED ADPERFS) WELL IMMEDIATELY SHUT IN DURING MEETING WITH PAD OP INITIAL T/I/O: 1100/2000/0 PSI LOG JEWELRY PASS FOR GUN CORRELATIONS. LOG STOP COUNT AND WATCH FOR PRESSURE TO STABILIZE AND GAIN < 1 PSI PER 15 MINUTES. ,PRESSURE HAS STABILIZED TO 1 PSI PER 10 MINUTES. 19 HOURS AND 42 ;MINUTES SINCE SI. WITH BHP AND WHP AT 3199 PSI AND 2030 PSI RESPECTIVELY, WING (OPENED, CHOKE OPENED TO 29 BEANS, AND IGV OPENED. WITH CHOKE AT 50 BEANS, AND 55 MIN AFTER OPENING CHOKE, 300 PSI DRAWDOWN (2900 PSI BHP) REACHED. CORRESPONDING WHP: 500 PSI. WHP BEFORE SHOOTING: 500 PSI. AT 15:00. GUN SHOT AT 15:25. API DATA FOR 2906 POWERJET OMEGA, HMX CHARGES HOLE SIZE: 0.34", PENETRATION DEPTH: 36" RUN 1: INTERVAL: 10328' - 10348'. CCL TO TOP SHOT: 3.4' CCL STOP f DEPTH: 10 RUN 2: INTERVAL: 10325' - 10328'. CCL TO TOP SHOT: 5.4' CCL STOP DEPTH: 1 FINAL PRESSURES: 2050/2050/0 ***JOB COMPLETE'"** FLUIDS PUMPED BBLS 16 MEOH 1 DIESEL 17 Total TREE = Y GRAY;PEN 2 WELLHEAD = "GRAY ACTUATOR = AXELSON KB. ELEV = BF. ELEV = 71' KOP = _10430' Max Angle = 101 @ 11704' Datum MD = 10406 Datum TV D = 8800' SS ~ 14-11A S ES: ***CHROME TBG!`*** ~ 13-5/8" X 4-112" XO, ID = 3.90" ~ 4-112" HES X NIP,ID = 3.813" 13-318" GSG, 72#, L-80, ID = 12.347" ~-~ 2651' Minimum ID = 3.725" @ 10131' 4-1 i2" XN NIPPLE EST TOP OF TIEBACK CMT GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3166 3166 1 KGB-2 DOME BK 16 01/20!10 4 4743 4743 0 KGB-2 DOME BK 16 01/20/10 3 6112 6021 34 KGB-2 DOME BK 16 01/20/10 2 7320 7004 44 KGB-2 DOME BK 16 01/20/10 1 8822 8004 57 KGB-2 SO BK 28 01!20/10 6930 ~ 7° BKR PORTED TIEBACK SEAL ASSY, ID = 6.16" 7" TIEBACK CSG, 26#, L-80 6g3p' 6930 7" X 9-5/8" BKR G2 ZKP LNR TOP PKR, ID = 6.28" TGIUBTGM, ID = 6.276" 6945 9-5/8" X 7" BKR HMC LNR HNGR, ID = 6.29" MILLOUT WINDOW (14-11A} 7109' - 7125' LWHIPSTOCK(08J29/05} ~-~ 7115• 9-518" CSG, 47#, L-80/500-95, ID = 8.681" 7109 EZSV (08/29/05} 7131' 4-1/2" TBG, 12.6#, 13CR80 TCII, .0152 bpf, ID = 3.958" I-I 10143' 7" LNR, 26#, L-80 BTGM, .0383 bpf, ID = 6.276" I-{ 10330 PERFORATION SUMMARY REF LOG: NIA ANGLE AT TOP PERF: 100 @ 10412' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpniSgz DATE SLTD 10412 - 10650 O 09/12/05 SLTD 11146 - 11802 O 09/12(05 ---~4-1/2" HES X NIP, ID = 3.813" 7" X 4-112" BKR S-3 PKR, ID = 3.875" 11' 4-1/2" HES X NIP, ID = 3.813" 10130 7" X 5" BKR ZXP LTP w 1TIEBK SLV , ID - 4.41 " 0131' 4-1/2" HES XN NIP, ID = 3.725" 1t)143` I-f 4-112" WLEG, ID = 3.958" I C~ ELMD TT NOT LOGGED \ 10152 7" X 4-1/2" BKR HMC LNR HNGR, ID = 4.41" ~ 10159' S" X 4-1/2" XO, ~ ~~ ID = 3.96" ~ ~ ~ 4-1/2" SLTD/SOLID LNR, 12.6#, L-80 BTGIBT-M, ID = 3.958" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 08/04/81 ORIGINAL COMPLETION 01/15/09 DAV/SV GLV GO (01109109) 09(16105 JNC SIDETRACK(14-11A} 12!12109 RCT/SV GLVGO(12103(09} 09/23(05 DAViPJC GLV GO 02/04/10 DAV/PJC GLV GO (01120110} 10/13(05 TWGPJC GLV GO 11!05105 SGSiTLH DRLG DRAFT CORRECTIONS 10!17!08 DAV/PJC XN NIP ID CORRECTION PRUDHOE BAY UNff WELL: 14-11 A PERMIT No: F2051260 API No: 50-029-20529-01 SEC 9, T10N, R14E, 1282.11' FEL & 4513.86' FNL BP 6cploration (Alaska} BP Exploration (Alaska) Inc. • --- ~ ~•-•-° Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 4~~~,~~~~> .1~~~ ~ 20 ~Cj Dec 07, 2009 '~' Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 14 Dear Mr. Maunder, • bP ...o ~,. , ... ~ _ - ~...~ . ~~~~: ,:~si~tt ,. a os-{~ ~--//~I Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered. to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-14 n~*e• ~~inamc Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 14-01A 1931850 500292031701 Sealed Conductor NA NA 14-02C 2071150 500292031803 Sealed Conductor NA NA 14-03A 1961290 500292031901 Sealed Conductor NA NA 14-o4A 1961640 500292032001 Sealed Conductor NA NA 14-05A 1920010 500292032701 Sealed Conductor NA NA 14-06A 2040360 500292032801 Sealed Conductor NA NA 14-07 1780660 500292032900 Sealed Conductor NA NA 14-08A 2022100 500292033001 Sealed Conductor NA NA 14-096 1820340 500292053402 Sealed Conductor NA NA 14-10 1801300 500292052800 Sealed Conductor NA NA 14-11A 2051260 500292052901 Sealed Conductor NA NA 14-12 1811090 500292063100 Sealed Conductor NA NA 14-13 1811010 500292062400 Sealed Conductor NA NA t4-14 1811020 500292062500 Sealed Conductor NA NA 14-15 1810840 500292061100 Sealed Conductor NA NA 14-16A 1971670 500292060801 Sealed Conductor NA NA 14-17A 2030010 500292056201 Sealed Conductor NA NA 14-186 2071290 500292055102 Sealed Conductor NA NA 14-19 1810450 500292057800 Sealed Conductor NA NA 14-20 1810700 500292059800 Sealed Conductor NA NA 14-21A 2051070 500292075601 Sealed Conductor NA NA 14-22A 1921230 500292074701 Sealed Conductor NA NA 14-23A 2090200 500292075701 NA 4 NA 25.50 10/20/2009 14-24 1830910 500292097000 NA 0.6 NA 3.40 10/20/2009 14-25 1831020 500292098100 NA 2.1 NA 15.30 11/16/2009 14-26 1811100 500292063200 Sealed Conductor NA NA 14-27 1831700 500292104600 NA 3 NA 17.00 10/25/2009 14-28 1820120 500292070800 Sealed Conductor NA NA 14-29 1811680 500292068000 Sealed Conductor NA NA 14-30 2050940 500292067901 Sealed Conductor NA NA 14-31 1831110 500292098900 Sealed Conductor NA NA 14-32 1831220 500292099900 NA 0.6 NA 3.40 10/19/2009 14-33 1831250 500292100200 Sealed Conductor NA NA 14-34 1831330 500292101000 NA 7.3 NA 47.60 10/20/2009 14-35 1831420 500292101800 Sealed Conductor NA NA 14-36 1831630 500292103900 NA 0.7 NA 3.40 10/20/2009 14-37 1880490 500292181000 NA 1.3 NA 5.10 10/20/2009 14-38 1881030 500292186200 NA 0.8 NA 3.40 10/24/2009 14-40A 2011350 500292187501 Sealed Conductor NA NA 14-41 1920960 500292229000 NA 0.8 NA 6.80 10/18/2009 14-43 1921080 500292229600 NA 1.4 NA 10.20 10/23/2009 14-44A 2021930 500292257301 NA 10 NA 88.40 11/24/2009 OPERAB:E: 14-11A (PTD #2051260) Tubing Integrity Restored Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comJ Sent: Saturday, January 10, 2009 10:03 AM ~~~~ ~2~'!n5 To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Bommarito, Olivia O; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: OPERAB:E: 14-11A (PTD #2051260) Tubing Integrity Restored All, Well 14-11A (PTD #2051260) passed an MIT-IA to 3,000 psi on 01109/09 after dummy gas lift valves were set. The passing test confirms tubing, production casing and production packer integrity. herefore, the well has been reclassified as Operable. The Well can be put on line when the surface piping issues have been resolved and live gas lift valves have been reset. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Friday, January 02, 2009 10:55 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; GPB, Area Mgr Central (GCl/3/F53); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Enget, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Bommarito, Olivia O; Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 14-11A (PTD #2051260) Sustained casing pressure due to TxIA communication AI I, Due to a surface piping issue the Well cannot be flouted at this time to re-set the checks in the gas lift valves. For this reason the plan has been modified to the folfoWing to prove competent mechanical barriers in the Well. 1, DHD: TIFL -Failed 2. Slickline: Dummy Gas Lift Valves 3. Fullbore: MIT-lA to 3000 psi I'm sorry for any confusion that may have been caused. Please contact me with any questions or comments. Thank you, Taylor Wellman filling in for Anna Dube(Andrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 2/25/2009 OPERAB:E: 14-11A (PTD #2051260) Tubing Integrity Restored Page 2 of 2 • From: NSU, ADW Well Integrity Engineer Sent: Friday, January 02, 2009 10:20 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; GPB, Area Mgr Central (GCl/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Bommarito, Olivia 0; Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 14-11A (PTD #2051260) Sustained casing pressure due to TxIA communication AI I, Well 14-11A (PTD #2051260) has been found to have sustained casing pressure on the IA. The well broke MOASP on 12/29/08 with TIO pressures of 2040/2000/0+ psi. A TIFL was conducted on 12/29/08 that failed due to overnight fluid movement and pressure build up. The well has been reclassified as Under Evaluation and has been placed under the 28 day clock. The following corrective action has been put in place. 1. D: TIFL -FAILED 2. Operations: POP to warm well 3. D: Re-TIFL A TIO plot and wellbore schematic are attached. Please contact me with any questions. « File: 14-11 A TIO.doc (Compressed) » « File: 14-11A.pdf » Thank you, Taylor Wellman filling in for Anna Dube/Andrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 the file so that changes to the file will be reflected in your item. 2/25/2009 UNDER EVALUATION: 14-11~TD #2051260} Sustained casing press,due to TxIA com... Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] I S~Z~ t Sent: Friday, January 02, 2009 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Bommarito, Olivia O; Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 14-11A (PTD #2051260) Sustained casing pressure due to TxIA communication All, Due to a surface piping issue the well cannot be flowed at this time to re-set the checks in the gas lift valves. For this reason the plan has been modified to the ollowing to prove competent mechanics! barriers in the well. 1. DHD: TIFL -Failed 2. Slickline: Dummy Gas Lift Valves 3. Fullbore: MIT-IA to 3000 psi I'm sorry for any confusion that may have been caused. Please contact me with any questions or comments. Thank you, Taylor Wellman filling in for Anna Dube/Andrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 ~''ty~~ J~t~ ~ fv ZOO From: NSU, ADW Well Integrity Engineer Sent: Friday, January 02, 2009 10:20 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; GPB, Area Mgr Central (GCl/3/F53); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Bommarito, Olivia O; Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 14-11A (PTD #2051260) Sustained casing pressure due to TxIA communication All, Zo~o~s, ~ ~~1 Well 14-11A (PTD #2051260) has been found to have sustained_ casino pressure on the IA. The well broke MOASP on 12/29/08 with TIO pressures of 2040/2000/0+ psi. A TIFL was conducted on_12/29/08 that failed due to overnight fluid movement and pressure build up. The well has been reclassified as Under Evaluation and has been placed under the 28 day clock. The following corrective action has been put in place. 1. D: TIFL -FAILED 2. Operations: POP to warm well 3. D: Re-TIFL A TIO plot and wellbore schematic are attached. Please contact me with any questions. «File:14-11ATIO.doc(Compressed)» «File:14-11A.pdf» ,/ Thank you, UNDER EVALUATION: 14-11A~'D #2051260) Sustained casing press due to TxIA com... Page 2 of 2 Taylor Wellman filling in for Anna Dube/Andrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 the file so that changes to the file will be reflected in your item. • PBU 14-11A PTD 205-126 1 /2/2009 12 month plot .._ T~ .a ._ 6~ uonn ,1. T t t .~ ___. _ _ .. JfiP! >.D16 H i I I.m~ 1 month plot Tbp • w -. as oon ooa ~ o~ iv+YC~ I;.'C:+'.E 13~8~C I:.~~SB 1~1.':+X I_~'L~ IL^6:76 I?~i.t6 I~.4~Y I_._..'3 t...A 6 1?:eX~Q ic~:3E 1Ji0ni7 TREE = GRAY GEN 2 WELLHEAD= GRAY ACTUATOR = AXELSON KB. ELEV - 71' BF. ELEV = ~ ~~~ KOP = 10430' 01 @ 11704' Max Angle = 1 . Datum MD = 10406 Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID =g~3.725" @ 10131' 7" TIEBACK CSG. 26#, L-80 I 6930' TGIVBTC-M, ID = 6.276" EZSV (08/29/05) ~-~ 7131' 5-112" TBG STUB (08!25!05) ~-1 7450' 9-518" CSG, 47#, L-80/SOO-95, ID = 8.681" ~-{ 9298' 14-11A NOTES: ***CHROME TBG**** 13-518" X 4-112" XO, ID = 3.90" 4-1(2" HES X NIP, ID = 3.813" EST TOP OF TIEBACK CMT GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3166 3166 1 KGB-2 DOME BK 16 10/13/05 4 4743 4743 0 KGB-2 DOME BK 16 10/13/05 3 6112 6021 34 KGB-2 DOME BK 16 10113!05 2 7320 7004 44 KGB-2 SO BK 24 10113/05 1 8822 8004 57 KGB-2 DMY BK 0 09/14/05 I 6945' I 17" BKR PORTED TIEBACK SEAL ASSY, ID = 6.16" 7" X 9-5/8" BKR G2 ZKP LNR TOP PKR, fD = 6.28" 9-518" X 7" BKR HMC LNR HNGR, ID = 6.29" MILLOUT WINDOW (14-11A) 7109' - 7125' 10067' 4-1l2" HES X NIP, ID = 3.813" 10088' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 10111' -~ 4-112" HES X NIP, ID = 3.813" 10130' 7" X 5" BKR ZXP LTP w /TIEBK SLV, ID = 4.41" 10131' 4-112" HES XN NIP, ID = 3.725" 10143' 4-112" WLEG, ID = 3.958" - ELMD TT NOT LOGGED 10152' 7" X 4-1/2" BKR HMC LNR HNGR, ID = 4.41" \~ 10159' 5" X 4-112" XO, ~ ~ ~ ID = 3.96" ~ ~ 10330' \~ ~ ~ ~ ~ 4-1/2" TBG, 12.6#, 13CR80 TCII, .0152 bpf, ID = 3.958" ~ 10143' 7" LNR. 26#. L-80 BTC-M..0383 bpf. ID = 6.276" PERFORATION SUMMARY REF LOG NIA ANGLE AT TOP PERF: 100 @ 10412' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn!Sgz DATE SLTD 10412 - 10650 O 09/12/05 SLTD 11146 - 11802 O 09(12/05 4-1/2" SLTDISOLID LNR, 12.6#, L-80 BTC/IBT-M. ID = 3.958" (-j 11804' DATE REV BY COMMENTS DATE REV BY COMMENTS 08104/81 ORIGINAL COMPLETION 09!16/05 JNG SIDETRACK (14-11A) 09/23/05 DAVIPJC GLV CIO 10/13/05 TWCIPJC GLV CIO 11;05105 SGSrTLH DP.LG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: 14-11A PERMIT No: 2051260 AP{ No: 50-029-20529-01 SEC 9, T10N, R14E, 1282.11' FEL & 4513.86' FNL BP Exploration (Alaska) WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : 14-11 A+PB 1 r February 11, 2008 AK-MW-390719 14-11It.+PB1: Digitt Log Images: 50-029-22459-01,70 1 CD Rom PLEAS ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANAVIITTAL LETTER TO THE ATTENTION OF: Sperrl Drilling Services Attn: iob Kalish 6900 arctic Blvd. Anchorage, Alaska 99518 ~~ ~- _ .. Date: 3 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ''MAR ~ 2008 • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 14-11 A February 1, 2008 _~..._ __.~.~.AK=MW-390719 1 LDWG formatted CD rom with verification listing. API#: 50-029-20529-01 ~~ FEB ~ ~ ~~~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURIVIN`G A`COPY OF TIIE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage;,, Alasiza 99518 Anchorage, Alaska 99508 ''~ri :: ~a~~~' Date: _ Signed: dos-r2~ ~1S9oS"~ • • WELL LOG TRANSMITTAL To: State of Alaska February 1, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 14-11APB1 AK-MW-390719 1 LDWG formatted CD rom with verification listing. API#: 50-029-20529-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 ~~ _ r~ Date `" ~_ ~, "~ ~ _ ~ Signed: , . _ . ,........ ~w ~ ~ FED ~ ~. X04 doS-lad X15 9~~ DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2051260 Well Name/No. PRUDHOE BAY UNIT 14-11A Operator BP EXPLORATION (ALASKA) INC MD 11804 TVD 9032 Completion Date 9/15/2005 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Log s Run: MWD DIR/GR/RWD, MWD DIR/GR/RES/AIM Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name D Asc Directional Survey D D Asc Directional Survey D D Asc Directionai Survey VED D Asc Directional Survey ~D C Las 15429 See Notes C Las 15430 See Notes Well Cores/Samples Information: Interval Name Start Stop Samples No (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH I Scale Media No Start Stop CH Received Comments 11518 11804 Open 9/26/2005 IIFR 11518 11804 Open 9!26/2005 MWD 7100 11616 Open 9/26/2005 PB 1 IIFR 7100 11616 Open 9/26/2005 PB 1 MWD 7050 11803 Open 9/17/2007 Field Data, LAS GR, ROP w/EMF Graphics 7050 11617 Open 9/17/2007 PB1 Field Data, LAS GR, ROP w/EMF Graphics Sample Set Sent Received Number Comme nts ADDITIONAL INFORMATION Well Cored? Y / N~ Chips Received? 1~'TN- Analysis ~( (~I- Received? Daily History Received? 'N Formation Tops Y~/ N Comments: Compliance Reviewed By: API No. 50-029-20529-01-00 UIC N Directional Survey Yes/~ Date: ~ ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~ ~l~L~~~? DATE: October 27, 2007 P. I. Supervisor (~ FROM: Bob Noble SUBJECT: Inspect SVS Control Panel Petroleum Inspector PBU 14-11A BPXA PTD 205-126 Oct 27, 2007: As requested I went to look at PBU 14-11A well house to see if BPX had changed the SVS panel. Inspection was a follow up to finding the safety valve system defeated during September 24, 2007 inspection and BPX letter dated October 15 summarizing the corrective actions taken/to be taken. Summary: The panel had NOT been changed. Talking with the drill- site operator and the lead Gordon Moench (stepped up for Konrad Schruf), they were unaware that the panel was going to be changed out. Gordon did say that Dowland-Bach was in the process of building a new skimpy panel for them. They expected the prototype to arrive in a week. I ask Gordon if he would give us a call when it arrived so we could look at it. Attachments: 2 photos 2007-1027_S V S_PBU_ 14- i l A_control~anel_bn.doc • PBU 1411 A SVS Control Panel October 27~ 2007 Photos by AOGCG Inspector Bob Noble Front side of PBU 14-11A SVS control panel (note needle on gauge is missing) Back side on PBU 14-11A SVS control panel (red handled valve was found defeated 9/24/2007) 2007-1027_S V S_P BU_ 14-1 l A_control~anel_bn.doc Date 09-14-2007 Transmittal Number:92903 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) have anv questions, please contact llou~las llortch at the rtx: at ~b4-4y is u~C elivery Contents CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: J6-06B ~ ~5 vat )6-06BP61 ~ ao~-c~~ ~ ~%~~a~ 13-31 A - v~ C ao~ I(oD ~ ~5~2'~ I4-11A `~ao5-~a6 ~S~a 14-11AP61 14-21A uz~ao5 -rv~ ~ ~5'~/3! 15-39A aolo-o~sr ~ ~brN3a I6-06Baa.-OM1t `' is~33 16-14Bao(o•oa3 "t5~13~/ :,-o3B avs ~~ $ c5~13s -10A aos-c3~ •+5~a~ 1-17C AO`s o~sa '~ e'Sk3~' ~GI-07A u=.eacX.-~aL '~ tS~f3~l r; ` a } !r Please ~'i"gn and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 ~; ~~ ~ ~~: .