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203-097
STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMM! • WELAMPLETION OR RECOMPLETION REPO AND LOG la. Well Status: Oil 0 Gas 0 SPLUG 0 Other ❑ Abandoned 0 • Suspended 0 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development p Exploratory 0 GINJ 0 WINJ ❑ WAG 0 WDSPL 0 No.of Completions: Zero • Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc s 10/23/2015 • 203-097 • 315-547 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 6/28/2003 50-029-21166-03-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 7/4/2003 PBU 15-07C • Surface: 1527'FNL,1354'FWL,Sec.22,T11N,R14E,UM • 9 Ref Elevations KB 57 77 17. Field/Pool(s): Top of Productive Interval: 2873'FSL,1653'FWL,Sec.14,T11N,R14E,UM GL 29.27 BF 32.74 PRUDHOE BAY,PRUDHOE OIL . Total Depth: 5011'FSL,3067'FWL,Sec.14,T11N,R14E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 12365'/8726' ADL 028306&028307 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 677294- y- 5959986 - Zone - ASP 4 15250'/8706' TPI: x- 682759 y- 5964519 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 684118 y- 5966690 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No m 13. Water Depth.