~.,~ ,~~ r?~i~~ic;°; Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 1.96612 Anchorage, AK 99519-6612 STATE OF ALASKA i~~ ALASKA OIL AND GAS CONSERVATION COMM~ION (~~~' Z(~~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~ ~ Rlaska Gil ~ Gas Cofts~ C®rr~issort Anchr~raoe 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Com letions One p Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 9/15/2005 12. Permit to Drill Number 205-126 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 8/31/2005 13. API Number 50-029-20529-01-00 4a. Location of Well (Governmental Section): Surface: 1776' FNL 1759' FEL SEC T1 R14 7. Date T.D. Reached 9/12/2005 14. Well Name and Number: PBU 14-11A , , . 09, 0N, E, UM Top of Productive Horizon: 4942' FNL, 2296' FEL, SEC. 09, T10N, R14E, UM g, KB Elevation (ft): 71.4' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 5042' FNL, 2594' FEL, SEC. 09, T10N, R14E, UM 9. Plug Back Depth (MD+ND) 11804 + 9032 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 674727 y- 5938553 Zone- ASP4 10. Total Depth (MD+TVD) 11804 + 9032 Ft 16. Property Designation: ADL 028312 _ TPI: x- 674271 y- 5935376 Zone- ASP4 Total Depth: x- 673976 Y- 5935269 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD DIR / GR / PWD, MWD DIR / GR / RES /AIM 22. ASING, LINER AND CEMENTING RECORD CASING ETTING EPTH MD ETTING EPTH ND HOLE AMOUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM S{ZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 110' Surface 110' 32" 300 sx Permafrost 13-3/8" 72# L-80 Surface 2651' Surface 2651' 17-1/2" 1640 sx Fondu, 400 sx AS II 9-5/8" 47# L-80 / S00-9 Surface 7109' Surface 6843' 12-1 /4" 500 sx Class 'G' 7" 26# L-80 24' 10330' 24' 8828' 8-1 /2" 168 sx Class 'G', 480 sx Class 'G' 4-1/2" 12.6# L-80 10130' 11804' 8714' 9032' 6-1/8" Uncemented Slotted Liner 23. Perforations open to Produc tion (MD + TV D of Top and ' " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Section 4-1/2", 12.6#, 13Cr80 10143' 10088' MD TVD MD TVD 10412' - 10650' 8874' - 8990' 11146' - 11802' 9006' - 8909' 25 ACfD, FRACTURE, CEMENT SQUEEZE, erc. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protect with 77 Bbls of Diesel 26. PRODUCTION TEST Date First Production: October 3, 2005 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 10/4/2005 Hours Tested 6.2 PRODUCTION FOR TEST PERIOD • OIL-BBL 1,003 GAS-MCF 773 WATER-BBL 311 CHOKE SIZE 83.59 GAS-OIL RATIO 770 Flow Tubing Press. 14 Casing Pressure 1,400 CALCULATED 24-HOUR RATE OIL-BBL 3,884 GAS-MCF 2,992 WATER-BBL 1,204 OIL GRAVITY-API (CORK) ~~ 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none"• / , l - _ der a~a1~+v~ayJ 7~es ~..-or C772...1'4bSaes. None ~ i ~` ~ 'p'=?il"inn , -_ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE P' I -L-~ ~ ~"'~( ~ ~/~'J r ~ 28. GEOLOGIC MARKERS 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10314' 8819' None Shublik A 10351' 8840' Shublik B 10400' $868' Shublik C 10419' 8879' Sadlerochit 10450' 8896' 45P 10549' 8943' 44P 10650' 8990' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Title Technical Assistant Date ~~~ ~ j'~S PBU 14-11 A 205-126 Prepared ey Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Jeff Cutler, 564-4134 Permit No. / A royal No. INSTRUCTIONS GeNeaAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 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). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 9/19/2005 8:02:20 AM BP EXPLORATION Page 1 of 8 Operations Summary Report Legal Well Name: 1 4-11 Common W ell Name: 1 4-11 Spud Date: 7/4/1981 Event Nam e: REENTE R+COM PLET E Start : 8/25/2005 End: Contractor Name: Rig Release: Rig Name: Rig Number: Date , From - To Ho ars Task Code NPT Phase ' Description of Operations 8!26/2005 17:00 - 19:30 ~ 2.50 MOB P PRE Bridle up derrick, lower chute, pull pins, PJSM and lay down 19:30 - 20:30 1.00 MOB P PRE derrick. ~ Open cellar doors -lift rig -pull mats, move pits, shop, and camp. 20:30 - 21:00 0.50 MOB P PRE Move sub off well and down pad to DS 14-11A. 21:00 - 23:00 2.00 MOB N WAIT PRE Wait on site preparation -final grading. 23:00 - 00:00 1.00 MOB P PRE Set matting boards for substructure. 8/27/2005 00:00 - 09:00 9.00 MOB P PRE Set mating board, Spot/ level substructure over well. Set pits, shop, and camp. Hook up interconnect. Bermand spot cutting pit. Raise derrick. Hang bridle. Raise pipe shed shoot. R.U. floor and pits. Hook up communication lines. Pre-Spud meeting w/ all hands, Co. Rep , TP. Accept rig @ 0600 hrs 8-27-2005. 09:00 - 11:00 2.00 WHSUR P DECOMP RU lubricator. and pull BPV. Installed second annular valve. RU circ lines to tree. 11:00 - 14:30 3.50 KILL P DECOMP Reverse out freeze protect diesel from tubing. Pump 45 bbl soap pill & displace well to clean sea water and circ out annulus freeze protect diesel thru choke 3 BPM 200 psi..lncreased to 8 BPM 780 psi. 14:30 - 15:30 1.00 WHSUR P DECOMP Install BPV with lubricator. Test from below to 1,000 psi. 15:30 - 17:30 2.00 WHSUR P DECOMP N.D. tree and adaptor -remove from cellar. Unable to screw sub into tubing hanger. 17:30- 19:30 2.00 BOPSU P DECOMP N.U. BOP's. 19:30 - 00:00 4.50 BOPSU P DECOMP R. U. test equp. Test BOP's as per BP policy to 250 psi low and 3,500 psi high. Test witnessed by Jeff Jones w/ AOGCC, Mike Whiteley w/ Fairweather, and Ronnie Dalton -tool pusher. 8/28/2005 00:00 - 03:00 3.00 BOPSU P DECOMP Test BOP's as per BP policy to 250 psi low and 3,500 psi high. Test witnessed by jell Jones with AOGCC, Whiteley - fairweather, Dalton - nabors. R.D. test equip. Blow down. 03:00 - 04:00 1.00 BOPSU P DECOMP Pull dart. Pull BPV with lubricator. 04:00 - 13:00 9.00 PULL P DECOMP Make up spear w/ double 4.805" grapples on jt 4" DP.. BOLDS. Spear tubing. Pull to 100K over string wt. No movement. Heat tbg head with steam. Pull and work pipe to 150K over string wt. No movement. Continue heating tubing head with 3 steam hoses. Work pipe pulling 150 K overstring wt every 30 min. Came free @ 155k over. String wt. 143K. Pull hanger to rig floor. 13:00 - 14:00 1.00 PULL P DECOMP Release spear - L.D. hanger. R.U. head pin. 14:00 - 15:00 1.00 PULL P DECOMP CBU @ 6 BPM 300 psi. R.U. 5.5" tbg handling tools and spooling unit. 15:00 - 18:00 3.00 PULL P DECOMP Lay down 55jts 5.5" 17# L80 LT&C tubing and SSSV spooling up control line. R.D. spooling unit. Recovered 26 clamps & 6 SS bands. 18:00 - 23:00 5.00 PULL P DECOMP L.D. totak 183 jts 5.5" tbg and cut off piece. RD handling tools. Clean and clear rig floor. 23:00 - 00:00 1.00 BOPSU P DECOMP RU test equip. Test Rams, annular, floor valves to 250 psi low and 3,500 psi high. Test witnessed by Mike Whiteley - fairweather. 8/29/2005 00:00 - 01:00 1.00 BOPSU P DECOMP Test pipe rams /annular to 250 psi low and 3,500 psi high. Set wear ring. RD test equip. 01:00 -04:00 3.00 DHB N DFAL DECOMP PJSM. R.U. SWS unit. RIH w/ 8.5" od gage /junk basket / GR / CCL to 6,000'. Tool failed. POOH w/ wireline and tools. 04:00 - 05:30 1.50 DHB N DFAL DECOMP Trouble shoot tools. Wire line shorted out. Cut off 400' wireline and rehead. MU wireline tools. Printed: 9/19/2005 8:02:29 AM BP EXPLORATION Page 2 of 8 Operations Summary Report Legal Well Name: 14-11 Common Well Name: 14-11 Event Name: REENTER+COMPLETE Contractor Name: Rig Name: Date !From - To Hours ! Task ICI Code' NPT -- 8/29/2005 I) 05:30 - 09:30 ~ 4.00 DHB I P 09:30 - 12:30 I 3.001 DHB I P 12:30 - 13:30 1.00 DHB P 13:30 - 17:30 4.00 STWHIP P 17:30 - 23:00 5.50 STWHIP P 23:00 - 00:00 1.00 STWHIP P 8/30/2005 ~ 00:00 - 01:00 ~ 1.00 ~ STWHIPI N ~ DFAL 01:00-03:00 ~ 2.OOSTWHIPP 03:00 - 04:00 I 1.001 STWHIPI N I DFAL 04:00 - 05:00 1.00 STWHIP P 05:00 - 05:30 0.50 STWHIP P 05:30 - 07:00 1.50 STWHIP N DFAL 07:00 - 09:00 2.00 STWHIP N DFAL 09:00 - 12:00 I 3.001 STWHIPI N I DFAL 12:00 - 14:30 2.50 STWHIP N DFAL 14:30 - 15:30 1.00 STWHIP N DFAL 15:30 - 16:00 0.50 STWHIP N DFAL 16:00 - 18:30 2.50 STWHIP N DFAL 18:30 - 00:00 5.50 STWHIP P 8/31!2005 100:00 - 00:30 I 0.501 STWHIPI P 00:30 - 02:00 1.50 STWHIP P 02:00 - 02:30 0.50 STWHIP P 02:30-05:00 ~ 2.50~STWHIP~P 05:00-07:00 2.00 STWHIPP 07:00 - 08:30 I 1.50 I STWHIPI P Spud Date: 7/4/1981 Start: 8/25/2005 End: Rig Release: Rig Number: Phase Description of Operations DECOMP Run gage ring /junk basket, GR /CCL. Tag Tbg stump C 7,440' ELM .Ran Gr/ CCL log to surface. DECOMP RIH w/ 9 5/8" EZSV plug on WL. Set plug ~ 7,130' ELM. POOH. RD SWS. DECOMP Test 9 5/8" csg to 3,500 psi for 30 min. Held. WEXIT M.U. Whipstock /Milling BHA. Orient -upload -surface test MWD. 450 GPM C~ 480 psi. Finish picking up BHA. Change handling tools. WEXIT RIH picking up 4" DP to 7,070'. Orient 2 deg LH. Install blower hose. WEXIT Tagged EZSV ~ 7,131'. Shear bottom trip anchor C~3 22K. No over pull -anchor not set. Set 25K on anchor again - no over pull -anchor not set. Running bolt sheared @ 45k. Unable to pull window mill free w/ 40K over or rotate. Work pipe to 40K over string wt. WEXIT Work pipe to 210K. Pulled mill free @ 230K (50K over string wt.) WEXIT Pump 45 bbl sweep high vis sweep & displace well with 9.0 ppg LSND mud Q 500 bpm @ 1200 psi. Slug DP. Observe well. WEXIT POOH for hook to fish whipstock or verify it is set and oriented - POOH w/ window mills to 5,000'. WEXIT Cut and slip drilling line. WEXIT Service top drive & crown. WEXIT POH with window mills. WEXIT Handle BHA, stand back HWDP & drill collars, U D window mills. M/U "J" hook & scribe. P/U oil jar &RIH to 1020'. Surface test MWD. WEXIT RIH from 1020' to 7090'. Fill pipe ~ 4000'. Orient to high side. Latch onto whipstock "J" slot @ 7115'. overpull 20K to 190K. Verify 2 times anchor is set. Pump dry job. WEXIT POH from 7090' to 1020'. WEXIT Handle BHA. UD jars, MWD & whipstock "J" hook. WEXIT M/U milling assy BHA to 985'. WEXIT RIH from 985' to 7109'. Install top drive blower hose. WEXIT Mill window and 20' new formation from 7109' to 7130'. UWT = 170K, DWT = 150K, RWT = 160K. WOB = 8K, torque = 4/5K. Pump @ 500 gpm ~ 1550 psi. WEXIT Mill window to 7125'. Drill formation to 7137'. TOW ~ 7109', BOW C~3 7125'. RPM = 95, torque = 8/10K. WOB = 10K. Pump 500 gpm @ 1280 psi. UWT = 170K, DWT = 155K, RWT = 160K. WEXIT Pump Super Sweep, CBU. WEXIT Perform F.I.T. to 11.9 EMW. Max pressure reached was 1120 psi, pumped 2.8 bbl. TVD @ 6866'. Surface pressure stabilized C~ 1000 psi, original mud wt. = 9.1 WEXIT Monitor well, pump dry job. Remove top drive blower hose. Install air slips. POH with window mills. WEXIT Stand back HWDP. UD drill collars, bumper sub and mills. Srting mill in gauge. Clear rig floor. WEXIT Pull wear bushing. M/U stack flushing tool (Johnny Wacker) Function rams & flush BOP stack. UD tool, install wear bushing. Printed: 9/19!2005 8:02:29 AM • BP EXPLORATION Operations Summary Report Page 3 of 8 Legal Well Name: 14-11 Common Well Name: 14-11 Spud Date: 7/4/1981 Event Name: REENTER+COMPLETE Start: 8/25/2005 End: Contractor Name: Rig Release: Rig Name: Rig Number: i Date ', From - To Hours Task Code', NPT Phase Description of Operations 8/31/2005 08:30 - 10:30 ~ 2.001 STWHIP P ~ WEXIT M/U BHA, P/U mud motor & make up bit. P/U MWD and 10:30-15:30 I 5.OOISTWHIPIP I (WEXIT 15:30-16:00 0.50 STWHIP P WEXIT 16:00-16:30 0.50 STWHIP P WEXIT 16:30 - 00:00. I 7.501 DRILL I P I I INT1 9/1/2005 100:00 - 06:00 6.001 DRILL P INTi 9/2/2005 100:00 - 10:00 ( 10.001 DRILL I P I I INTi 10:00 - 10:30 0.50 DRILL P INTi 10:30 - 11:30 1.00 DRILL P INT1 11:30 - 12:30 1.00 DRILL P INT1 12:30 - 13:00 0.50 DRILL P INTi 13:00 - 14:30 1.50 DRILL P INT1 14:30 - 00:00 I 9.501 DRILL I P I I INT1 9/3/2005 00:00 - 18:30 18.501 DRILL P INTi 18:30 - 20:30 I 2.001 DRILL I P I I INT1 20:30 - 22:30 2.00 DRILL P INT1 22:30 - 00:00 1.50 DRILL P INTi 9/4/2005 00:00 - 01:00 1.00 DRILL P INT1 01:00 - 03:00 2.00 DRILL P INT1 03:00 - 04:30 I 1.501 DRILL I P I I INTi 04:30 - 07:30 I 3.001 DRILL I P I I INTi upload. P/U flex drill collars & jars. Surface test MW D tools @ 803'. RIH P/U 4" drill pipe from 803' to 6587'. Fill pipe C~ 3000' intervals. Service top drive, install blower hose. RIH from 6587' to 7054', orient, pumps off, slide through window to 7137'. Window clean. Drill 8 1/2" hole from 7137' to 7490'. AST = 2.63 hrs, ART = 2.27 hrs. UWT = 160K, DWT = 145K, RWT = 155K. WOB = 10K. Pump @ 505 gpm ~ 1750 psi. Torque = 4K off bottom, 6K on. Drill from 7490' to 8352'. AST = 6.84 hrs. ART = 9.66 hrs. UWT = 170K, DWT = 140K, RWT = 160K. WOB = 7/8K. Pump C~ 490 gpm ~ 3000 psi. Torque off bottom = 3/4k, on = 5/7K @ 75 rpm. Drill from 8353' to 8642'. AST = 2.98 hrs. ART = 4.12 hrs. Diffacult to slide and hold tool face. Torque increasing while rotating, mix Lube Tex and nut plug. UWT = 170K, DWT = 150K, RWT = 160K. WOB 10K. RPM 75. Torque on bottom = 7K, off = 4K. Pump @ 500 gpm ~ 3300 psi. Pump hi-vis sweep, circ until clean. Short trip, POH from 8642' to 7054'. (TOW @ 7109') Slip & cut 87' drill line. Service top drive & crown. RIH, took 15K down weight @ 7174'. Stand back 1 stand drill pipe. Orient to high side, RIH to 8548'. Wash down from 8548' to 8642'. Drill from 8642' to 8906'. AST = 3.5 hrs, ART = 2.22 hrs. UWT = 175K, DWT = 147K, RWT = 162K. WOB = 8/15K. RPM = 85. Torque on bottom = 5/8K, off = 4. Pump @ 500 gpm @ 3400 psi. Drill from 8906' to 9475'. ROP lower than expected and erratic. Average ROP dropping throughout bit run. Crossed fault at +-9020' without losses. AST = .59 hrs, ART = 15.11 hrs. HWT = 175K, RWT = 165K, DWT = 150K. WOB = 10K. RPM = 80. Torque = 4/5K off bottom, 4/6K on. Pump @ 500 gpm @ 3700 psi. Bit performance still slower than expected with ROP only 13 ft/hr from 17:00 to 18:00 hrs. Discuss with ODE and HTC rep and agree that ROP is unacceptable. Consensus is to POH for bit change. Pump dry job, monitor well. POH from 9475' to 7241'. Pulling speed 60 fpm in open hole, hole in good shape. HWT = 190K, max pull = 210K from 8600' to 8500'. Perform MAD pass from 7238' to 6930'. pulling speed = 180 fph. Remove top drive blower hose and install air slips. POH from 6930' to 3225'. Pulling speeed = 90 fpm. POH for bit from 3225' to 803'. Rack back HWDP & drill collars. L/D bit, down-load MWD. Change pulsar in MWD. Bit is essentially undamaged so, poor ROP is not because of bit damage. Up-load MWD, break connection and check float. P/U new bit - Tri-cone. RIH to 803' and pulse check MWD. RIH with reduced speed from 3000' to 7054'. Orient to high Printed: 9/19/2005 8:02:29 AM i BP EXPLORATION Operations Summary Report Page 4 of 8 Legal Well Name: 14-11 Common Well Name: 14-11 Event Name: REENTER+COMPLETE Start: 8/25/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date I From - To Hours ' Task 9/4/2005 ~ 04:30 - 07:30 3.00 DRILL 07:30 - 08:00 0.50 DRILL 08:00 - 09:00 1.00 DRILL 09:00 - 00:00 ~ 15.00 DRILL 9/5/2005 100:00- 18:30 I 18.501 DRILL 18:30 - 22:30 I 4.001 DRILL 22:30 - 00:00 I 1.50) DRILL 9/6/2005 100:00 - 03:30 I 3.501 DRILL 03:30 - 06:00 I 2.501 DRILL 06:00 - 07:00 1.00 CASE 07:00 - 11:30 i 4.50 CASE 11:30 - 12:30 1.00 CASE 12:30 - 14:00 1.50 CASE 14:00 - 15:00 1.00 CASE 15:00 - 16:30 1.50 CASE 16:30 - 19:00 I 2.501 CASE 19:00 - 22:00 I 3.001 CASE 22:00 - 23:00 1.00 ~ CASE 23:00 - 20:00 21.001 CASE Spud Date: 7/4/1981 End: Code NPT Phase Description of Operations ~ P INT1 side. P INT1 Service top drive. P INTi RIH through window @ 7109', no obstructions. RIH @ 60 fpm running speed from 7054' to 8475', hole in good shape. P INTi Drill form 9475' to 9917'. AST = 2.96 hrs, ART = 9.42 hrs. UWT = 180K, RWT = 165K, SWT = 150K. WOB = 20/30K. Torque = 4/5K off bottom, 4/6 on @ 85 rpm. Pump C~3 485 gpm @ 3300 psi. ROP is generally slow, ranging from 20 to 50 fph. P INT1 Drill from 9917' to 10322' hole in good shape. AST = .92 hrs, ART = 4.77 hrs. UWT = 190K, RWT = 170K, SWT = 150K. Torque = 5K on bottom, 5/6K off C~3 90 rpm. WOB = 30K. Pump C~3 490 gpm @3450 psi. P INTi Circ up cuttings sample, drill to T.D ~ 10330'. Pump sweep followed by dry job. Monitor well. P INTi POH from 10330' to 8164' C~3 60 fpm. UWT = 215K. Had 50K overpull @ 9433' & 9406'. Wipe through tight spots, wiped clean. Hole in good shape. Lots of small overpulls, once wiped they were clean. P INT1 POH from 8164' to 7054' @ 60 fpm, 40K overpull ~ 8030' & 7404'. Wipe tight spots clean. POH from 7054' to 3000' @ 90 fpm. Continue POH to 803'. P INT1 UD BHA. UD HWDP, jars & drill collars. Break bit. Down load MW D. Clear & clean rig floor. Graded the bit :Teeth 2 Chipped teeth on cone # 3 : Bearings effective : In gauge. P LNR1 R/U to run 7" 26# L-80 BTC-M liner. PJSM. P LNR1 RIH with 7" liner, running tool and 1 stand of 4" drill pipe to 3522'. P LNR1 Circ 1 liner volume C~3 6 bpm @ 300 psi. P LNR1 RIH with liner on 4" drill pipe from 3522' to 7065' @ 90 fpm. Fill pipe C~3 10 stand intervals. P LNR1 Circ 1.5 times liner & drill pipe volume @ 7 bpm @ 725 psi. P LNR1 RIH from 7065', running speed = 60 fpm. Fill pipe @ 10 stand intervals. DWT = 135K. Tight spot @ 10171', unable to work past. P LNR1 Break circ and stage pump up slowly to 5 bpm C~ 900 psi. Work through tight spot. RIH to 10304'. P/U cement head and joint of drill pipe, tag bottom @ 10330'. Break circ and stage pump up slowly to 6 bpm C~3 840 psi. P LNR1 PJSM with Schlumberger cement crew, drill crew and WSL. Batch mix cement, pump 3 bbl water and test lines to 4000 psi. Pump 25 bbl 12.2 ppg MudPush spacer followed by 35 bbl of 15.8 ppg Class "G" GasBlok cement. Wash up to tee, kick out drill pipe wiper plug and displace with 11.2 ppg mud. Observe liner wiper plug latch up. Bump plug with 3500 psi, bleed off pressure, floats held. CIP @ 21:30. Switch to rig pumps. Rotate off of liner hanger. Pressure up to 1000 psi and & unsting. Circ 30 bbl above liner top C~3 500 gpm. Slow pump, set down 70K string weight abd set packer. Pick up and rotate down to confirm. P LNR1 CBU C~3 500 gpm @ 3000 psi. Pump dry job. UD cement head and joint of drill pipe. Clear & clean rig floor. TOL C~? 6930', 7" shoe C~3 10330'. P LNR1 Slip and cut 80' drill line. Printed: 9/19/2005 8:02:29 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 14-11 Common Well Name: 14-11 Event Name: REENTER+COMPLETE Start: 8/25/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours ', Task Code 'I NPT Phase 9/7/2005 00:00 - 02:30 2.50 CASE P LNR1 02:30 - 03:00 0.50 CASE P LNR1 03:00 - 03:30 0.50 CASE P LNR1 03:30 - 04:30 1.00 CASE P TIEB1 04:30 - 05:00 0.50 CASE P TIEB1 05:00 - 16:00 11.00 CASE P TIEB1 16:00 - 19:30 I 3.501 CASE I P I I TIEB1 19:30 - 22:00 I 2.501 CASE I P I ITIEBI 22:00 - 00:00 ~ 2.00 CASE ~ P ~ ~TIEB1 9/8/2005 00:00 - 00:30 0.50 CASE P TIEB1 00:30 - 01:30 1.00 CASE P TIEB1 01:30 - 03:00 1.50 CASE P TIEB1 03:00 - 08:30 I 5.501 WHSUR I P I I TIEB1 08:30 - 10:00 1.50 WHSUR P TIEBi 10:00 - 14:30 4.50 WHSUR P TIEB1 14:30 - 19:30 I 5.001 BOPSUpP I ITIEBI 19:30 - 22:30 I 3.001 DRILL I P I I PROD1 22:30 - 00:00 1.50 DRILL P PROD1 9/9/2005 00:00 - 02:00 2.00 DRILL P PROD1 02:00 - 03:30 1.50 DRILL P PROD1 Page 5 of 8 Spud Date: 7/4/1981 End: Description of Operations POH from 6930', L/D 7" liner running tool. Pull wear ring. Clear and clean rig floor R/U casing tools, prepare to run 7" tie-back string. Test 9 5/8" casing x 7" liner to 3500 psi for 30 min. OK. PJSM with drill crew, Baker rep, Nabors casing &WSL. R/U and run 7" 26# L-80 BTC-M x TCII tie-back to 6888'. Torque turn TCII pipe. Clear rig floor. Change bails, M/U circ swage. Break circ and stab seal assy into top of 7" tie-back at 6930', slack off 5' to no-go. Pressure up to confirm seals assy is in tie-back. Confirm space out, R/D circ swage. P/U XO joint and cement head. Stab seal assy into tie back, pressure up to 500 psi, P/U on casing until pressure drops and 4 cement ports are exposed. Up weight for 7" string = 185K, down = 165K. PJSM with Schlumberger cement crew, drill crew, Baker rep. & WSL. R/U cementers, tie onto annulus for diesel returns. Pump 5 bbl High vis spacer. Test lines to 3500 psi. Pump 40 bbl high vis spacer followed by 90 bbl diesel freeze protect. Drop bottom plug and pump 99.1 bbl of 15.8 ppg class "G" cement. Drop top plug, open annulus valve, close annular preventor and displace with 11.2 ppg mud taking returns to the slop tank. Did not bump plug. CIP @ 21;45. Approx 10 bbl of diesel back to surface. Blow down lines, R/D cement head & casing tools. Clear rig floor. R/U hoses and use guzzler to vacuum out 7" landing joint, prepare to cut pipe. Clean drip pan under rig floor & blow down BOP stack. N/D BOPE, remove secondary annulus valve. Pull 170K on 7" tie-back string (UWT on string = 185K) and set emergency slips. R/U Wachs casing cuttter and cut pipe. Install pack-off bushing in casing spool. Pack-off lacking 2" from seating in spool. Pull pack-off out of spool. Clean casing spool and pack-off. Redress with new seals. Set pack-off, RILDS. Set new tubing spool and N/U same. Energize pack-off with plastic. Install secondary annulus valve. Test pack-off to 3820 psi. N/U BOPE. Install mouse hole. R!U to test BOPS. Test to 250 psi low test and 3500 psi high. Test stack, choke manifold, top drive valves and perform accumulator efficency test. Good test, no failures. Test witnessed by WSL John Rall and James Willingham, Tool pushers Charlie Henley and Jim Henson. Witness of test waived by AOGCC Rep. Lou Grimalde. R/D test equip, blow down lines and install wear ring. PJSM. P/U 6 1/8" bit and directional BHA to 364'. Up load MW D & surface test with 245 gpm C~3 1200 psi. RIH from 364' to 3160'. RIH from 3160', tag cement @ 6864'. Drill cement from 6864' to 6907. Test 7" casing to 3500 psi for 10 min OK. Drill float equipment ~ 6909'. Once through landing collar we pushed debris or cement plug rubber down to Printed: 9/19/2005 8:02:29 AM • • BP EXPLORATION Page 6 of 8 Operations Summary Report Legal Well Name: 14-11 Common Well Name: 14-11 Spud Date: 7/4/1981 Event Name: REENTER+COMPLETE Start: 8/25/2005 End: Contractor Name: Rig Release: Rig Name: Rig Number: ~ ~ s/s/ Date li From - To Hours ~ Task 'Code NPT Phase 2005 02:00 - 03:30 1.50 DRILL P PROD1 03:30 - 05:00 1.50 DRILL P PROD1 05:00 - 06:00 1.00 DRILL P PROD1 06:00 - 08:30 2.50 DRILL P PROD1 08:30 - 12:00 3.50 DRILL P PROD1 12:00 - 13:00 1.00 DRILL P PROD1 13:00 - 13:30 0.50 DRILL P PROD1 13:30 - 15:30 2.00 DRILL P PRODi 15:30 - 16:30 1.00 DRILL P PROD1 16:30 - 19:00 2.50 DRILL P PRODi 19:00 - 20:00 1.00 DRILL P PROD1 20:00 - 00:00 4.00 DRILL P PRODi 9/10/2005 00:00 - 00:00 ~ 24.00 ~ DRILL P ~ ~ PROD1 9/11/2005 100:00 - 04:00 I 4.001 DRILL I P I I PROD1 04:00 - 06:00 I 2.001 DRILL I N I DFAL I PROD1 06:00 - 10:30 4.50 DRILL N DFAL PROD1 10:30 - 12:30 2.00 DRILL N DFAL PROD1 12:30 - 13:30 I 1.001 DRILL I N I DFAL I PROD1 13:30 - 16:30 3.00 DRILL N DFAL PRODi 16:30 - 17:30 1.00 DRILL P PROD1 17:30 - 18:30 1.00 DRILL N RREP PROD1 18:30 - 19:00 0.50 DRILL P PROD1 19:00 - 20:00 1.00 DRILL N DFAL PROD1 20:00 - 00:00 4.00 DRILL N DFAL PROD1 9/12/2005 100:00 - 03:00 I 3.001 DRILL I N I DFAL I PROD1 Description of Operations 7200'. RIH to 10240', tag float equipment. Test casing to 3500 psi for 30 min, OK. Drill cement and float equipment from 10240' to 10326'. UWT = 185K, DWT = 155K, RWT = 165K. WOB = 6/10K. Pump ~ 250 gpm @ 1300 psi. Torque = 6/7K. Rotary rpm = 20. Pump 75 bbl fresh water, 45 bbl of high vis sweep and displace well to 8.4 ppg FloPro mud C~3 250 gpm. Shut down pumps, clean flow line, shaker beds and troughs. Change shaker screens. Take slow pump rates. Drill shoe @ 10330', and 20' of new formation to 10352'. Pull to shoe, R/U and perform F.I.T. to 10 ppg EMW @ 750 psi. Drill from 10352' to 10389', partial lost returns C~ 72 bph. Mix & pump 50 bbl LCM pill. Pump @ 250 gpm @ 1380 psi. Drill from 10389' to 10441', spot LCM pill and pull to 7" casing shoe @ 10330'. Monitor well for losses. Static losses = 14 bph. RIH to bottom @ 10441' and drill to 10582'. HWT = 175K, DWT = 150K, RWT = 170K. Torque = 5/6K off bottom, 6/7K on @ 55 rpm. Pump @ 270 gpm @ 1850 psi. AST = 2.71 hrs, ART = 4.1 hrs. Total fluid lost to well = 748 bbl. Drill ahead from 10582' to 11505', treat active mud system for partial lost returns. Loosing 7 to 15 bph. Total mud lost to well = 1261 bbl. UWT = 190K, DWT = 140K, RWT = 165K. Torque off bottom = 7/8K, on = 8/10K @ 550 rpm. Pump C~? 275 gpm C~3 2050 psi. Drill from 11505' to 11616'. Loosing 7 to 15 bph to well. Bit diffacult to slide and drilling @ 13 fph while rotating. Mixing bead/tube pills. Torque flagging from 8500 ft Ibs to 11000. Still had good differential pressure. AST = .51, ART = 1.71 Mud lost to well in the last 24 hrs = 177. Total lost to well = 1438. CBU, pump dry job & POH for bit. HWT = 190K. Hole in good shape. Hole is breathing. Pull to 7" shoe. Monitor well, static. Remove top drive blower hose. Blow down top drive. POH from 10330' to 353'. Pull at reduced rate, monitor hole fill. Stand back BHA. Left 6" of mud motor shaft and bit in hole. Down load MWD. L/D mud motor. M/U new mud motor & roller cone bit. P/U MWD, orient, upload. RIH with BHA to 450' & pulse check. RIH to 10245'. Fill pipe at 2500' intervals. Slip and cut drill line. Replace "O" ring on top drive valve bank. Service top drive, hook up blower hose. RIH to 11610' to ensure fish is on bottom. POH to 11515'. Side track in open hole, cut a trench from 11515' to 11522'. Begin time drilling from 11522' to 11532'. HWT = 187K, SWT = 137K, RWT = 160K. torque off bottom = 8/9K, on = 8/9K. pump 274 gpm @ 1750 psi. Side track in open hole from 11532'. Rotate and time drill to 11590'. Drill to 11616'. AST = 0, ART = 3.0 hrs. Total mud lost to well in last 24 hrs = 163 bbl. Total lost to well = 1601 bbl. Printed: 9/19/2005 8:02:29 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 14-11 14-11 REENTER+COMPLETE Date ~ From - To Hours ', Task I Code NPT -- - - - 9/12/2005 ~ 03:00 - 11:30 ~ 8.50 DRILL ~ P 11:30 - 12:30 1.001 DRILL ~ P 12:30 - 13:30 1.00 DRILL ~ P 13:30 - 15:00 1.50 DRILL P 15:00 - 16:00 1.00 DRILL P 16:00 - 17:00 1.00 DRILL P 17:00 - 20:30 3.50 DRILL P 20:30 - 22:30 2.00 DRILL P 22:30 - 23:00 0.50 CASE P 23:00 - 00:00 1.00 CASE P 9/13/2005 00:00 - 01:30 1.50 CASE P 01:30 - 02:00 0.50 CASE P 02:00 - 07:00 5.00 CASE P 07:00 - 07:30 0.50 CASE P 07:30 - 08:00 0.50 CASE P 08:00 - 09:00 1.00 CASE P 09:00 - 10:00 ~ 1.00 ~ CASE ~ P 10:00 - 10:30 0.50 CASE P 10:30 - 16:30 6.00 CASE P 16:30 - 18:30 2.00 CASE P 18:30 - 20:00 1.50 BUNCO 20:00 - 00:00 4.00 RUN 9/14/2005 ~ 00:00 - 05:30 5.50 ~ RU 05:30 - 06:00 0.50 BUNCO 06:00 - 09:30 3.50 BUNCO 09:30 - 10:30 1.00 BUNCO 10:30 - 11:30 1.00 BUNCO 11:30 - 14:00 I 2.501 RUN 14:00 - 15:30 I 1.501 RU 15:30 - 16:30 I 1.001 BOPSUR P Page 7 of 8 Spud Date: 7/4/1981 Start: 8/25/2005 End: Rig Release: Rig Number: Phase Description of Operations PROD1 Drill ahead in new hole to 11804'. AST = .89, ART = 5.37 HWT = 190K, DWR = 130K, RWT = 160K. Torque off bottom = 8K, on = 9K. Pump @ 277 gpm @ 1800 psi. PROD1 Circ up samples for geologist from 11804'. Pump @ 275 gpm @ 1780 psi. Well is at T.D. PROD1 POH to 11500', orient motor to low side, slide through OH side track. RIH to 11804'. Hole in good shape. PROD1 Pump sweep, Circ until clean. Spot liner running pill. PROD1 POH from 11804' to 7" shoe @ 10330'. PROD1 Drop ball and shear pump out sub. CBU, pump dry job. Monitor well PROD1 POH from 10330' to BHA @ 354'. PROD1 L/D HWDP, jars & drill collars. Down load MWD, pull pulasr. L/D mud motor & bit. Clear & clean rig floor. RUNPRD R/U to run 4 1/2" liner. RUNPRD PJSM with drill crew, Baker Rep. & WSL. Run 4 1/2" 12.6# BTC slotted liner and IBT-M solid liner. RUNPRD RIH with 4.5 " L-8026# BTC slotted liner &IBT-M solid liner. RUNPRD M/U liner hanger. RD handling tools. RIH with liner on drill pipe. Liner weight = 20K. Monitor well. Static. RUNPRD RIH w/ 4.5" liner on D. P. to 10,330'. RUNPRD Circ DP volume. 5 BPM 700 psi. Monitor well. Breathing - 5 flow. UP 170K, DN 150K, RT 160K. TO 4100 ft lbs. RUNPRD Run 4.5" liner to bottom @ 11,804'. No problems. RUNPRD Drop ball. Circ ball to liner hanger. 5 bpm @ 710 psi. Pressure to 3,500 psi and set hanger. Set down 40K on hanger. Bleed off pressure. UP 174k, DN 152K. Set liner top packer w/ 50k. Two surf indications. Rot down w/ 50K 4k torque. L.D. two singles DP. RUNPRD Displace well to 8.4 ppg sea water @ 10,131'. 10 BPM @ 2,700 psi. Monitor well. RUNPRD Lubricate rig /service top drive. RUNPRD POOH w/ running tool laying down D.P. L.D. running tool. RUNPRD MU mule shoe sub and RIH w/ 1,770' DP. POOH lay down DP. RUNCMP Pulled wear ring. Clear floor. RU to run 4.5" 13 Cr80 tbg completion. PJSM. RUNCMP M.U. tail pipe and packer. RIH picking up 4.5" 12.6# 13Cr80 Vam top tubing to 2,883'. Hole taking 2 BPH sea water. RUNCMP RIH picking up 4.5" 12.6# 13Cr80 Vam Top tbg to 7,463'.TO 4,440 ft lbs. RUNCMP Lubricate rig and service top drive. RUNCMP RIH picking up 4.5" 13 Cr80 tbg to 10,130'. RUNCMP Space out and M:U. hanger. RUNCMP Land tbg hanger. UP 135k, DN 115K. RILDS. Lay Down landing jt. RUNCMP RU circ lines. Test lines to 4,000 psi. Reverse circ one tbg vol clean seawater. Displace w/ inhibitited sea water to top GLM. RUNCMP Drop ball and rod. Pressure to 3,500 psi on tbg and set pkr @ 10,078'. Test tbg for 30 min. Held. Bleed press to 1,500 psi. Pressure annulus to 3,500 psi. Test packer/ csg to 3,500 psi for 30 min. Held.Bleed off tbg press and sheared DCK in top GLM. RUNCMP Blow down all lines. Drain stack. Set TWCV and test to 1,000 psi. Printed: 9/19/2005 8:02:29 AM • • BP EXPLORATION Page 8 of 8 Operations Summary Report Legal Well Name: 14-11 Common Well Name: 14-11 Spud Date: 7/4/1981 Event Name: REENTER+COMPLETE Start: 8/25/2005 End: Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To :Hours Task ~ Code NPT --_ ~ ~ Phase Description of Operations ! _ _ 9/14/2005 16:30 - 19:00 2.50 BOPSU P RUNCMP ND BOP's. Split stack @ mud cross. 19:00 - 22:00 3.00 WHSUR P RUNCMP Prep wellhead - N.U. Tbg head adaptor flange. Test to 5,000 psi for 10 min. Held 22:00 - 00:00 2.00 WHSUR P RUNCMP NU tree. Adaptor flange turned wrong and flow line not lining up with tree. ND and reposition adaptor flange. 9/15/2005 00:00 - 03:00 3.00 WHSUR P RUNCMP N.U. adaptor flange and tree. Test to 5,000 psi. 03:00 -04:00 1.00 WHSUR P RUNCMP Pull TWCV w/ lubricator. 04:00 - 07:00 3.00 WHSUR P RUNCMP Freeze protect tbg /annulus - RU Hot oil truck and test lines to 3,000 psi. Reverse circ 77 bbls diesel. U-Tube diesel. 07:00 - 07:30 0.50 WHSUR P RUNCMP Dry rod BPV. Test from below to 1,000 psi. 07:30 - 08:00 WHSUR P 0.50 RUNCMP N. D. second annular valve. Secure well. Release rig C~? 0800 1 hrs 9-15-2005 Printed: 9!19/2005 8:02:29 AM Halliburton Sperry-Sun North Slope Alaska BPXA 14-11A Job No. AKZZ3907191, Surveyed: 12 September, 2005 Survey Report 16 September, 2005 Your Ref: APl 500292052901 Surface Coordinates: 5938552.91 N, 674726.84E (70° 14' 16.1405" N, 148° 35' 20.6654" VVJ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 71.40ft above Mean Sea Level 5-~~I'~r'~SUI"1 [ZRELLING SEE~VECES A Halliburton Company DES la dITIV Survey Ref; svy4664 • Halliburton Sperry-Sun Survey Report for 14-11A Your Ref.~AP1500292052901 Job No. AKZZ3907191, Surveyed: 12 September, 2005 North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 11518.78 97.860 291.030 8883.48 8954.88 3033.89 S 1495.02 W 5935485.19 N 673302.52E 1224.92 Tie On Point 11551.84 96.120 290.420 8879.45 8950.85 3022.28 S 1525.71 W 5935496.09 N 673271.57E 5.573 1256.50 Window Point 11583.04 97.170 290.740 8875.84 8947.24 3011.38 S 1554.73 W 5935506.31 N 673242.31E 3.516 1286.35 11611.32 99.100 298.010 8871.83 8943.23 2999.84 S 1580.21 W 5935517.25 N 673216.57E 26.346 1312.74 11645.64 100.040 292.600 8866.12 8937.52 2985.38 S 1610.79 W 5935531.00 N 673185.66E 15.783 1344.47 11676.66 100.550 292.670 8860.58 8931.98 2973.63 S 1638.96 W 5935542.09 N 673157.23E 1.659 1373.56 11704.51 101.060 292.620 8855.36 8926.76 2963.10 S 1664.21 W 5935552.04 N 673131.74E 1.840 1399.62 11752.88 100.180 290.150 8846.44 8917.84 2945.77 S 1708.47 W 5935568.34 N 673087.09E 5.339 1445.23 11804.00 100.180 290.150 8837.41 8908.81 2928.44 S 1755.71 W 5935584.57 N 673039.46E 0.000 1493.80 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference . Northings and Eastings are relative to Well Reference . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 275.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11804.OOft., The Bottom Hole Displacement is 3414.42ft., in the Direction of 210.944° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 11518.78 8954.88 3033.89 S 1495.02 W 11551.84 8950.85 3022.28 S 1525.71 W 11804.00 8908.81 2928.44 S 1755.71 W Comment Tie On Point Window Point Projected Survey BPXA ~, LJ L 16 September, 2005 - 8:51 Page 2 of 3 DrillQuesf 3.03.06.008 North Slope Alaska Survey tool program for 14-11A From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 7100.40 6836.07 7100.40 6836.07 11804.00 8908.81 Halliburton Sperry-Sun Survey Reporf for 14-11A Your Ref; AP1500292052901 Job No. AKZZ3907191, Surveyed: 12 September, 2005 BPXA Survey Tool Description CB-GYRO-MS (14-11) MWD+IIFR+MS (14-11APB1) :7 16 September, 2005 - 8;51 Page 3 of 3 DrillQuest 3.03.06.008 Halliburton Sperry-Sun North Slope Alaska BPXA 14-11A (mwd) Job No, AKMW3907191, Surveyed: 12 September, 2005 Survey Report 16 September, 2005 Your Ref: AP1500292052901 Surface Coordinates: 5938552.91 N, 674726.84E (70° 14' 16,1405" N, 148° 35'20,6654" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 71.40ft above Mean Sea Level ~~F~~~~/-SUIT • 5 E t~ y" t C E"5 Survey Ref: svy4665 A Halliburton Company Y Halliburton Sperry-Sun Survey Report for 14-11A (mwd) Your Ref: API 500292052901 Job No. AKMW3907191, Surveyed: 12 September, 2005 North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11518.78 97.860 308.520 8883.47 8954.87 3089.59 S 1525.20 W 5935428.81 N 673273.65 E 11551.84 96.120 287.990 8879.41 8950.81 3074.15 S 1553.95 W 5935443.57 N 673244.55 E 11583.04 97.170 293.700 8875.79 8947.19 3063.13 S 1582.90 W 5935453.92 N 673215.35 E 11611.32 99.100 300.270 8871.79 8943.19 3050.44 S 1607.83 W 5935466.03 N 673190.13 E 11645.64 100.040 320.350 8866.03 8937.43 3028.67 S 1633.51 W 5935487.20 N 673163.96 E 11676.66 100.550 314.920 8860.48 8931.88 3006.13 S 1654.06 W 5935509.26 N 673142.88 E 11704.51 101.060 308.230 8855.25 8926.65 2987.98 S 1674.51 W 5935526.93 N 673122.02 E 11752.88 100.180 306.390 8846.34 8917.74 2959.17 S 1712.33 W 5935554.86 N 673083.55 E 11804.00 100.180 306.390 8837.30 8908.70 2929.32 S 1752.83 W 5935583.76 N 673042.36 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are r elative to True North. Vertical depths are relative to Well Reference . Northings and Eastings are relative to Well Reference . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 275.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11804.OOft., The Bottom Hole Displacement is 3413.70ft., in the Direction of 210.895° (True). Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 11518.78 8954.87 3089.59 S 1525.20 W 11551.84 8950.81 3074.15 S 1553.95 W 11804.00 8908.70 2929.32 S 1752.83 W Comment Tie On Point Window Point Projected Survey 16 September, 2005 - 8:51 Page 2 of 3 Dogleg Vertical Rate Section Comment (°/100ft) 1250.12 Tie On Point 61.855 1280.11 Window Point 18.487 1309.91 23.988 1335.85 57.750 1363.32 17.301 1385.77 23.666 1407.72 4.158 1447.90 0.000 1490.85 Projected Survey BPXA DrillQuest 3.03.06.008 • • • Halliburton Sperry-Sun Survey Report for 14-11A (mwd) Your Ref: AP1500292052901 Job No. AKMW3907191, Surveyed: 12 September, 2005 North Slope Alaska BPXA Survey tool program for 14-11A (mwd) From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 7100.40 6836.07 CB-GYRO-MS (14-11) 7100.40 6836.07 11804.00 8908.70 MWD Magnetic (14-11AP61 (mwd)) • • 16 September, 2005 - 8:51 Page 3 of 3 DrillQuest 3.03.06.008 Halliburton Sperry-Sun North Slope Alaska BPXA 14-11APB 1 Job No. AKZZ3907191, Surveyed: 11 September, 2005 Survey Report 75 September, 2005 Your Ref: AP1500292052970 Surface Coordinates: 5938552.91 N, 674726.84E (70° 14' 16.1405" N, 148° 35' 20.6654" V1~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 71.40ft above Mean Sea Level !~" ~enr~/-~Uf"1 BRI:LLIIVG SERVICES A Halliburton Company Survey Ref: svy4662 Halliburton Sperry-Sun Survey Report for 14-11AP61 Your Ref: API 500292052970 Job No. AKZZ3907191, Surveyed: 11 September, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 7100.40 34.750 163.020 6764.67 6836.07 897.81 S 359.88E 5937663.68 N 675107.43 E -436.76 Tie On Point MWD+IIFR+MS 7109.00 34.710 163.020 6771.74 6843.14 902.50 S 361.31E 5937659.03 N 675108.96E 0.465 -438.59 Window Point 7190.53 38.960 160.980 6836.98 6908.38 948.96 S 376.45E 5937612.93 N 675125.18E 5.424 -457.72 7284.39 44.250 158.720 6907.15 6978.55 1007.41 S 397.97E 5937554.99 N 675148.04E 5.858 -484.25 7378.16 44.050 159.270 6974.43 7045.83 1068.39 S 421.38E 5937494.58 N 675172.86E 0.461 -512.89 7471.94 45.750 164.920 7040.88 7112.28 1131.34 S 441.67E 5937432.11 N 675194.60E 4.622 -538.59 7565.61 46.040 162.770 7106.08 7177.48 1195.94 S 460.38E 5937367.96 N 675214.81E 1.677 -562.86 7659.38 46.370 165.710 7170.98 7242.38 1261.06 S 478.76E 5937303.28 N 675234.69E 2.290 -586.84 7751.92 45.840 168.210 7235.15 7306.55 1326.02 S 493.81E 5937238.69 N 675251.24E 2.029 -607.50 7845.82 46.490 171.070 7300.19 7371.59 1392.63 S 505.98E 5937172.38 N 675264.95E 2.303 -625.43 7938.24 46.910 176.490 7363.60 7435.00 1459.45 S 513.25E 5937105.74 N 675273.77E 4.291 -638.49 8031.51 48.340 185.870 7426.53 7497.93 1528.19 S 511.77E 5937036.99 N 675273.88E 7.582 -643.01 8125.21 47.680 187.100 7489.22 7560.62 1597.39 S 503.91E 5936967.63 N 675267.63E 1.203 -641.21 8217.97 48.700 191.800 7551.08 7622.48 1665.55 S 492.54E 5936899.22 N 675257.84E 3.933 -635.83 8311.10 47.850 195.570 7613.07 7684.47 1733.06 S 476.11E 5936831.35 N 675242.99E 3.156 -625.35 8404.53 47.260 198.710 7676.13 7747.53 1798.93 S 455.81E 5936765.03 N 675224.21E 2.559 -610.86 8496.99 49.660 205.140 7737.48 7808.88 1863.03 S 429.93E 5936700.34 N 675199.83E 5.814 -590.67 8589.73 51.280 206.550 7796.51 7867.91 1927.40 S 398.74E 5936635.27 N 675170.14E 2.104 -565.21 8685.36 53.050 210.250 7855.18 7926.58 1993.80 S 362.80E 5936568.05 N 675135.75E 3.572 -535.19 8778.57 56.120 213.900 7909.20 7980.60 2058.12 S 322.44E 5936502.82 N 675096.89E 4.585 -500.59 8871.99 57.400 216.880 7960.41 8031.81 2121.79 S 277.19E 5936438.11 N 675053.12E 2.999 -461.06 8965.84 57.640 216.460 8010.81 8082.21 2185.30 S 229.91E 5936373.53 N 675007.33E 0.456 -419.49 9058.74 57.510 216.820 8060.62 8132.02 2248.22 S 183.11E 5936309.54 N 674962.00E 0.356 -378.36 9151.72 56.730 217.200 8111.10 8182.50 2310.57 S 136.11E 5936246.11 N 674916.45E 0.906 -336.97 9245.36 57.750 216.250 8161.77 8233.17 2373.69 S 89.02E 5936181.92 N 674870.85E 1.384 -295.57 9338.91 58.210 217.750 8211.37 8282.77 2437.03 S 41.29E 5936117.49 N 674824.59E 1.446 -253.53 9426.24 58.500 217.000 8257.19 8328.59 2496.11 S 3.84 W 5936057.38 N 674780.85E 0.803 -213.73 9526.96 59.020 217.310 8309.43 8380.83 2564.74 S 55.85 W 5935987.56 N 674730.44E 0.579 -167.89 9619.79 57.120 219.430 8358.53 8429.93. 2626.51 S 104.74 W 5935924.68 N 674683.00E 2.819 -124.58 9713.60 56.920 217.160 8409.60 8481.00 2688.27 S 153.50 W 5935861.81 N 674635.68E 2.041 -81.38 9806.88 57.410 218.330 8460.17 8531.57 2750.24 S 201.48 W 5935798.74 N 674589.15E 1.178 -38.99 9900.29 56.290 216.990 8511.26 8582.66 2812.14 S 249.26 W 5935735.74 N 674542.81E 1.697 3.22 9993.42 54.880 215.200 8563.89 8635.29 2874.21 S 294.53 W 5935672.64 N 674498.99E 2.192 42.90 10085.48 54.600 217.350 8617.04 8688.44 2934.81 S 339.00 W 5935611.03 N 674455.94E 1.931 81.92 10179.50 54.680 218.330 8671.45 8742.85 2995.36 S 386.04 W 5935549.41 N 674410.32E 0.854 123.50 • 15 September, 2005 - 17:39 Page 2 of 4 DrillQuest 3.03.06.00$ Halliburton Sperry-Sun Survey Report for 14-11AP61 Your Ref.• AP1500292052970 Job No. AKZZ3907191, Surveyed: 11 September, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 10271.47 55.630 220.220 8724.00 8795.40 3053.78 S 433.82 W 5935489.89 N 674363.90E 1.978 166.01 10334.66 55.790 220.300 8759.60 8831.00 3093.62 S 467.56 W 5935449.28 N 674331.10E 0.274 196.15 10365.73 55.860 220.600 8777.06 8848.46 3113.18 S 484.24 W 5935429.34 N 674314.88E 0.830 211.06 10395.88 55.350 220.230 8794.09 8865.49 3132.13 S 500.37 W 5935410.03 N 674299.19E 1.971 225.48 10430.91 55.480 220.760 8813.97 8885.37 3154.06 S 519.09 W 5935387.67 N 674280.98E 1.300 242.22 10462.18 59.530 225.180 8830.77 8902.17 3173.33 S 537.08 W 5935367.99 N 674263.44E 17.599 258.46 10490.58 62.290 230.490 8844.59 8915.99 3189.97 S 555.47 W 5935350.93 N 674245.44E 19.007 275.33 10523.56 62.680 235.620 8859.83 8931.23 3207.54 S 578.84 W 5935332.82 N 674222.49E 13.845 297.08 10554.81 61.670 241.170 8874.43 8945.83 3222.02 S 602.36 W 5935317.80 N 674199.31E 16.034 319.25 10583.01 61.170 244.440 8887.92 8959.32 3233.33 S 624.38 W 5935305.98 N 674177.56E 10.336 340.20 10616.99 61.990 250.420 8904.10 8975.50 3244.79 S 651.96 W 5935293.88 N 674150.25E 15.663 366.68 10648.15 65.730 254.840 8917.83 8989.23 3253.12 S 678.65 W 5935284.94 N 674123.76E 17.496 392.54 10676.38 69.970 259.800 8928.48 8999.88 3258.84 S 704.14 W 5935278.63 N 674098.40E 22.140 417.44 10710.81 73.730 263.150 8939.21 9010.61 3263.68 S 736.49 W 5935273.04 N 674066.18E 14.307 449.24 10741.01 75.670 265.390 8947.18 9018.58 3266.58 S 765.47 W 5935269.47 N 674037.27E 9.615 477.86 10769.33 77.940 270.830 8953.65 9025.05 3267.49 S 793.02 W 5935267.93 N 674009.76E 20.346 505.22 10803.11 79.630 275.050 8960.22 9031.62 3265.78 S 826.10 W 5935268.86 N 673976.64E 13.235 538.32 10833.24 84.750 277.780 8964.31 9035.71 3262.44 S 855.75 W 5935271.51 N 673946.92E 19.217 568.15 10861.54 89.380 283.550 8965.76 9037.16 3257.22 S 883.50 W 5935276.10 N 673919.06E 26.116 596.26 10897.51 92.650 284.500 8965.12 9036.52 3248.50 S 918.39 W 5935284.00 N 673883.98E 9.467 631.77 10928.77 92.280 285.840 8963.78 9035.18 3240.33 S 948.53 W 5935291.47 N 673853.65E 4.443 662.51 10956.79 95.500 290.330 8961.88 9033.28 3231.66 S 975.10 W 5935299.53 N 673826.89E 19.687 689.73 10990.63 98.740 287.670 8957.68 9029.08 3220.72 S 1006.84 W 5935309.72 N 673794.91E 12.349 722.30 11019.89 98.430 288.020 8953.32 9024.72 3211.86 S 1034.38 W 5935317.95 N 673767.17E 1.588 750.51 11050.58 98.050 289.300 8948.92 9020.32 3202.14 S 1063.15 W 5935326.99 N 673738.18E 4.309 780.02 11099.70 98.670 290.880 8941.78 9013.18 3185.45 S 1108.79 W 5935342.62 N 673692.16E 3.424 826.94 11143.87 98.980 290.710 8935.00 9006.40 3169.95 S 1149.60 W 5935357.17 N 673651.01E 0.798 868.94 11190.65 98.610 291.800 8927.85 8999.25 3153.19 S 1192.68 W 5935372.93 N 673607.55E 2.435 913.32 11235.93 98.230 293.110 8921.22 8992.62 3136.08 S 1234.08 W 5935389.07 N 673565.77E 2.982 956.05 11285.99 97.490 290.390 8914.37 8985.77 3117.71 S 1280.13 W 5935406.37 N 673519.30E 5.582 1003.53 11329.94 97.120 289.390 8908.78 8980.18 3102.88 S 1321.12 W 5935420.25 N 673477.98E 2.409 1045.66 11379.46 96.870 291.830 8902.75 8974.15 3085.58 S 1367.12 W 5935436.48 N 673431.59E 4.917 1093.00 11424.47 98.300 290.250 8896.81 8968.21 3069.56 S 1408.76 W 5935451.53 N 673389.59E 4.712 1135.87 11471.11 98.170 294.290 8890.12 8961.52 3052.07 S 1451.47 W 5935468.02 N 673346.49E 8.577 1179.94 11518.78 97.860 291.030 8883.48 8954.88 3033.89 S 1495.02 W 5935485.19 N 673302.52E 6.803 1224.92 • 15 September, 2005 - 17:39 Page 3 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 14-11AP61 Your Ref: API 500292052970 Job No. AKZZ3907191, Surveyed: 11 September, 2005 Norfh Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11564.27 97.920 292.060 8877.23 8948.63 3017.34 S 1536.94 W 5935500.76 N 673260.24 E 11616.00 97.920 292.060 8870.10 8941.50 2998.10 S 1584.42 W 5935518.90 N 673212.32 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference . Northings and Eastings are relative to Well Reference . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 275.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11616.OOft., The Bottom Hole Displacement is 3391.02ft., in the Direction of 207.855° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 7100.40 6836.07 897.81 S 359.88E Tie On Point 7109.00 6843.14 902.50 S 361.31E Window Point 11616.00 8941.50 2998.10 S 1584.42 W Projected Survey Survey tool program for 14-11APB1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 7100.40 6836.07 CB-GYRO-MS (14-11) 7100.40 6836.07 11616.00 8941.50 MWD+IIFR+MS (14-11APB1) Dogleg Vertical Rate Section Comment (°/100ft) 2.247 1268.11 0.000 1317.09 Projected Survey BPXA C, • 15 September, 2005 - 17:39 Page 4 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun North Slope Alaska BPXA 14-11APB1 (mwd) Job No. AKMW3907191, Surveyed: 11 September, 2005 Survey Report 15 September, 2005 Your Ref: AP1500292052970 Surface Coordinates: 5938552.91 N, 674726.84E (70° 14' 16.1405" N, 148° 35' 20.6654" Vl/) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 71.40ft above Mean Sea Level DRILLING SE~VFCES Survey Ref:svy4663 A Halliburton Company C~ Halliburton Sperry-Sun Survey Report for 14-11AP81 (mwd) Your Ref: AP1500292052970 Job No. AKMW3907191, Surveyed: 11 September, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Easting5 Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 7100.40 34.750 163.020 6764.67 6836.07 897.81 S 359.88E 5937663.68 N 675107.43 E -436.76 Tie On Point MWD Magnetic 7109.00 34.710 163.020 6771.74 6843.14 902.50 S 361.31E 5937659.03 N 675108.96E 0.465 -438.59 Window Point 7190.53 38.960 154.160 6837.03 6908.43 947.82 S 379.28E 5937614.13 N 675127.98E 8.333 -460.44 7284.39 44.250 159.340 6907.21 6978.61 1005.08 S 403.72E 5937557.46 N 675153.74E 6.719 -489.78 7378.16 44.050 160.260 6974.49 7045.89 1066.38 S 426.27E 5937496.70 N 675177.71E 0.716 -517.59 7471.94 45.750 165.250 7040.94 7112.34 1129.57 S 445.84E 5937433.98 N 675198.74E 4.169 -542.60 7565.61 46.040 164.970 7106.13 7177.53 1194.57 S 463.13E 5937369.39 N 675217.53E 0.377 -565.48 7659.38 46.370 167.550 7171.03 7242.43 1260.31 S 479.20E 5937304.05 N 675235.11E 2.017 -587.22 7751.92 45.840 168.800 7235.19 7306.59 1325.57 S 492.87E 5937239.11 N 675250.29E 1.129 -606.52 7845.82 46.490 171.200 7300.23 7371.63 1392.27 S 504.62E 5937172.71 N 675263.59E 1.969 -624.04 7938.24 46.910 176.470 7363.64 7435.04 1459.10 S 511.83E 5937106.07 N 675272.34E 4.174 -637.05 8031.51 48.340 186.200 7426.58 7497.98 1527.82 S 510.16E 5937037.32 N 675272.27E 7.853 -641.37 8125.21 47.680 187.850 7489.27 7560.67 1596.94 S 501.65E 5936968.03 N 675265.36E 1.486 -638.92 8217.97 48.700 192.220 7551.12 7622.52 1664.98 S 489.58E 5936899.72 N 675254.87E 3.679 -632.83 8311.10 47.850 199.390 7613.15 7684.55 1731.79 S 470.70E 5936832.50 N 675237.55E 5.816 -619.85 8404.53 47.260 199.850 7676.21 7747.61 1796.73 S 447.55E 5936767.04 N 675215.91E 0.729 -602.45 8496.99 49.660 205.260 7737.54 7808.94 1860.57 S 420.97E 5936702.60 N 675190.82E 5.089 -581.53 8589.73 51.280 206.050 7796.57 7867.97 1925.04 S 390.00E 5936637.42 N 675161.35E 1.866 -556.29 8685.36 53.050 210.790 7855.24 7926.64 1991.41 S 354.04E 5936570.24 N 675126.93E 4.329 -526.26 8778.57 56.120 214.460 7909.26 7980.66 2055.34 S 313.06E 5936505.38 N 675087.45E 4.598 -491.01 8871.99 57.400 217.630 7960.48 8031.88 2118.49 S 267.09E 5936441.18 N 675042.95E 3.151 -450.71 8965.84 57.640 217.180 8010.88 8082.28 2181.38 S 218.99E 5936377.19 N 674996.33E 0.479 -408.28 9058.74 57.510 217.560 8060.69 8132.09 2243.70 S 171.40E 5936313.78 N 674950.19E 0.373 -366.30 9151.72 56.730 217.280 8111.17 8182.57 2305.71 S 123.95E 5936250.69 N 674904.19E 0.876 -324.43 9245.36 57.750 216.720 8161.84 8233.24 2368.60 S 76.56E 5936186.72 N 674858.27E 1.200 -282.71 9338.91 58.210 217.850 8211.44 8282.84 2431.71 S 28.51E 5936122.51 N 674811.70E 1.136 -240.34 9426.24 58.500 217.640 8257.26 8328.66 2490.50 S 17.00 W 5936062.69 N 674767.56E 0.390 -200.13 9526.96 59.020 217.650 8309.49 8380.89 2558.68 S 69.59 W 5935993.30 N 674716.56E 0.516 -153.68 9619.79 57.120 219.840 8358.59 8429.99 2620.13 S 118.88 W 5935930.73 N 674668.71E 2.863 -109.93 9713.60 56.920 217.570 8409.66 8481.06 2681.54 S 168.09 W 5935868.20 N 674620.94E 2.041 -66.26 9806.88 57.410 218.800 8460.24 8531.64 2743.14 S 216.54 W 5935805.49 N 674573.93E 1.226 -23.36 9900.29 56.290 217.620 8511.32 8582.72 2804.58 S 264.92 W 5935742.94 N 674526.99E 1.599 19.47 9993.42 54.880 215.430 8563.96 8635.36 2866.31 S 310.65 W 5935680.17 N 674482.70E 2.461 59.65 10085.48 54.600 217.370 8617.11 8688.51 2926.81 S 355.25 W 5935618.66 N 674439.51E 1.747 98.81 10179.50 54.680 218.810 8671.52 8742.92 2987.15 S 402.55 W 5935557.23 N 674393.62E 1.252 140.67 • • 15 September, 2005 - 17:41 Page 2 of 4 Dr111Quest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 14-11APB1 (mwd) Your Ref: API 500292052970 Job No. AKMW3907191, Surveyed: 11 September, 2005 North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 10271.47 55.630 220.750 8724.07 8795.47 3045.15 S 450.85 W 5935498.13 N 674346.68E 2.016 183.73 10334.66 . 55.790 220.890 8759.67 8831.07 3084.66 S 484.97 W 5935457.84 N 674313.48E 0.312 214.28 10365.73 55.860 221.080 8777.12 8848.52 3104.06 S 501.83 W 5935438.05 N 674297.08E 0.554 229.38 10395.88 55.350 220.640 8794.16 8865.56 3122.88 S 518.11 W 5935418.86 N 674281.24E 2.076 243.96 10430.91 55.480 221.200 8814.04 8885.44 3144.67 S 537.00 W 5935396.64 N 674262.86E 1.367 260.88 10462.18 59.530 225.720 8830.84 8902.24 3163.79 S 555.14 W 5935377.11 N 674245.16E 17.783 277.29 10490.58 62.290 232.060 8844.66 8916.06 3180.08 S 573.84 W 5935360.39 N 674226.85E 21.789 294.49 10523.56 62.680 236.620 8859.90 8931.30 3197.12 S 597.60 W 5935342.80 N 674203.49E 12.319 316.68 10554.81 61.670 240.140 8874.49 8945.89 3211.61 S 621.12 W 5935327.77 N 674180.31E 10.472 338.85 10583.01 61.170 245.350 8887.99 8959.39 3222.95 S 643.13 W 5935315.93 N 674158.57E 16.319 359.78 10616.99 61.990 251.600 8904.17 8975.57 3233.90 S 670.91 W 5935304.33 N 674131.05E 16.353 386.50 10648.15 65.730 255.500 8917.90 8989.30 3241.80 S 697.73 W 5935295.81 N 674104.42E 16.438 412.53 10676.38 69.970 259.370 8928.55 8999.95 3247.47 S 723.24 W 5935289.55 N 674079.05E 19.664 437.45 10710.81 73.730 264.150 8939.28 9010.68 3252.15 S 755.60 W 5935284.13 N 674046.80E 17.123 469.29 10741.01 75.670 266.120 8947.25 9018.65 3254.61 S 784.63 W 5935280.99 N 674017.85E 8.992 497.98 10769.33 77.940 269.620 8953.71 9025.11 3255.63 S 812.17 W 5935279.33 N 673990.33E 14.457 525.33 10803.11 79.630 261.860 8960.29 9031.69 3258.10 S 845.19 W 5935276.10 N 673957.38E 23.081 558.01 10833.24 84.750 260.550 8964.38 9035.78 3262.66 S 874.68 W 5935270.85 N 673928.01E 17.530 586.99 10861.54 89.380 263.910 8965.83 9037.23 3266.48 S = 902.67 W 5935266.39 N 673900.11E 20.203 614.54 10897.51 92.650 274.260 8965.20 9036.60 3267.06 S 938.57 W 5935264.98 N 673864.23E 30.168 650.26 10928.77 92.280 278.000 8963.85 9035.25 3263.72 S 969.62 W 5935267.59 N 673833.11E 12.012 681.48 10956.79 95.500 284.020 8961.95 9033.35 3258.39 S 997.05 W 5935272.29 N 673805.57E 24.319 709.26 10990.63 98.740 282.120 8957.75 9029.15 3250.80 S 1029.75 W 5935279.13 N 673772.70E 11.077 742.50 11019.89 98.430 282.050 8953.39 9024.79 3244.74 S 1058.04 W 5935284.53 N 673744.28E 1.086 771.22 11050.58 98.050 287.680 8948.98 9020.38 3236.95 S 1087.38 W 5935291.63 N 673714.76E 18.197 801.13 11099.70 98.670 287.160 8941.84 9013.24 3222.40 S 1133.75 W 5935305.10 N 673668.07E 1.640 848.59 11143.87 98.980 289.560 8935.06 9006.46 3208.65 S 1175.17 W 5935317.89 N 673626.34E 5.415 891.05 11190.65 98.610 289.390 8927.91 8999.31 3193.24 S 1218.76 W 5935332.28 N 673582.41E 0.869 935.81 11235.93 98.230 291.650 8921.28 8992.68 3177.54 S 1260.71 W 5935347.01 N 673540.11E 5.008 978.97 11285.99 97.490 288.680 8914.43 8985.83 3160.45 S 1307.25 W 5935363.02 N 673493.18E 6.060 1026.83 11329.94 97.120 286.900 8908.84 8980.24 3147.13 S 1348.76 W 5935375.37 N 673451.37E 4.104 1069.34 11379.46 96.870 282.900 8902.81 8974.21 3134.49 S 1396.25 W 5935386.90 N 673403.61E 8.033 1117.74 11424.47 98.300 281.230 8896.87 8968.27 3125.17 S 1439.87 W 5935395.21 N 673359.77E 4.860 1162.02 11471.11 98.170 290.260 8890.18 8961.58 3112.66 S 1484.25 W 5935406.70 N 673315.12E 19.163 1207.32 11518.78 97.860 308.520 8883.47 8954.87 3089.59 S 1525.20 W 5935428.81 N 673273.65E 37.933 1250.12 BPXA n ~J 15 Sep#ember, 2005 - 17:41 Page 3 of 4 DrlllQuest 3.03.06.008 ` Halliburton Sperry-Sun s Survey Report for 14-11APB1 (mwd) Your Ref: AP1500292052970 Job No. AKMW3907191, Surveyed: 11 September, 2005 North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11564.27 97.920 310.410 8877.23 8948.63 3060.95 S 1559.99 W 5935456.63 N 673238.21 E 11616.00 97.920 310.410 8870.10 8941.50 3027.74 S 1599.00 W 5935488.93 N 673198.43 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference . Northings and Eastings are relative to Well Reference . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 275.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11616.OOft., The Bottom Hole Displacement is 3424.03ft., in the Direction of 207.839° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 7100.40 6836.07 897.81 S 359.88E Tie On Point 7109.00 6843.14 902.50 S 361.31E Window Point 11616.00 8941.50 3027.74 S 1599.00 W Projected Survey Survey tool program for 14-11APB1 (mwd) From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 7100.40 6836.07 CB-GYRO-MS (14-11) 7100.40 6836.07 11616.00 8941.50 MWD Magnetic (14-11AP61 (mwd)) BPXA Dogleg Vertical Rate Section Comment (°/100ft) 4.118 1287.27 0.000 1329.03 Projected Survey • 15 September, 2005 - 17:41 Page 4 of 4 DrillQuest 3.03.06.008 TREE = GRAY GEN 2 WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 71' BF. ELEV = KOP = 10430' Max Angle = 101 @ 11704' Datum MD = 9526' Datum TV D = 8800' SS 14 -11 A _ S,~r,rNOT~: FROM DRLG -DRAFT 13-3/8" CSG, 72#, L-80, ID = 12.347" 2651' Top of Tie-Back Cement 3150' 2221' 4-1/2" X Nipple (3.813" ID) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 8822 8005 57 KGB-2 DOME BK 16 09/23/05 2 7320 7004 44 KGB-2 SO BK 20 09/23/05 3 6112 6021 33 KGB-2 DMY BK 0 4 4743 4743 0 KGB-2 DMY BK 0 5 3166 3166 0 KGB-2 DMY BK 0 6 6930' Top of the 7" 26#, L-80, BTGM liner NIPPLE I ~ loosr • ` 10088' Top of 9-5/8" Window 7109' ' . 10111' 10131' ' 10130' 5-1/2" TBG, 17#, L-80 Cut @ 7500' Top of Cement 8600' 4-1/2" AVA TBG Patch 30.17' (2.990 ID) 8825' 4-1/2" TBG-NPC, 12.6#, N-80, 0.0152 bpf, ID = 3.958" 9016' 9-5/8" CSG, 47#, SOO-95, ID = 8.681" 9298' TOP OF 7" LNR 8970' PERFORATION SUMMARY REF LOG: BRCS ON 07/25!81 ANGLE AT TOP PERF: 36 @ 9556' Note: Refer to Production DB for historical pert' data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" SLTD ! 1804 - 11146 SLOT 09/16/05 4-1/2" SLTD 10650 - 10411 SLOT 09/16/05 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 10445' 4 1/2" X Nipple (3.813" ID) 7" x 4 1/2" Baker S3 Packer 4 1/2" X Nipple (3.813" ID) 4 1/2" XN Nipple (3.725" ID) 4 1/2" Hanger /liner top packer 4-1/2" 12.6#, L-80, IBT Slotted Liner 11804' 8902' S-1/2" BAKER PBR ASSY 9013' 4-1/2" CAMCO DB-6 LAND NIP, ID = 3.81" 9016' 4-1/2"TUBING TAIL 9020' --~ '~';r ~" ,r;rS> o_ ~~o~8f 9750' 7" X 4-1/2" BKR FB-1 PKR 9806' ELMD TT LOGGED 08/04/81 PBTD 10414' 10468' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/04!81 ORIGINAL COMPLETION 01 /07/02 RN/TP CORRECTIONS 08/27/03 BHGKK CORRECTIONS 08/08/05 JNC FYoposed ST Completion 09/23/05 PJC DRLG DRAFT CORRECTIONS BP 6cploration (Alaska) PRUDHOE BAY UNIT WELL: 14-11A PEl~INfT No: 1801310 API No: 50-029-20529-01 SEC 9, T10N, R14E, 1282.11' FEL ii 4513.86' FNL • • 19-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 14-11A Dear Dear Sir/Madam: Enclosed is one disk with the "`.PTT and *.PDF files. Tie-on Survey: 11,518.78' MD Window /Kickoff Survey: 11,551.84' MD (if applicable) Projected Survey: 11,804.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 199,,518 Date ~ ~/~-~~ ? Si ned O Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~ v5 ~ ~~ • r~ L_J 19-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 14-11A MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 11,518.78' MD Window /Kickoff Survey: 11,551.84' MD (if applicable) Projected Survey: 11,804.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Ol ~ ~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • • 19-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 14-11A PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 7,100.40' MD Window /Kickoff Survey: 7,109.00' MD (if applicable) Projected Survey: 11,616.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 D ~ ,--- ate S Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~~~~~ ~ r~ -.J r~ u 19-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 14-11A PB1 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 7,100.40' MD Window /Kickoff Survey: 7,109.00' MD (if applicable) Projected Survey: 11,616.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date U ~ oZ.(~{ ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) °' ~' y sue]' ~ ~ ~ G ti,, rY ~ 1 ~ ~ ~ ~ ~ ~ ~ ! ~`1 ~ ~ g r r ~ ~ ~ ~' ~~ . ~ ~ ~' ~ ~ i ~ ~'~ , ; i ~ ~"; _ FRANK H. MURKOWSK/, GOVERNOR ~~~ = ~ ~:~ ~~~ OIL ~i`L ~ 9 333 W. 7r" AVENUE, SUITE 100 COI~TSERQATIOIIT CO1~IItIISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907} 276-7542 Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe 14-11A BP Exploration (Alaska) Inc. Permit No: 205-126 Surface Location: 1776' FNL, 1759' FEL, SEC. 09, T10N, R14E, UM Bottomhole Location: 4558' FNL, 3943' FEL, SEC. 09, T l ON, R 14E, UM Dear Mr. Wesley: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of a ommission to witness any required test. Contact the Commission's petr eu field inspector at (907) 659- 3607 (pager). K. DATED this~day of August, 2005 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~ ALASKA AND GAS CONSERVATION COISSION PERMIT TO DRILL 20 AAC 25.005 i ia. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Development Oil ^ Mgltipl@.zQr~e. ^ Stratigraphic Test ^ Service ^Development Gas ^ Sl~rtgle' 2cS 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 11. Well Name and Number:/ PBU 14-11A 8~~~~°$ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12039 TVD 8900 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1776' FNL 1759' FEL SEC 09 T10N R14E UM 7. Property Designation: ADL 028312 Pool , , . , , , Top of Productive Horizon: 4899' FNL, 2226' FEL, SEC. 09, T10N, R14E, UM 8. Land Use Permit: 13. Approximate Spu te: Augus 5 05 Total Depth: 4558' FNL, 3943' FEL, SEC. 09, T10N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nea est Property: 11250' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 674727 y- 5938553 Zone- ASP4 10. KB Elevation (Height above GL): 70.g feet 15. Distance to Nearest Well Within Pool 14-39 is 550' away at 10635' 16. Deviated Wells: Kickoff Depth: 7100 feet Maximum Hole Angle: 98 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3250 Surface: 2365 18., asing rogram: Size Specifications Setting Depth To Bottom uantdy o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD ND MD TVD includin sta a data 8-1/2" 7" 26# L-80 BTC-M 3381' 6950' 6711' 10331' 8830' 170 sx Class 'G' N/A 7" 26# L-80 BTC-M 3300' 3650' 3650' 6950' 6711' 67 sx Class 'G' ~ N/A 7" 26# L-80 TC-II 3650' Surface Surface 3650' 3650' As above 6-118" 4-1/2" 12.6# L-80 TC-il 1858' 10181' 8747' 12039' 8900' Uncemented Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for RedrilL AND Re-entry Operations) Total Depth MD (ft): 10468 Total Depth TVD (ft): 9628 Plugs (measured): 9771 Effective Depth MD (ft): 9771 Effective Depth TVD (ft): 9069 Junk (measured): None Casin Len th Size Cement Volume MD TVD n r 110' 20" 300 sx Permafrost 110' 110' 2651' 13-3/8" 1640 sx Fondu, 400 sx Arcticset II 2651' 2651' 9298' 9-5/8" 500 sx Class 'G' 9298' 8685' r ion ' r 1475' 7" 550 sx Class 'G' 8970' - 10445' 8416' - 9609' Perforation Depth MD (ft): 9556' - 9724' Perforation Depth TVD (ft): 8895' - 9031' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jeff Cutler, 564-413a Printed Name ve We ley ~ Title Senior Drilling Engineer Prepared By Name/NUmber: Si nature ~~'~'~'~~ ~-' Phone 564-5153 Date ~/~~~~~ ,5i Terrie Hubble, 56a-4628 Commission Use Only Permit To Drill Number: 2.0 ._ Z ,~' API Number: 50- 029-20529-01-00 Permit Approval Date: ~ See cover letter for other requirements Conditions of Approval: Sample quired ! ;~ Yes~~;No Mud Log Required ^ Yes~'No Hydr en Ifide Measures Yes ~~ No Directional Survey Required ~1'es a No Other:~'~:,t f~ r I~ L c Sc7Ca f SI . ~~ , ~ D~ j APPROVED BY A rove ~~~ i ,' THE COMMISSION Date tt~14r~- ~ 1 ~ 9 f Lads' -~,- ~~~r Form i0-401 Fl~i~ed o>~oii~ -" /Subrryit In Duplicate ~ ~ Well Name: 14-11A Planned Well Summary Horizontal Well 14-11 A Type Sidetrack Object ve Zone 4 Producer AFE Number: PBD4P2388 Surface Northin Eastin Offsets TRS Location 5,938,553 674,727 1776' FNL / 1759' FEL 10 N, 14 E, 9 API Number: 50-029-20529-01 Target Northin Eastin Offsets TRS Location 5,935,420 674,340 380' FSL / 2225' FEL 10 N, 14 E, 9 Bottom Northin Eastin Offsets TRS Location 5,935,721 672,614 721' FSL / 1336' FWL 10 N, 14 E, 9 Planned KOP: 7,100' and / 6,835' tvd Planned TD: 12,039' and / 8,900' tvd Ri Nabors 2ES l CBE: 42.26' RTE: 70.8' Directional Program i A roved Well Ian: W 06 Exit oint: 7,100' and / 6,835' tvd Maximum Hole Inclination: ~98° in the tanned 6 1/8" roduction section. Proximity Issues: 14-39 is the only close approach issue with this well. It is a LTSI well and passes anti collision with a 1 in 200 minor risk. A Tolerable Collision Risk worksheet will be com leted for this well. Survey Program: Standard MWD. Nearest Well within ool: Well 14-39, with center-to-center distance of --550' C~ TSAD, 10,635' md. Nearest Pro ert Line 11,250' to unit bounda to SW. 14-11 A Sidetrack Page 1 • • Hole Section: Required Sensors /Service 8 1/2" intermediate: Real time MWD Dir/GR/PWD throu hout the interval 6 1/8" roduction: Real time MWD Dir/GR/Res/Aim throu hout the interval. Two sam le catchers. Cased Hole: None Planned O en Hole: None tanned Logging Program Mud Program Hole Section /operation: Density (ppg) Viscosity 9.0-9.3 50-60 Mill window in the 9 of the HRZ 8,640' PV YP API F 15-22 30-40 <6.0 casing to 100' above the top 9.0 - 9.5 Hole Section /operation: Drilling 8 1/2'; interval from 100' above the top of the HRZ 8,640 and to section TD T e Dens' Viscosit PV YP API FL H LSND 11.0 42 - 52 18 - 25 22 - 28 <5.0 9.0 - 9.5 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade Connection Length Top and / tvd Bottom and / tvd 8 1/2" 7" 26.0# L-80 BTC-M 3,381' 6,950' / 6,711' 10,331' / 8,830' Cs 7" Tie-Back 26.0# L-80 BTC-M 3,300 3,650' / 3650' 6,950' / 6,711' Cs 7" Tie-Back 26.0# L-80 TC-tl 3,650 Surface 3,650' / 3650' 6 1/8" 4 ~/z" Slotted 12.6# L-80 TC-II 1,858' 10,181' / 8,747' 12,039' / 8,900' Tubin 4 ~/z" 12.6# 13-Cr VamTo 10,181' Surface 10,181' / 8,747' Cementing Program Casin Strin 7", 26#, L-80, BTC,, M Drillin Liner Slurry Design Basis: Lead slurry: e,planned. Tail slurry: 1, 0(' of 7" X 8-1/2" annulus with 40% excess, 85' of 7", 26# shoe track. ; :.~' Pre-Flush None tanned id S Fl /V l S acer 35bbls MudPUSH at 12.0 s equence ume: u o Lead Slur None tanned Tail Slur 35 bbl / 197 cf / 17 sxs Class `G', 15.8 .1 cf/sk. ,~ 14-11 A Sidetrack Page 2 U Casin Strin 7", 26#, L-80, BTC-m X TC-II Tie-Back Slurry Design Basis• ' Lead slurry: n e,planned Tail slur ' of 7" X 9-5/8" annulus. Pre-Flush - None tanned Fluids Se uence /V l m S acer 35bbls MudPUSH at 12.0 q o u e: Lead Slur None tanned Tail Slur 97.3 bbl / 546.3 cf / 6 x Class `G', 15.8 .1a~~cf/sk. ~ ..~: _. Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 9 5/8" casin Bride lu to surface 30 min recorded 3,500 si surface 9 5/8" casin window 20' new formation be and FIT 12.5 EMW 7" casin Float a ui ment to surface 30 min recorded 3,500 si surface 7" Tie-Back After drillin tie-back cement 30 min recorded 3,500 si surface 7" casin shoe 20' new formation be and FIT 10.0 EMW 4'/z" roduction liner Float a ui ment to surface 30 min recorded 3,500 si surface Well Control Well control equipment consisting of 5,OOOpsi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8 1/2" intermediate interval Maximum antici ated BHP: 3,100psi at 8,590' TVDss. Maximum surface ressure: 2 p I (based upon BHP and a full column of gas from TD C~3 0.10 psi/ft) Calculated kick tolerance: fin' with 12.5 EMW FIT Planned BOPE test ressure: si low / 3,500 si hi h - 7 da test c cle Pre drillin hase BOPE configuration for 7" Variable Bore Rams will remain installed, rather than C/O to 7" pipe rams drilling liner. while running 3,480' of 7" liner. In the event of a kick the rig will follow the current, best practice, making up a safety valve crossed over to casing thread, then changing elevators and picking up a joint of drill pipe. This confi uration rovides two sets of em to able rams, rather than one. Well Interval: 6 1/8" roduction interval Maximum antici ated BHP: 3,250 si at 8,850' TVDss. Maximum surface ressure: 2, SI (based upon BHP and a full column of gas from TD C~ 0.10 psi/ft) Calculated kick tolerance: I fini with 10.0 pp EMW FIT. Planned BOPE test ressure: 56 si low / 3,500 si hi h -14 da test c cle Drillin o erations Planned com letion fluid: 8.4 p seawater / 6.8 Diesel 14-11 A Sidetrack Page 3 • • Disposal Annular In'ection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 for injection. All Class I wastes are to be hauled to Pad 3 for dis osal. Geologic Prognosis Formation MD TVDbkb TVDss Comments CM2 6821 6750 Above window C~3 6835' TVD bkb CM1 8058 7518 7447 THRZ 8746 7951 7880 BHRZ 9040 8114 8043 TJC 9773 8520 8449 TJB 10096 8700 8629 TJA 10275 8799 8728 Sa River 10431 8886 8815 Possible Hydrocarbons Shublik 10472 8908 8837 TSAD / TZ46P 10635 8984 8913 Possible Hydrocarbons pp 3250 psi 45N 10783 9023 8952 Possible Hydrocarbons 45P 10795 9024 8953 Possible Hydrocarbons HOT 10944 9029 8958 OWC 9096 9025 Below TD TD Criteria: I TD as per directional plan to avoid penetrating the Shublik and resulting lost circulation risks Operations Summar Current Condition; / LTSI since 8/98. / Freeze protected FL w/ 5 bb/s methanol & 37 bbls crude. / 8/96 TIFL passes /Post TIFL monitoring indicates very slow gas leak. / The minimum lD is 2.99" in the 4-1/2"AVA patch at 8,825'. / OA tracking IA with approximately a 100 psi per day rise / Downhole leak, IA X OA Scope * Notify the field AOGCC representative with intent to plug and abandon Pre-Rig Operations: 1. Replace all live Gas Lift valves with Dummy valves and fluid pack as necessary for CT P&A. 2. R/U SL and drift tbg, tag up on cement plug @ 9,771' MD 3. RIH with CT and P&A the 14-11 well bore. Pump sufficient cement to leave top up into the tubing tail at 8600' MD. Ir.~ ~~~ 14-11 A Sidetrack Page 4 • • 4. Drift the 5'/z" tubing to 7,700' MD to confirm clear to the required cut depth of 7,500' MD. 5. RIH with the appropriate jet cutter and cut the 5'/z" tubing at 7,500' MD. 6. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to 2,200' MD with diesel. 7. Test the 9 5/8" pack-off and tubing hanger seals to 5,OOOpsi for 30 minutes. Function all Lock Down Screws, repair or replace as needed. 8. Bleed casing and annulus pressures to zero. 9. Set a BPV. Secure the well. Level the pad as necessary. Rig Operations: 1. M! / RU Nabors rig 2ES 2. Circulate out diesel freeze protection and displace the well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. 4. R/U. Pull 5'/z" tubing from the cut at 7,500' MD and above. 5. R/U E-line. M/U 8.5" gauge ring /junk basket / CCL. RIH and tag tubing stump. POOH. 6. RIH with HES EZSV on E-line. Set bridge plug at 7,124', as required to avoid cutting a casing collar while milling the window. POOH. R/D E-line. 7. Pressure-test the 9-5/8" casing to 3,500psi for 30 minutes. Record test. 8~' J and RIH with 9-5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. 9. Displace the well to 9.0 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. ~, 1~ - ~~110. Mill window in 9-5/8" casing at ± 7,100' MD, plus approximately 20' beyond middle of window. w Circulate well bore clean. ~~p~U (' 11. Pull up into 9 5/8" casing and conduct an FIT to 12.5 ppg EMW. POOH. ~ 12. M/U 8'/z" Dir/GR/PWD assembly. RIH, kick off and drill the 8'/z" intermediate section to 100' above the HRZ with 9.0 - 9.3 ppg LSND. 13. At -8,600' MD (100' above the top of the HRZ) weight up to 11.0 ppg with spike fluid from the MI / plant. 14. Continue drilling ahead in the 8'/z" hole section to the top of the Sag River, per directional proposal. Circulate well clean, short trip to window. POH laying down excess 5" DP. 15. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. Test to 3500 psi. ~ 16. Run 7" liner tieback from TOL to surface. Cement from tieback sleeve to ±3,150' MD. ~ 17. Break BOP stack, set casing on slips inside existing tubing spool, rough cut casing, set back BOPs. 18. Dress casing stub and install packoff and tubing spool. 19. NU and test BOPs / 20. M/U 6-1/8" Dir/GR/Res assembly. RIH to the tie-back landing collar. 21. Drill out the 7" tieback and RIH. „ /. 22. Test the 7 tie-back and liner to 3 500 si for 30 minutes. Record the test. P 23. Drill out the 7" liner float equipment and cement to the shoe. 24. Displace the well to 8.4 ppg Fio-Pro drilling fluid. „ , 25. Drill out the 7 shoe plus ~20 new formation, pull up into the shoe and conduct an FIT to 10.Oppg ~ EMW. Drill ahead to TD per directional proposal. 26. Circulate well bore clean, short trip to shoe, circulate. POOH. 27. Run 4'/z", 12.6#, L-80, IBT slotted production liner. POOH. 28. R/U and run a 4'/i", 12.6#, Cr13 VamTop tubing completion, stinging into the 4'/z" liner tie back sleeve. 29. Set packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 30. Set a BPV. 31. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. / 32. Freeze protect the well to 2,200' TVD. Secure the well. 33. Rig down and move off. Post-Rig Operations: MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 14-11 A Sidetrack Page 5 2. Install well house and instrumentation. Phase 1: Move In / Rig Up /Test BOPE Planned Phase Time Planned Phase Cost 54 hours $321,000 Reference RP • "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards - No wells will require shut-in for the rig move onto 14-11. However, 14-18 is 35' to the North. This is the closest neighboring well. Care should be taken while moving onto the well. Spotters should be employed at all times. - During MI/RU operations, the 14-11 well bore will be secured with the following barriers: o Tubing: the cement P&A plug, kill weight fluid, and a BPV. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. - Prior to pulling the tree, verify there is a static column of brine to surface and that no pressure exists. - During ND/NU BOPE operations, the 14-11 well bore will be secured with the following barriers: • Tubing: the cement P&A plug, kill weight fluid, and a TWC/blanking plug. • IA: Annulus valves and kill weight fluid. • OA: Annulus valve and kill weight fluid. - DS-14 is esignated as an H2S site. Standard Operating Procedures for H2S precautions ~- should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading 14-10 30 ppm % 14-06A 50 ~' 14-19 10ppm 14-10 30 The maximum level recorded of H2S on the pad was 200ppm in well 14-07 on 08/22/2004. - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Phase 2: De-complete Well Planned Phase Time Planned Phase Cost 36.0 hours $114,000 Reference RP • "De-completions" RP 14-11 A Sidetrack Page 6 • • Issues and Potential Hazards - Monitor the well to ensure the fluid column remains static, prior to pulling the completion. - Have all wellhead and completion equipment NORM-tested, following retrieval. - This wellhead is a Gray Gen 2. Check with Cameron to ensure all replacement parts and required equipment is available. - Once the stack has been nippled down, verify the hanger thread and type in preparation for de- completion. Be prepared with the appropriate tubing spear, in the event it becomes necessary. - There is a 5-1/2" Camco BAL-O SSSV at 2190' with a'/a" control line. ~28 Hydril control line clamps, 1 on every other tbg joint, were run initially. - Run GR/CCL Log from the bridge plug setting depth to surface after setting the EZSV. Phase 3: Run Whip Stock _ Planned Phase Time Planned Phase Cost 30.0 hours $217,000 Reference RP • "Whip stock Sidetracks" RP Issues and Potential Hazards - The 9 5/8" casing was cemented with 97 bbls (500 sxs) Class G cement. Cement top is calculated at 7663' and not expected behind the 9-5/8" csg at the KOP. - Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled Phase 5: Drill 81/2" Intermediate Hole Interval Planned Phase Time Planned Phase Cost 102.0 hours $563,000 Reference RP • "Shale Drilling, Kingak and HRZ" RP • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards - Must tie MWD - GR back to GR-CCL run during the de-completion phase. No other shallow logs exist for this well. - For this well, the HRZ and Kingak will require a mud weight of 11.Oppg. Maintain mud weight at 11.Oppg, minimally, from above the HRZ to the 7" casing point. Follow all shale drilling practices to minimize potential problems. - KICK TOLERANCE: In the worst-case scenario of 7.1 ppg pore pressure at the Sag River depth, a fracture gradien~p#'T'Z~5 ppg at the 9 5/8" casing window, and 11.0 ppg mud in the hole, the kick tolerance is nfinif~. - The above kick tolee nce is based on an FIT of 12.5 ppg EMW, if this is not reached contact the ODE 14-11 A Sidetrack Page 7 L_~ • Phase 6: Run and Cement 7" Intermediate Casing and 7" Tie-Back Planned Phase Time Planned Phase Cost 58.8 hours $642,000 Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Freeze Protecting an Outer Annulus" RP • "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards - Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab /surge pressures could initiate HRZ /Kingak instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Proper casing centralization will facilitate minimizing the potential for differential sticking. Phase 7: Drill 6 1/8" Production Hole Interval Planned Phase Time Planned Phase Cost 120.0 hours $595,000 Reference RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards - The geologic polygon is bounded by faults and existing wellbores; it is designed to maintain a 200' minimum offset from all faults. ALL POLYGON LINES ARE HARDLINES. - 14-11A is expected to cross two faults. The first at 9024' MD (8105' TVD) has an estimated throw of <10', losses are not expected. The second fault at 10042' MD (8670' TVD) has an estimated throw of 110-140' and presents a higher risk of lost circulation. Phase 9: Run 4~/s" Production Liner Planned Phase Time Planned Phase Cost 18.0 hours $181,000 Issues and Potential Hazards - The completion design is to run a 4 'h", 12.6#, L-80 slotted liner throughout the production interval. - Differential sticking is possible. The 8.4ppg Flo-Pro will be 600 psi over balanced to the Ivishak Zone 4 formation. Minimize the time the pipe is left stationary while running the liner. - Sufficient 4'/z" liner will be run to extend 150' back up into the 7" liner shoe. - Ensure the 4 ~/z" liner top packer is set prior to POH. 14-11 A Sidetrack Page 8 • • Phase 12: Run 4 ~/2" L-80 Completion Planned Phase Time Planned Phase Cost 24 hours $440,000 Reference RP • "Completion Design and Running" RP • "Tubing connections" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. - The completion, as designed, will be to run a 4Y2", 12.6#, 13-Cr, VamTop production tubing string, stinging into the 4'h" liner tieback sleeve. Phase 13: ND/NU/Release Rig Planned Phase Time Planned Phase Cost 14.4hours $43,000 Reference RP • "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - No wells will require shut-in for the rig move off of 14-11A. However, 14-18 is 35' to the North. This is the closest neighboring well. Care should be taken while moving off from the well. Spotters should be employed at all times. 14-11 A Sidetrack Page 9 TREE = GRAY GEN 2 WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 71' BF. ELEV = KOP = 5200' Max Angle = 37 @ 9900' Datum MD = 9526' Datum TV D = 8800' SS ~ 14-11 Current 13-3/8" CSG, 72#, L-80, ID = 12.347" 2651' Minimum ID = 2.990" @ 8825' 4-1 /2" AVA PATC H 9-5/8" CSG, 47#, L-80, ID = 8.681" 8313' TOP OF 9-5/8" CSG 8313' SAFETY NOTES: 90~~ 5-1/2" CAM BAL-O SSSV NIP, ID = 4.56" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2898 2898 1 CA/ RK 2 4819 4819 0 CA/ 3 6219 6110 33 CA/ RK 4 6292 6171 33 CA/ RK 5 7300 7001 34 CA/ RK 6 7374 7063 31 CA/ RK 7 7994 7593 31 CA/ RK 8 8068 7656 31 CA/ RK 9 8454 7986 32 CA/ RK 10 8528 8049 33 CA/ RK 11 8761 8243 34 CA/ RK 12 8837 8307 34 CA/ RK 8825' -j 4-1/2" AVA TBG PATCH (30.17') 5-1/2" TBG-PC, 17#, L-80, 0.0232 bpf, ID = 4.892" ~-1 8928• TOP OF 4-1 /2" TBG-NPC 8928' TOP OF 7" LNR -8970' ~4-1/2" TBG-NPC, 12.6#, N-80, 0.0152 bpf, ID = 3.958" ~-~ 9016' 9-5/8" CSG, 47#, SOO-95, ID = 8.681" 9298' PERFORATION SUMMARY REF LOG: BRCS ON 07/25/81 ANGLE AT TOP PERF: 36 @ 9556' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-5/8" 4 9556 - 9569 O 11/25/91 2-5/8" 4 9592 - 9616 O 06/07/92 3-3/8" 4 9672 - 9724 O 09/04/85 3-1/8" 4 9950 - 9990 C 08/14/88 3-1/8" 4 9996 - 10106 C 08/14/88 3-1/8" 4 10118 - 10128 C 08/14/88 3-1/8" 4 10155 - 10175 C 08/14/88 8902' 5-1/2" BAKER PBR ASSY 8916' 9-5/8" X 5-1/2" BAKER SAB PKR 8928' 5-1 /2" X 4-1 /2" XO 9~ U13' ~-j 4-112" CAMCO DB-6 LAND NIP, ID = 3.81" 9016' 4-1 /2" TUBING TAIL 9020' ELMD TT LOGGED 03/30/86 9750' ~-~ 7" X 4-1/2" BKR FB-1 PKR 9771' ~CMT PLUG 9803' 4-1/2" CAM DB-6 NIP, ID = 3.813" W/ EQUALIZING PLUG 98~ ELMD TT LOGGED 08/04/81 PeTD 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" rTD 4' 10445' 10468' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/04/81 ORIGINAL COMPLETION 01/07/02 RN/TP CORRECTIONS 08/27/03 BHGKK CORRECTIONS PRUDHOE BAY UNfT WELL: 14-11 PERMfr No: 1801310 API No: 50-029-20529-00 SEC 9, T10N, R14E, 1282.11' FEL & 4513.86' FNL BP 6cploration (Alaska) TREE = GRAY GEN 2 WELLHEAD= GRAY ACTUATOR = AXELSON KB. ELEV = 71' BF. ELEV = KOP = 5200' Max Angle = 37 @ 9900' Datum MD = 9526' Datum TV D = 8800' SS • 14-11A Proposed Completion SAFETY NOTES: 2200' 4-1/2" X Nipple (3.813" ID) GAS LIFT MANDRELS DATE 13-3/8" CSG, 72#, L-80, ID = 12.347" 2651' Top of Tie-Back Cement 3150' 7" 26#, Tie Back, TGII threads to 3650', BTGM thread 3650' to 6950' 6950' Minimum ID = 2.990" @ 8825' 4-1 /2" AVA PATC H Top of 9-5/8" Window 7100' 5-1/2" TBG, 17#, L-80 Cut @ 7500' Top of Cement 8600' 4-1/2" AVA TBG Patch 30.17' (2.990 ID) 8825' 4-112" TBG-NPC, 12.6#, N-80, 0.0152 bpf, ID = 3.958" 9016' 9-5/8" CSG, 47#, SOO-95, ID = 8.681" 9298' TOP OF 7" LNR 8970' PERFORATION SUMMARY REF LOG: BHCS ON 07/25/81 ANGLE AT TOP PERF: 36 @ 9556' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-5/8" 4 9556 - 9569 O 11/25/91 2-5/8" 4 9592 - 9616 O 06/07/92 3-3/8" 4 9672 - 9724 O 09/04/85 3-1/8" 4 9950 - 9990 C 08/14/88 3-118" 4 9996 - 10106 C 08/14/88 3-1/8" 4 10118 - 10128 C 08/14/88 3-1/8" 4 10155 - 10175 C 08/14/88 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 10445' 2 3 4 5 6 6950' Top of the 7" 26#, L-80, BTGM liner 10108' 4 1/2" X Nipple (3.813" ID) 10128' 7" x 4 1/2" Baker S3 Packer 10148' 4 1/2" X Nipple (3.813" ID) 10168' 4 1/2" XN Nipple (3.725" ID) 10181' 4 1/2" Hanger /liner top packer 10181' 4 1/2" WLEG 1 10331' 7" 26# L-80, BTGM (6.276" ID) 4-1/2" 12.6#, L-80, IBT Slotted Liner 12039' 8902' 5-1/2"BAKERPBRASSY 8916' 9-5/8" X 5-1/2" BAKER SAB PKR 8928' 5-1/2" X 4-1/2" XO 9013' 4-1/2" CAMCO DB-6 LAND NIP, ID = 3.81" 9016' 4-112" TUBING TAIL 9020' ELMD TT LOGGED 03/30/86 9750' 7" X 4-1/2" BKR FB-1 PKR 9771' cMT PLUG 9803' 4-1/2" CAM DB-6 NIP, ID = 3.813" W/ EQUALIZING PLUG 8 8806' ELMD TT LOGGED 08/04/81 PBTD 10414' TD 10468' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/04/81 ORIGINAL COMPLETION 01/07/02 RN/TP CORRECTIONS 08/27/03 BHC/KK CORRECTIONS 08/08/05 JNC Proposed ST Completion PRUDHOE BAY UNIT WELL: 14-11 A PERMff No: 1801310 API No: 50-029-20529-01 SEC 9, T10N, R14E, 1282.11' FEL 8~ 4513.86' FNL BP Exploration (Alaska) ('()MI'ANV nl!IAII .~ L. UP III A nu (vcuuti Me l: h1 nnwnlwawn I!mrlyur_ I1('W~4 b M h l I ' ' rlin~lcr N~rNi ran e( ~u : rer ( I~:mrt ~urfa.:r: I:Ilipwvl - ('a.ing KI~:I~I~:KI~:N('1~: INr()KMnll(>N 1UKVI~.Y I'KIxIKAh1 Pl:m: 11-1IA tipU! (I9-I I1'I;m 11-I IAI ('.~. I IN I~:I K I W Il l 19 11 T e Ni~N; Ikpa; I m Ikplh l S - ~71.m I ~~~~I l rc9LL•J ni- 11i~ei(ul N v CLen( llur Halo: H/ 17/2(H15 IM1 lltl ; N.)UI~1 71 NI IXI 1211iv I'LuuxJ.I+IIA UPU(~Vic AI\Vllll~lthl~ M,. .n ullkpll; Ii.I.n u.~ J ~ M. (I)~~i'k~J' __. Halo: (':J.ululii~n M.ilxxl: Minunuin t'un;niv. It.•vi.•x'ia' I)a0.•: W'anuuN Meaxnl: Kule> Iiasvl ~ -- 0 0 a 0 F CASING DETAILS No. TVD MD Name I 8830.50 10331.48 7" 2 8900.58 12039.00 4 I!2" Nain. N-~ ~1~.-N' N~vrhme I~vainE Imnu4 luugiruk 1Ln SIZe lull ~IVi', ni -.. :vi%«<yl !~'J^n.)N 'u"I J'I<~.IJIN 11%"3t•.U.6G~W N.A 7.000 TARGET DETAILS 4.500 Name TVD +N.-S +E/-N' Northing Easting Shape 14-I IA TI 884150 -3123.31 -469,27 5')35420.00 674340.10 Point ' 14-IIAT3 8900.50 -2877.38 -1948.02 593563L35 672846.15 Point 14-I IA T2 9030.00 -3240.00 -1050.00 5935289.66 673752.27 Point SECTION DETAILS Sec MD Inc Azi TVD +N.-S +E/-W DLag TFace VSec Target I I 7100.00 34.75 163.02 6835.59 -898.09 359.96 0.00 0.00 137.31 ' ~ 2 7120.00 37.15 163.02 6851.78 -909.31 363.39 12.00 0.00 139.95 ' I 3 7420.00 46.15 163A2 7075.72 -1099.79 421.55 3.00 0.00 184.82 ' ~ 4 7690.00 46.15 163.02 7262.78 -1286.01 478.41 0.00 0.00 228.69 ~ ~, 5 87229> 56.29 215.74 7941.68 -2028.61 328.60 4.00 94.42 729.73 6 10351.30 56 29 215.74 8841.50 -3123.31 -459.27 0.00 0.00 1959.40 14-I IA TI ~~ 7 10441.30 56.29 215.74 8891.45 -3184.08 -503.00 0.00 0.00 2027.65 8 10865.99 89.71 284.38 9029.07 -3288.95 -860.47 `f7.00 78.00 2389.66 I 9 11038.30 89.71 284.38 9029.94 -3246.14 -102738 0.00 0.00 2512.81 . 10 IIOG1.74 90.00 286.00 9030.00 -3240.00 -1050.00 7.00 79.88 2529.33 14-IIAT2 II 11211.43 98.24 292.49 901924 -3190.90 -1190.78 7.00 37.96 2626.69 I ~ 12 12039.57 98.24 292.49 890050 -2877.38 -1948.02 O.W 0.00 3125,72 14-IIAT3 FORMATION TOP DETAILS No. I-VllPath MDPath Formation 7525.50 8069.64 CMI 2 7975.50 8790.89 THRZ 3 8160.50 9124.23 BHRIJLCU/JD 4 8510.50 9754.89 TJC 5 8660.50 10025.16 TJB 6 8790.50 10259.41 TJA 7 8830.50 10331.48 TSGR 8 8847.50 10362.11 TSHU 9 8920.50 10495.22 TSAD/46P 10 8964.50 10587.11 45N II 8966.50 10591.78 45P 12 9010.50 10720.93 44N 13 9013.50 10733.58 44P 2000 2501 Vertical Saction at 240.00° [SOOft/in] 4500 rr~~ ~Y (c>MI'ANY I)t'IAII ~ IiP M)~w.' RI'FLnI N( 1. INI{)I(MAI Ir)N ~nl IN I~.IRI WII( IJ II Ink Nl~Nl <Nw lalum Mcdxl hi wn(unalw.: ' \'•n 111\I) kl .1 % ]. ~. 1\' HI I II xNl~Ixq~.l I .m~r ~~~~le - 1 eW~A \I.as n+11J.pIh K.l:nrw.- J. _T.~ 7u.41 4an Afell)..1: Im~(ylildlr N~~nh t:~leul aw~n Al.Nnei. Alinnmm~ l'unmim• emir s~rra«: hwrr,~l ~ ra>~~~~; Wammx Mabxl: RWvs I krxyl SECTION DETAILS Sec MD Inc Azi TVD +N/-S +Ei-W DLeg TFace VSec Target 1 7100.00 34.75 163.02 6835.59 -898A9 359.96 0.00 0.00 137.31 2 7120.00 37.15 163.02 6851.78 -90931 363.39 12.00 0.00 139.95 3 7420.00 46.15 163.02 7075.72 _1099.7) 421.15 3.00 0.00 184.82 4 76)0.00 46.15 163.02 7262.78 -1286.01 478.41 0.00 0.00 228.69 j 8729.95 5619 211,74 7941.68 -2028.61 128.60 4.00 94.42 729.73 6 10351.30 56.29 215.74 8841.50 -3123.31 -459.27 0.00 0.00 1959.40 14-IIA TI 7 1044130 5619 215.74 8891.45 -3184.08 -503.00 0.00 Q00 2027.65 8 10865.99 89.71 284.38 9029.07 -3288.95 -860.47 17.00 78.00 2389.66 9 11038.30 89.71 284.38 9029.94 -3246.14 -1027.38 0.00 0.00 2512.81 10 11061.74 90.00 286.00 9030.00 -3240.00 -IU50.W 7.00 79.88 2529.33 I4-IIA T2 II 11211.43 9814 292.49 9019.24 -3I9Q90 -1190.78 7.00 37.96 2626.69 12 12039.57 9814 292.49 8900.50 -2877.38 -1948.02 0.00 O.UO 3125.72 14-IIA T3 c C 0 0 L 1= 0 s 0 .r,n~,., rrcr~,„,.m rla,i IJ nnwpaeua IvNI~, 14 unl Ikplh Im n.p h I 1 .~I'lan I~u~l ~ ('reue~ Hy Ih~ iI;J nuunexa(I cnl I l U;r4•' T. 17: 211Ui 711x)Ixl I_li... Ilmur.~~l: I~IlA oplx~\3~ MWI)~II~It-AI1 ('heck) Uule. W7~.1.1. IJtl All Name - N-T ~I~.-W NuN~hig I~a.lnlx I.mnuL I.mxnule xLn 10.11 -Illlt.li «2.57 ~)ix_+s. yl l~].1]?[.,%.1 7u'1~'I~~.IJIN lax"i~?u.(b~W' NA TA RGET DE"PAILS N;une TVD +N/-S +E/-W Northing Easting Shape 14-IIA Fault2 8175.50 -1855,74 -292.94 5936691.00 674477.00 Polygon 14-IIAFaultl 8740.50 -2793.29 -541.75 5935748.00 674250.00 Polygon 14-IIA TI 8841.1p _3123.31 -459.27 59;5420.00 674340.10 Point 14-IIA T3 8900.50 -2877.38 -1')48.02 5935631.35 672846.15 Point 14-IIA Poly 8970.50 -3145.01 -472.58 5935398.00 674327.30 Polygon 14-IIA T2 9030.00 -3240.00 -10>0.00 5935289.66 673752.27 Point I 3 -- -- -~--~ - ~'~-- - -'--. --~ -- - - 3 3' MD. 9029.941 - _. - _ _. - -- --- -- - ---!~ - - - -. - Fart I?ir 11100' : I I0 --~_ - -- - -- - I - _ ~- II IA wp06 i '; ! 1 14 ~ FORMATION TOP DETAILS I -- I ~I F -- 9 0, '~ I No. TVDPath MDPath Formation -- I ~ ._. ! - I Plpn l4-I I A ~~ I _. -.._ -- I ~ - ~ I 1 ]525.50 8069.64 C'MI -- - i - - - I 1 A Tk -j - - - I- - -- -. 2 7975.50 8790.89 THRZ 3 8160.50 9124.23 BHRZ/LCU/JD i I .. i ~ ~ ', - I ~'. '. 4 8510. i0 9754.89 TJC - -._ -. _._ 1 2"~ ~I ., ~ _ _.. I _--i-. a ~ i 5 8660.50 10025.16 TJB 6 8790.50 10219.41 TJA _ - -' i _ _ ___ _ ! _- -- ~ ~ ~ ~ ~ ~ j - 7 8830.50 10331.48 TSGR 8 8 I Stan r1 /ioo':1oa41 -- . --. ..- _ -_-_ _ _ i _ _ - ~ I ~ - - 91.45'TVD ~. 847.50 10362.1 I TSHU __ ~ I .3' MD, 88 q 92 10 10491 22 -. _ -- Di, _.. ._ T Di46P - - - - _ - I ~.,, I 0 8 0 SA i ~ ~ I ~ I 96 .50 10587.11 45N - - ~ - -- - ~ ~ ; 9, 0. ,I I _- _ _ -~- ~ - 12 90610 50 10720.93 44N - ~ ~ : 1 -I!,I~ Tg ~ i I II ~ ~ I -.. 13 9013 50 107'33.58 44P End Dlr' : 0865.99' MD, 9p29.dT T D CASING DETAILS No. TVD MD Name Size -2500 -2000 -1500 -1000 -500 0 500 I 8830.50 10331.48 7" 7.000 West(-)/Easry+)[500ft/in] 2 8900.58 12039.00 41/2" 4.500 ~ i Sperry-Sun BP Planning Report Company: BP Amoco Date: 8/17/2005 Time: 14:53:48. Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 14-11, True North Site: PB DS 14 Vertical (TVD) Reference: ' 42+28:5 70.5 Well:. 14-11 Section (VS) Reference: WeIT`(O.OON,O:OOE,240.OOAzij Wellpath: Plan 14-11A Survey Calculation Methods Minimum Curvature Db: Oracle. Plan: 14-11A wp06 Date Composed: 6/9/2005 Version: 35 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB DS 14 TR-10-14 UNITED STATES :North Slope Site Position: Northing: 5939577.43 ft Latitude: 70 14 26.346 N From: Map Easting: 674150.48 ft Longitude: 148 35 36.726 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.32 deg Well: 14-11 Slot Name: 14-11 Well Position: +N/-S -1037.63 ft Northing: 5938552.91 ft Latitude: 70 14 16.141 N +E/-W 552.57 ft Easting : 674726.84 ft Longitude: 148 35 20.665 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name fti ft in in 10331.48 8830.50 7.000 8.500 7" 12039.00 8900.58 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle 'Dip Direcfion ft ft deg deg 0.00 CM3 0.00 0.00 0.00 CM2 0.00 0.00 8069.64 7525.50 CM1 0.00 0.00 8790.89 7975.50 THRZ 0.00 0.00 9124.23 8160.50 BHRZ/LCU/JD 0.00 0.00 9754.89 8510.50 TJC 0.00 0.00 10025.16 8660.50 TJB 0.00 0.00 10259.41 8790.50 TJA 0.00 0.00 10331.48 8830.50 TSGR 0.00 0.00 10362.11 8847.50 TSHU 0.00 0.00 10495.22 8920.50 TSAD/46P 0.00 0.00 10587.11 8964.50 45N 0.00 0.00 10591.78 8966.50 45P 0.00 0.00 10720.93 9010.50 44N 0.00 0.00 10733.58 9013.50 44P 0.00 0.00 0.00 43N 0.00 0.00 0.00 43P 0.00 0.00 0.00 HOT 0.00 0.00 Targets Map Map <--- Latitude --> <-- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting -Deg Mi m'Sec Deg Min Sec Dip... Dir. ft ft ft ft ft 14-11A Fault 2 8175. 50 -1855. 74 -292.94 5936691.00 674477.00 70 13 57.889 N 148 35 29.178 W -Polygon 1 8175. 50 -1855. 74 -292.94 5936691.00 674477.00 70 13 57.889 N 148 35 29.178 W -Polygon 2 8175. 50 -2743. 24 -25.42 5935810.00 674765.00 70 13 49.161 N 148 35 21.404 W 14-11A Fault 1 8740. 50 -2793. 29 -541.75 5935748.00 674250.00 70 13 48.668 N 148 35 36.405 W -Polygon 1 8740. 50 -2793. 29 -541.75 5935748.00 674250.00 70 13 48.668 N 148 35 36.405 W -Polygon 2 8740. 50 -2960. 81 -133.50 5935590.00 674662.00 70 13 47.021 N 148 35 24.544 W ~ i Sperry-Sun BP Planning Report Company: BP Amoco Date: 8/17/2005 Time: 14:53:48 Page; 2 Field: Prudhoe Bay` Co-ordinate(NE) Reference: Well: 14-11, True North Site: PB DS 14 Vertical (TVD) Reference:' 42+28.5 70.5. Well: 14-11 Section (VS) Reference: Well.{O.OON,O:QOE,240.OOAzi) Wellpath: Plan 14-11A Survey Calculation Method: Minimum Curvature Dh:' Oracle. Targets Map Map w_ Latitude --> ~--- Longitude --> Name Description TVD +N/-S +E/-W Northing Eastin g Deg Min -Sec Deg .Min Sec Di p. Dir. ft ff ft ft ft 14-11A T1 8841.50 -3123.31 -459.27 5935420.00 674340. 10 70 13 45.423 N 148 35 34.008 W 14-11A T3 8900.50 -2877.38 -1948.02 5935631.35 672846. 15 70 13 47.839 N 148 36 17.263 W 14-11A Poly 8970.50 -3145.01 -472.58 5935398.00 674327 .30 70 13 45.209 N 148 35 34.395 W -Polygon 1 8970.50 -3145.01 -472.58 5935398.00 674327 .30 70 13 45.209 N 148 35 34.395 W -Polygon 2 8970.50 -3360.55 -409.35 5935184.00 674395 .50 70 13 43.089 N 148 35 32.558 W -Polygon 3 8970.50 -3357.51 -928.85 5935175.00 673876 .10 70 13 43.119 N 148 35 47.650 W -Polygon 4 8970.50 -2952.89 -1985.53 5935555.00 672810 .40 70 13 47.096 N 148 36 18.352 W -Polygon 5 8970.50 -2802.45 -1937.53 5935706.50. 672854 .90 70 13 48.576 N 148 36 16.959 W -Polygon 6 8970.50 -3118.89 -973.84 5935412.50 673825. 60 70 13 45.466 N 148 35 48.958 W -Polygon 7 8970.50 -3145.01 -472.58 5935398.00 674327. 30 70 13 45.209 N 148 35 34.395 W 14-11A T2 9030.00 -3240.00 -1050.00 5935289.66 673752. 27 70 13 44.274 N 148 35 51.170 W Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 7100.00 34.75 163.02 6835.59 -898.09 359.96 0.00 0.00 0.00 0.00 7120.00 37.15 163.02 6851.78 -909.31 363.39 12.00 12.00 0.00 0.00 7420.00 46.15 163.02 7075.72 -1099.79 421.55 3.00 3.00 0.00 0.00 7690.00 46.15 163.02 7262.78 -1286.01 478.41 0.00 0.00 0.00 0.00 8729.95 56.29 215.74 7941.68 -2028.61 328.60 4.00 0.98 5.07 94.42 10351.30 56.29 215.74 8841.50 -3123.31 -459.27 0.00 0.00 0.00 0.00 14-11A T1 10441.30 56.29 215.74 8891.45 -3184.08 -503.00 0.00 0.00 0.00 0.00 10865.99 89.71 284.38 9029.07 -3288.95 -860.47 17.00 7.87 1 6.16 78.00 11038.30 89.71 284.38 9029.94 -3246.14 - 1027.38 0.00 0.00 0.00 0.00 11061.74 90.00 286.00 9030.00 -3240.00 - 1050.00 7.00 1.23 6.89 79.88 14-11A T2 11211.43 98.24 292.49 9019.24 -3190.90 - 1190.78 7.00 5.51 4.34 37.96 12039.57 98.24 292.49 8900.50 -2877.38 - 1948.02 0.00 0.00 0.00 0.00 14-11A T3 Survey MD Incl Azim TVI) Sys TVD N/S E/W DLS MapN MapE Tool/Comme t ft deg deg ft ft ft ft deg/100ft ft ft 7100.00 34.75 163.02 6835.59 6765.09 -898.09 359.96 0.00 5937663.47 675107.49 Start Dir 12/10 7120.00 37.15 163.02 6851.78 6781.28 -909.31 363.39 12.00 5937652.32 675111.18 Start Dir 3/100 7200.00 39.55 163.02 6914.51 6844.01 -956.78 377.89 3.00 5937605.21 675126.77 MWD+IFR+MS 7300.00 42.55 163.02 6989.92 6919.42 -1019.58 397.06 3.00 5937542.87 675147.39 MWD+IFR+MS 7400.00 45.55 163.02 7061.79 6991.29 -1086.07 417.36 3.00 5937476.88 675169.23 MWD+IFR+MS 7420.00 46.15 163.02 7075.72 7005.22 -1099.79 421.55 3.00 5937463.26 675173.74 End Dir :7420 7500.00 46.15 163.02 7131.14 7060.64 -1154.97 438.40 0.00 5937408.49 675191.86 MWD+IFR+MS 7600.00 46.15 163.02 7200.42 7129.92 -1223.93 459.46 0.00 5937340.03 675214.51 MWD+IFR+MS 7690.00 46.15 163.02 7262.78 7192.28 -1286.01 478.41 0.00 5937278.42 675234.89 Start Dir 4/100 7700.00 46.12 163.57 7269.71 7199.21 -1292.91 480.48 4.00 5937271.56 675237.12 MWD+IFR+MS 7800.00 45.97 169.13 7339.14 7268.64 -1362.81 497.46 4.00 5937202.08 675255.72 MWD+IFR+MS 7900.00 46.09 174.68 7408.60 7338.10 -1434.01 507.59 4.00 5937131.14 675267.49 MWD+IFR+MS 8000.00 46.48 180.19 7477.73 7407.23 -1506.17. 510.80 4.00 5937059.08 675272.37 MWD+IFR+MS 8069.64 46.91 183.98 7525.50 7455.00 -1556.79 508.96 4.00 5937008.43 675271.70 CM1 8100.00 47.13 185.61 7546.20 7475.70 -1578.93 507.10 4.00 5936986.26 675270.36 MWD+IFR+MS 8200.00 48.03 190.89 7613.68 7543.18 -1651.94 496.49 4.00 5936913.03 675261.45 MWD+IFR+MS 8300.00 49.17 196.00 7679.84 7609.34 -1724.84 479.04 4.00 5936839.75 675245.69 MWD+IFR+MS 8400.00 50.52 200.93 7744.35 7673.85 -1797.27 454.81 4.00 5936766.78 675223.15 MWD+IFR+MS 8500.00 52.07 205.66 7806.90 7736.40 -1868.90 423.94 4.00 5936694.46 675193.95 MWD+IFR+MS 8600.00 53.80 210.17 7867.19 7796.69 -1939.35 386.57 4.00 5936623.16 675158.22 MWD+IFR+MS 8700.00 55.69 214.49 7924.93 7854.43 -2008.31 342.88 4.00 5936553.22 675116.15 MWD+IFR+MS 8729.95 56.29 215.74 7941.68 7871.18 -2028.61 328.60 4.00 5936532.59 675102.34 End Dir :8729 Sperry-Sun BP Planning Report Company: BP AmoCO Date: 8/17!2005 Time: 14;53:48 Pager 3 Field: Prudhoe Bay , Co-ordinate(NE) Reference: WeIL 14-11; True North' Site: PB DS 14 Vertical (TVD) References 42+28:5 70.5 Well: 14-11 Section (VS) Reference: Well (O.OON,O,OOE,240.OOAzi) Wellpath: Plan 14-11A Survey Calculation Method: Minimum Curvature Db: ` Orate Survey MD Inc! Azim TVD Sys TVD ` N/S E/W DLS MapN Map!: TooUComme t ft deg deg ft ft ft ft deg/100ft' ft ft 8790.89 56.29 215.74 7975.50 7905.00 -2069.76 298.99 0.00 5936490.77 675073.69 THRZ 8800.00 56.29 215.74 7980.56 7910.06 -2075.91 294.56 0.00 5936484.52 675069.41 MWD+IFR+MS 8900.00 56.29 215.74 8036.05 7965.55 -2143.43 245.97 0.00 5936415.90 675022.40 MWD+IFR+MS 9000.00 56.29 215.74 8091.55 8021.05 -2210.94 197.38 0.00 5936347.28 674975.38 MWD+IFR+MS 9100.00 56.29 215.74 8147.05 8076.55 -2278.46 148.78 0.00 5936278.66 674928.37 MWD+IFR+MS 9124.23 56.29 215.74 8160.50 8090.00 -2294.82 137.01 0.00 5936262.03 674916.98 BHRZJLCU/JD 9151.26 56.29 215.74 8175.50 8105.00 -2313.07 123.87 0.00 5936243.48 674904.27 14-11AFault2 9200.00 56.29 215.74 8202.55 8132.05 -2345.98 100.19 0.00 5936210.04 674881.36 MWD+-FR+MS 9300.00 56.29 215.74 8258.05 8187.55 -2413.50 51.59 0.00 5936141.41 674834.34 MWD+IFR+MS 9400.00 56.29 215.74 8313.55 8243.05 -2481.01 3.00 0.00 5936072.79 674787.33 MWD+IFR+MS 9500.00 56.29 215.74 8369.04 8298.54 -2548.53 -45.59 0.00 5936004.17 674740.32 MWD+IFR+MS 9600.00 56.29 215.74 8424.54 8354.04 -2616.05 -94.19 0.00 5935935.55 674693.31 MWD+IFR+MS 9700.00 56.29 215.74 8480.04 8409.54 -2683.57 -142.78 0.00 5935866.93 674646.29 MWD+IFR+MS 9754.89 56.29 215.74 8510.50 8440.00 -2720.62 -169.45 0.00 5935829.27 674620.49 TJC 9800.00 56.29 215.74 8535.54 8465.04 -2751.09 -191.37 0.00 5935798.31 674599.28 MWD+IFR+MS 9900.00 56.29 215.74 8591.04 8520.54 -2818.60 -239.97 0.00 5935729.69 674552.27 MWD+IFR+MS 10000.00 56.29 215.74 8646.53 8576.03 -2886.12 -288.56 0.00 5935661.07 674505.25 MWD+IFR+MS 10025.16 56.29 215.74 8660.50 8590.00 -2903.11 -300.79 0.00 5935643.80 674493.42 TJB 10100.00 56.29 215.74 8702.03 8631.53 -2953.64 -337.15 0.00 5935592.45 674458.24 MWD+IFR+MS 10169.31 56.29 215.74 8740.50 8670.00 -3000.44 -370.84 0.00 5935544.88 674425.66 14-11A Fault 1 10200.00 56.29 215.74 8757.53 8687.03 -3021.16 -385.75 0.00 5935523.82 674411.23 MWD+-FR+MS 10259.41 56.29 215.74 8790.50 8720.00 -3061.27 -414.62 0.00 5935483.06 674383.30 TJA 10300.00 56.29 215.74 8813.03 8742.53 -3088.67 -434.34 0.00 5935455.20 674364.22 MWD+IFR+MS 10331.48 56.29 215.74 8830.50 8760.00 -3109.93 -449.64 0.00 5935433.60 674349.42 7" 10351.30 56.29 215.74 8841.50 8771.00 -3123.31 -459.27 0.00 5935420.00 674340.10 14-11AT1 10362.11 56.29 215.74 8847.50 8777.00 -3130.61 -464.52 0.00 5935412.58 674335.01 TSHU 10400.00 56.29 215.74 8868.53 8798.03 -3156.19 -482.93 0.00 5935386.58 674317.20 MWD+-FR+MS 10441.30 56.29 215.74 8891.45 8820.95 -3184.08 -503.00 0.00 5935358.24 674297.79 Start Dir 17/10 10495.22 58.64 226.26 8920.50 8850.00 -3218.27 -532.80 17.00 5935323.37 674268.79 TSAD/46P 10500.00 58.89 227.16 8922.98 8852.48 -3221.07 -535.78 17.00 5935320.50 674265.88 MWD+IFR+MS 10587.11 64.45 242.78 8964.50 8894.00 -3264.65 -598.42 17.00 5935275.49 674204.27 45N 10591.78 64.79 243.57 8966.50 8896.00 -3266.55 -602.18 17.00 5935273.50 674200.56 45P 10600.00 65.41 244.95 8969.96 8899.46 -3269.79 -608.89 17.00 5935270.10 674193.92 MWD+IFR+MS 10601.30 65.51 245.17 8970.50 8900.00 -3270.29 -609.96 17.00 5935269.58 674192.86 14-11A Poly 10700.00 73.78 260.76 9004.99 8934.49 -3296.94 -698.13 17.00 5935240.89 674105.34 MWD+IFR+MS 10720.93 75.69 263.88 9010.50 8940.00 -3299.64 -718.14 17.00 5935237.73 674085.40 44N 10733.58 76.87 265.73 9013.50 8943.00 -3300.75 -730.37 17.00 5935236.34 674073.20 44P 10800.00 83.22 275.21 9025.00 8954.50 -3300.16 -795.68 17.00 5935235.41 674007.90 MWD+IFR+MS 10865.99 89.71 284.38 9029.07 8958.57 -3288.95 -860.47 17.00 5935245.12 673942.87 End Dir :1086 10900.00 89.71 284.38 9029.24 8958.74 -3280.50 -893.42 0.00 5935252.80 673909.74 MWD+IFR+MS 11000.00 89.71 284.38 9029.75 8959.25 -3255.66 -990.28 0.00 5935275.39 673812.33 MWD+IFR+MS 11038.30 89.71 284.38 9029.94 8959.44 -3246.14 -1027.38 0.00 5935284.04 673775.02 Start Dir 7/100 11061.74 90.00 286.00 9030.00 8959.50 -3240.00 -1050.00 7.00 5935289.66 673752.27 14-11AT2 11100.00 92.11 287.65 9029.30 8958.80 -3228.93 -1086.61 7.00 5935299.88 673715.41 MWD+IFR+MS 11200.00 97.62 291.99 9020.82 8950.32 -3195.18 -1180.30 7.00 5935331.44 673620.98 MWD+IFR+MS 11211.43 98.24 292.49 9019.24 8948.74 -3190.90 -1190.78 7.00 5935335.48 673610.40 End Dir :1121 11300.00 98.24 292.49 9006.54 8936.04 -3157.37 -1271.76 0.00 5935367.13 673528.66 MWD+IFR+MS 11400.00 98.24 292.49 8992.20 8921.70 -3119.51 -1363.20 0.00 5935402.85 673436.38 MWD+IFR+MS 11500.00 98.24 292.49 8977.86 8907.36 -3081.65 -1454.64 0.00 5935438.58 673344.09 MWD+IFR+MS 11600.00 98.24 292.49 8963.53 8893.03 -3043.79 -1546.08 0.00 5935474.31 673251.81 MWD+IFR+MS 11700.00 98.24 292.49 8949.19 8878.69 -3005.93 -1637.52 0.00 5935510.03 673159.52 MWD+IFR+MS 11800.00 98.24 292.49 8934.85 8864.35 -2968.08 -1728.96 0.00 5935545.76 673067.23 MWD+IFR+MS 11900.00 98.24 292.49 8920.51 8850.01 -2930.22 -1820.40 0.00 5935581.49 672974.95 MWD+IFR+MS Sperry-Sun BP Planning Report Company; BP AmoCO Date: 8/17/2005 Time: 14:53:48 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 1411, True North `Site: PB DS 14 Vertical (TVD) Reference: 42+28:5 70.5 Well: 14-11 Section (VS) Reference: Well (t).OON,O:OOE,240.OOAzi) Wellpath: Plan 1411A Survey Calculation Method: Minimum Curvature Dbt Oracle - Survey MD - Incl Azim TVD Sys TVD N/S E/W DLS MapN MapE' Tool/Comme t ft deg.. deg ft ft ft ft deg/100ft ft ft 12000.00 98.24 292.49 8906.17 8835.67 -2892.36 -1911.84 0.00 5935617.21 672882.66 MWD+IFR+MS 12039.00 98.24 292.49 8900.58 8830.08 -2877.59 -1947.50 0.00 5935631.15 672846.67 41/2" 12039.57 98.24 292.49 8900.50 8830.00 -2877.38 -1948.02 0.00 5935631.35 672846.15 14-11A T3 TERRLE L RUBBLE 89-6!1252 217 BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612- MB 7-5 ~~_ ~~~~ ANCHORAGE, AK 99519-6612 DATE PAY TO THE ~~ ' ~.t{~ ORDER OF DOLLA First National Bank Alaska Anchorage, ArK j9~9501 MEMO- ~~,~. k,~ ~ ~:i25200060~:g914~~~6227~~~155611' 0217 PATTON BOGGS LLP ST FIFTH AVENUE, SUITE 700 A RAGE, AK 99501 \Y TO' THE Stae Of Alaska -Alaska & Gas Commission iDER' OF Twenty-Seven and 007100***'""'*************** ***~+~+***.~*,.* NORTIiRIM BANK ANCHORAGE, AK 99503 89-93-1252 MO \ ~? ;, 011916.0105 11'00337211' e:1 2 5 2009 34~:Oi07 q3u^ r PELICAN HILL OIL & GAS IIVC. PH.907-277-1.401 / 4Y41 B STREET, SUITE 205 ANCHORAGE, AK 99503 PAY TO THE. ORDER ~`~~ L A S K A '"^~ wic FOR e~=?~~~=~ 11'00 16 5 L11' ~: l 2 5 200060: 3040 2 50 711' 00 33 Y W a c R 0 DOLLARS a v v 1651 Q 89-6/1252 DATE ~ u - ~~ ~\ ~ Z pp DOLLARS LLI ~~ .~ ror • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# D~ ~~.~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-64) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (pI~ records, data and togs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01(05 C\j ody\transm ittal_checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOEOlL-640150 Well Name: PRUDHOE BAY UNIT 14-11A Program Well bore seg ^ PTD#:2051260 Company BP EXPLORATION (ALASKA) INC Initial Class/Type ! 1-OIL GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal ^ Administration 1 Permit fee attached Yes 2 Lease number appropriate Yes - 3 Uni_quewell_nameandnumber__________________________ _________ __Yes____.--__--_---__--_- 4 Well locatedin_ad_efined_pool___ ___ ____________________ _________ _Yes____-.-_----._-_____ ______. ---------------------------------------------- 5 Well located pr_operdistance_f[omdrillingunitboundary------------- -----------Yes______.-_-----_--____ - -- 6 Well locatedp[operdistance-fromotherwells-___--_-_ ________ _-_--.----Yes__________________________________________ --------------------------------- 7 Sufficient acreage available in_dril_ling unit_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ . - - - . _ 8 If deviated,is_wellboreplat_inclu_ded____________-- -----------Yes-------------,-----------------------------.---------------- _-_-. 9 Operator onlyaffectedparty---- --------------- - ----------Yes--------------------..--- 10 OpeCatorhas_appropriate-bondinforCe- --- --- ------ -------- Yes-- - .. -- ------ -- -- .- ----- -- --- -- -- - --- -- - - 11 Permit can be issued without conservation order Yes - - - - - Appr Date 12 Permit_c_an be issued without administrative_appr_ova_I - _ - - - - - - - - -Yes - - - - - - - - _ - - - RPC 8!1812005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and_strata a~rth4rized by_ Injection Order # (put_IO# in_ comments)-(For- NA_ - - _ - - - - -- - 15 All wells within 1f4-mil_e area of review identified (For sere-ice well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ - _ _ _ - - _ 16 Pre-produced injector; duration of pre pr-oduetion less than- 3 months_ (For_seryice well only) N_A_ - - _ - . - - , , _ - - - - , 17 ACMP-Finding of Consistency_hasbeenissued_for_thisproject---------- ----------NA-____________--_-------_--_--__-__--__--__---..-______--_--______----__--- Engineering 18 Conductor string-provided_______________________________ __________NA-___-____ - - 19 Surfacecasingprotectsall-kn4wnU$DWs_____________________ __________IJA______- - - 20 CMT-vot adequate-to circulate_on conductor_& su_rf_csg _ _ _ - - - - - _ - . - - _ _ _ _ _ NA_ _ _ _ _ _ _ _ - - - - - - - - - - - - - 21 CMT_vol_adequate_totie-in long string to surfcsg__________________ __ ------NA-_-___ _______-__--__. 22 CMT_willcoyerallknow_nproductivehorizons-------------------- ----------No_____- -$lottedprodliner,-_______________--_----____________-_---_---__---__---_-- 23 Casing designs adequate for C, T,6&_permafrost_-______________ __________Yes__-__.------__-_________-----__-----_---__________--__------_--__--_------- 24 Adequatetankage_orreserlepit_________________________- -__-------Yes_______Nabors-2ES,-_----.- - - 25 If_a_re-drill,has_a1.0-403 forabandon_mentbeenapproved------------ ----------Yes_---__8116!20.05. _______-----.-__ __-------_________-_--.--- 26 Adequatewellboreseparationproposed._-__________________ __________Yes..___--__--__--__-_,____, ------------------------------------------------- 27 Ifdiverterrequired,doesitmeetregu_lations____________________ __________ NA_______-$idet[ack.----____ Appr Date 28 Drillingfluid_programsehematic-&equiplistadequate---- ---------- ----------Yes______-Max MW-11.0-ppg.________-__---______________-__------_________-. WGA 8!1912005 29 BO_PES, do they meet_regu_lation _ _ - _ Yes _ _ _ 30 BOPE_ptess rating appropriate; test to-(put psig in comments)- - - - - - - - - - - - - - - Yes Test to 3500-psi. -MSP 2365 psi, _ - - - -------------------- 31 Choke-manifold comRlies-wlAPI-RP-53 (M_ay 84) _ _ _ _ Yes - _ _ _ _ _ _ 32 Work willoccurwithoutoperationshutdown_____________________ ________ _Yes______----.----_____________-_____- --------------------------------------- 33 Ispresence_ofH2Sgasprobable.--_________________----- -------_--Yes______50ppm._.---____________-__-___-_-, ---------------------------------- 34 Mechanical condition of wells within AOR verified GFo[service well onlya NA- _ _ - - _ - - - Geology 35 Pe[mit_canbeissuedw/ohydrogen_sulfidemeasu[es_______________ __________ No--_-_-_________--__--_-.------___--___-__--_--_--_-_--__--__ 36 Data_presentedon_potentialoverpressurezones-__________ ___.---.-NA___________________-_-.-_--_-____-_- I Appr Date 37 Seismic analysis ofshallQwgas-zones____________--_-----_- __.-__-_ NA ___________________ _____-_--_--- - - RPC 8/1812005 38 Seabed conditionsuruey_(ifoff-shore)________________________ __________NA-________--_-.-__-.----_-___-__-___-___-----._ 39 -Contact name/phone for weekly progress_reports [exploratory only]_ - - NA- - _ - Geologic Engineering is Commissioner: s ~ Date: Commissioner: Date ommi 1 ~ ~ ~ ~ ~ ' Date ~'' ~~9 © a C - 9- ~ ~ ~ , L~ • Well History File g~~ ~. ~ 208 APPENDIX • Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • 14-11A.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed Jan 30 08:17:00 2008 Reel Header Service name .............LISTPE Date . ...................08/01/30 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header service name .............LISTPE Date . ...................08/01/30 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: • scientific Technical services Li brary_, .._.S.ci:enti fi c Technical services ~t~ H ~ ~ FEB ~. ~. ZDO 14-11A 500292052901 BP Exploration, Sperry"Sun 30-JAN-08 MWD RUN 3 MWD RUN 4 Mw-000390719 Mw-000390719 A. SHANAHAN N. WHITE D. MASKELL D. MASKELL MWD RUN 6 Mw-000390719 A. SHANAHAN J. RALL 9 lON 14E 1776 1759 Page 1 (Alaska) Inc. MWD RUN 5 Mw-000390719 A. SHANAHAN J. RALL cos-,a~~r s~v5 i ~ 14-11A.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: .00 DERRICK FLOOR: 71.40 GROUND LEVEL: 42.26 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 7109.0 2ND STRING 8.500 9.625 7109.0 3RD STRING 6.125 7.000 10330.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 14-11A PB1 WELLBORE AT 11522'MD/8883'TVD. 4. MWD RUNS 1&2 ARE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3 & 4 COMPRISE DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND PRESSURE WHILE DRILLING (PWD). THROUGH CASING GAMMA RAY DATA FROM 6858'MD/ 6531'TVD TO 7136'MD/6794'TVD WAS ACQUIRED AFTER DRILLING AND ADDENDED TO MWD DATA. 6. MWD RUNS 5 & 6 COMPRISE DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 7. MWD DATA IS DEPTH CORRECTED/SHIFTED TO THE GR PDC LOG OF 25-JUL-1981 (SCHLUM DIL). LOG DATA AND ANNOTATIONS ARE SHIFTED CORRESPONDINGLY; HEADER DATA AND REMARKS RETAIN THE ORIGINAL DRILLER'S DEPTH REFERENCE. SHIFTING WAS DONE PER THE EMAIL FROM DOUG DORTCH(SAIC) ON BEHALF OF COLE ABEL (BP EXPLORATION ALASKA, INC.) OF 15-NOV-07 TO BUSTER BRYANT OF SPERRY DRILING SERVICES. 8. MWD RUNS 3-6 REPRESENT WELL 14-11A WITH API#: 50-029-20529-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11804'MD/8909'TVD. Page 2 • 14-11A.tapx SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL2B.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX 1 and clipped curves; all bit runs merged. .5000 START DEPTH 6904.5 7153.0 10330.5 10330.5 10330.5 10330.5 10330.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 11766.5 11819.0 11773.5 11773.5 11773.5 11773.5 11773.5 --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 6904.5 6889.5 6917.5 6903.0 6920.5 6905.5 6935.5 6920.5 6988.0 6974.0 7003.5 6989.5 7014.0 6998.0 7017.0 7002.0 7027.0 7012.0 7036.5 7021.5 7069.5 7055.5 7073.0 7058.5 7078.5 7064.0 7086.5 7071.5 7108.5 7093.0 11819.5 11804.0 Page 3 • MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 3 MWD 4 MWD 5 MWD 6 REMARKS: MERGED MAIN PASS. 14-11A.tapx MERGE TOP MERGE BASE 6889.0 9476.0 9476.0 10330.0 10330.0 11522.0 11522.0 11804.0 Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum Specification Block sub-type...0 • Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 $ 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 6904.5 11819 9361.75 9830 6904.5 11819 ROP MWD FT/H 0.08 209.94 61.2458 9333 7153 11819 GR MwD API 17.13 571.37 112.093 9725 6904.5 11766.5 RPX MWD OHMM 1.48 2000 18.7938 2887 10330.5 11773.5 RPS MWD OHMM 1.92 2000 19.9715 2887 10330.5 11773.5 RPM MWD OHMM 1.72 1960.66 21.6422 2887 10330.5 11773.5 RPD MWD OHMM 0.4 2000 28.3519 2887 10330.5 11773.5 FET MWD HOUR 0.56 92.69 4.33344 2887 10330.5 11773.5 First Reading For Entire File..........6904.5 Last Reading For Entire File...........11819 File Trailer service name... .......sTSLI6.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.002 Physical EOF Page 4 ., File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 comment Record FILE HEADER FILE NUMBER: 2 RAW MWD 14-11A.tapx • Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6889.5 ROP 7137.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): STOP DEPTH 9444.5 9476.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: Page 5 03-SEP-05 Insite 6.02 Memory 9476.0 6889.0 9476.0 34.7 58.5 TOOL NUMBER 126027 8.500 7109.0 Other 11.00 51.0 9.1 800 .0 .000 .0 .000 159.8 .000 .0 .000 .0 • • 14-11A.tapx HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6889.5 9476 8182.75 5174 6889.5 9476 ROP MWD030 FT/H 0.72 203 63.7276 4678 7137.5 9476 GR MWD030 API 43.71 418.88 142.584 5111 6889.5 9444.5 First Reading For Entire File..........6889.5 Last Reading For Entire File...........9476 File Trailer Service name... .......STSLIB.002 Service Sub Level.Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 comment Record FILE HEADER FILE NUMBER: 3 Page 6 • • 14-11A.tapx RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9445.0 10299.0 RoP 9476.5 10330.0 LOG HEADER DATA DATE LOGGED: 05-SEP-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10330.0 TOP LOG INTERVAL (FT): 9476.0 BOTTOM LOG INTERVAL (FT): 10330.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 54.6 MAXIMUM ANGLE: 59.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 126027 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 7109.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 11.20 MUD VISCOSITY (S): 47.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 900 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 159.8 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Page 7 14-11A.tapx Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MwD040 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9445 10330 9887.5 1771 9445 10330 ROP MWD040 FT/H 5.02 90.84 32.5841 1708 9476.5 10330 GR MwD040 API 62.78 158.13 128.927 1709 9445 10299 First Reading For Entire File..........9445 Last Reading For Entire File...........10330 File Trailer Service name... .......STSLI6.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10299.5 11522.0 FET 10315.0 11522.0 RPD 10315.0 11522.0 RPM 10315.0 11522.0 RPS 10315.0 11522.0 RPx 10315.0 11522.0 Page 8 • 14-11A.tapx ROP 10330.5 11522.0 LOG HEADER DATA DATE LOGGED: 11-SEP-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11522.0 TOP LOG INTERVAL (FT): 10330.0 BOTTOM LOG INTERVAL (FT): 11522.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 55.4 MAXIMUM ANGLE: 99.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 047410 EWR4 ELECTROMAG. RESIS. 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10330.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 45.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 4300 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.500 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .609 180.0 MUD FILTRATE AT MT: 1.500 69.0 MUD CAKE AT MT: 1.400 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Page 9 • • 14-11A.tapx Name service order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MwD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MwD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10299.5 11522 10910.8 2446 10299.5 11522 ROP MWD050 FT/H 1.05 209.94 78.0952 2384 10330.5 11522 GR MWD050 API 17.13 571.37 49.4664 2446 10299.5 11522 RPX MWD050 OHMM 1.48 1251.58 11.123 2415 10315 11522 RPS MWD050 OHMM 1.92 1515.87 11.7818 2415 10315 11522 RPM MWD050 OHMM 2.12 1960.66 22.230b 2415 10315 11522 RPD MWD050 OHMM 0.73 2000 27.8778 2415 10315 11522 FET MWD050 HOUR 0.6 92.69 2.82786 2415 10315 11522 First Reading For Entire File..........10299.5 Last Reading For Entire File...........11522 File Trailer Service name... .......STSLIB.004 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF File Header service name... .......sTSLI6.005 service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type. ..........LO Previous File Name.......STSLI6.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 11476.0 11758.0 RPM 11476.0 11758.0 RPS 11476.0 11758.0 Page 10 • 14-11,4. tapx RPX 11476.0 11758.0 FET 11476.0 11758.0 GR 11522.5 11751.0 ROP 11522.5 11803.5 LOG HEADER DATA DATE LOGGED: 12-SEP-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11804.0 TOP LOG INTERVAL (FT): 11522.0 BOTTOM LOG INTERVAL (FT): 11804.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 96.1 MAXIMUM ANGLE: 101.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 047410 EWR4 ELECTROMAG. RESIS. 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10330.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 44.0 MUD PH: $,1 MUD CHLORIDES (PPM): 4000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATUR E (MT): 1.500 69.0 MUD AT MAX CIRCULATING TER MPERATURE: .568 193.5 MUD FILTRATE AT MT: 1.500 69.0 MUD CAKE AT MT: 1.400 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~iny Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Page 11 • 14-11A.tapx Depth Uni ts. .. .. ..... Datum specificat ion Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MwD060 API 4 1 68 8 3 RPX MwD060 OHMM 4 1 68 12 4 RPS MwD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 11476 11803.5 11639.8 656 11476 11803.5 RoP MWD060 FT/H 0.08 196.49 56.2285 563 11522.5 11803.5 GR MwD060 API 19.53 405.06 43.4547 458 11522.5 11751 RPX MWD060 OHMM 7.15 2000 50.2952 565 11476 11758 RPS MWD060 OHMM 2.13 2000 53.3096 565 11476 11758 RPM MWD060 OHMM 1.72 451.03 17.0588 565 11476 11758 RPD MWD060 OHMM 0.4 1271.65 27.2789 565 11476 11758 FET MwD060 HOUR 0.56 28.62 14.358 565 11476 11758 First Reading For Entire File..........11476 Last Reading For Entire File...........11803 File Trailer Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/01/30 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number.....,01 Next Tape Name..........,UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/01/30 Ori in ...................STS Ree~ Name. .... .......,UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library Page IZ scientific Technical services scientific Technical services • 14-11A.tapx Physical EOF Physical EOF End Of LIS File Page 13 < d • 14-11,4PBl.tapx Sperry-Sun Drilling services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed Jan 30 15:28:13 2008 Reel Header Service name .............LISTPE Date . ............. ....08/01/30 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library Tape Header Service name .............LISTPE Date . ...................08/01/30 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 Mw-000390719 A. SHANAHAN D. MASKELL SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD • scientific Technical services Scientific Technical Services 14-11A PB1 500292052970 BP Exploration `(A`l aska) rnc. __ Sperry Sun 30-JAN-08 MWD RUN 4 MWD RUN 5 Mw-000390719 Mw-000390719 N. WHITE A. SHANAHAN D. MASKELL J. RALL 9 lON 14E 1776 1759 .00 71.40 42.26 Page 1 c~C~`J'!~~° ~15~d1° 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: • 14-11APBl.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 7109.0 8.500 9.625 7109.0 6.125 7.000 10330.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. WELL 14-11A EXITS THIS WELLBORE AT 11522'MD/8883'TVD. 4. MWD RUNS 1&2 ARE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3 & 4 COMPRISE DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND PRESSURE WHILE DRILLING (PWD). THROUGH CASING GAMMA RAY DATA FROM 6858'MD/ 6531'TVD TO 7136'MD/6794'TVD WAS ACQUIRED AFTER DRILLING AND ADDENDED TO MWD DATA. 6. MWD RUN 5 COMPRISES DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 7. MWD DATA IS DEPTH CORRECTED/SHIFTED TO THE GR PDC LOG OF 25-JUL-1981 (SCHLUM DIL). LOG DATA AND ANNOTATIONS ARE SHIFTED CORRESPONDINGLY; HEADER DATA AND REMARKS RETAIN THE ORIGINAL DRILLER'S DEPTH REFERENCE. SHIFTING WAS DONE PER THE EMAIL FROM DOUG DORTCH(SAIC) ON BEHALF OF COLE ABEL (BP EXPLORATION ALASKA, INC.) OF 15-NOV-07 TO BUSTER BRYANT OF SPERRY DRILING SERVICES. 8. MWD RUNS 3-5 REPRESENT WELL 14-11A PB1 WITH API#: 50-029-20529-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11617'MD/8942'TVD. SROP = SMOOTHED RATE SGRC = SMOOTHED GAMMA SEXP = SMOOTHED PHASE SHALLOW SPACING). SESP = SMOOTHED PHASE SPACING). )F PENETRATION WHILE DRILLING. RAY COMBINED. SHIFT-DERIVED RESISTIVITY (EXTRA SHIFT-DERIVED RESISTIVITY (SHALLOW Page 2 • 14-11APBl.tapx SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name... .......STSLIB.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX 1 clipped curves; all bit runs merged. .5000 START DEPTH 6904.5 7153.0 10330.5 10330.5 10330.5 10330.5 10330.5 STOP DEPTH 11570.0 11632.5 11577.0 11577.0 11577.0 11577.0 11577.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 6904.5 6889.5 6917.5 6903.0 6920.5 6905.5 6935.5 6920.5 6988.0 6974.0 7003.5 6989.5 7014.0 6998.0 7017.0 7002.0 7027.0 7012.0 7036.5 7021.5 7069.5 7055.5 7073.0 7058.5 7078.5 7064.0 7086.5 7071.5 7108.5 7093.0 11537.5 11522.0 11631.5 11616.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 3 6889.0 9476.0 MwD 4 9476.0 10330.0 MwD 5 10330.0 11617.0 Page 3 • 14-11APBl.tapx REMARKS: MERGED MAIN PA55. Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum Specification Block sub-type...0 • Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 6904.5 11632.5 9268.5 9457 6904.5 11632.5 ROP MWD FT/H 0.72 209.94 61.5539 8960 7153 11632.5 GR MwD API 17.13 571.37 114.924 9332 6904.5 11570 RPX MWD OHMM 1.48 1251.58 11.1933 2494 10330.5 11577 RPS MWD OHMM 1.92 1515.87 11.8441 2494 10330.5 11577 RPM MWD OHMM 2.12 1960.66 22.0107 2494 10330.5 11577 RPD MWD OHMM 0.73 2000 27.5366 2494 10330.5 11577 FET MWD HOUR 0.6 92.69 2.79828 2494 10330.5 11577 First Reading For Entire File..........6904.5 Last Reading For Entire File...........11632.5 File Trailer service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header service name... .......STSLI6.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 Page 4 • 14-11APBl.tapx File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER r: FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6889.5 9444.5 RoP 7137.5 9476.0 LOG HEADER DATA DATE LOGGED: 03-SEP-05 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9476.0 TOP LOG INTERVAL (FT): 6889.0 BOTTOM LOG INTERVAL (FT): 9476.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 34.7 MAXIMUM ANGLE: 58.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 126027 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 7109.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 11.00 MUD VISCOSITY (S): 51.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 159.8 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 5 • 14-11APBl.tapx Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Log~iny Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MwD030 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6889.5 9476 8182.75 5174 6889.5 9476 ROP MWD030 FT/H 0.72 203 63.7276 4678 7137.5 9476 GR MWD030 API 43.71 418.88 142.584 5111 6889.5 9444.5 First Reading For Entire File..........6889.5 Last Reading For Entire File...........9476 File Trailer Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Ty e ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSL2B.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSL26.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH Page 6 • 14-11APBl.tapx GR 9445.0 10299.0 ROP 9476.5 10330.0 LOG HEADER DATA DATE LOGGED: 05-SEP-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10330.0 TOP LOG INTERVAL (FT): 9476.0 BOTTOM LOG INTERVAL (FT): 10330.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 54.6 MAXIMUM ANGLE: 59.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 126027 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8,500 DRILLER'S CASING DEPTH (FT): 7109.0 BOREHOLE CONDITIONS MUD TYPE: Other. MUD DENSITY (LB/G): 11.20 MUD VISCOSITY (S): 47.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 900 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 159.8 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~iny Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 Page 7 • 14-11APBl.tapx Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 9445 10330 9887.5 1771 9445 10330 ROP MWD040 FT/H 5.02 90.84 32.5841 1708 9476.5 10330 GR MWD040 API 62.78 158.13 128.927 1709 9445 10299 First Reading For Entire File..........9445 Last Reading For Entire File...........10330 File Trailer Service name... .......STSLIB.003 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......sTSL2B.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10299.5 11554.5 RPD 10315.0 11561.5 RPM 10315.0 11561.5 RPS 10315.0 11561.5 RPx 10315.0 11561.5 FET 10315.0 11561.5 ROP 10330.5 11617.0 LOG HEADER DATA DATE LOGGED: 11-SEP-05 SOFTWARE SURFACE SOFTWARE VERSION: Incite Page 8 • DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 • 14-11APBl.tapx 6.02 Memory 11617.0 10330.0 11617.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum specification Block sub-type...0 55.4 99.0 TOOL NUMBER 047410 148579 6.125 10330.0 other 8.40 45.0 9.0 4300 .0 1.500 69.0 .609 180.0 1.500 69.0 1.400 69.0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 Page 9 • 14-11APBl.tapx RPD MWD050 OHMM 4 1 68 24 7 FET MwD050 HOUR 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 10299.5 11617 10958.3 2636 10299.5 11617 ROP MWD050 FT/H 1.05 209.94 76.8264 2574 10330.5 11617 GR MWD050 API 17.13 571.37 49.0893 2511 10299.5 11554.5 RPX MWD050 OHMM 1.48 1251.58 11.1933 2494 10315 11561.5 RPS MWD050 OHMM 1.92 1515.87 11.8441 2494 10315 11561.5 RPM MWD050 OHMM 2.12 1960.66 22.0107 2494 10315 11561.5 RPD MwD050 OHMM 0.73 2000 27.5366 2494 10315 11561.5 FET MwD050 HOUR 0.6 92.69 2.79828 2494 10315 11561.5 First Reading For Entire File..........10299.5 Last Reading For Entire File...........11617 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/01/30 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer service name .............LISTPE Date . ...................08/01/30 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EoF Physical EOF Scientific Technical Services scientific Technical services Page 10 i ~ 14-11APBl.tapx End Of LIS File Page 11
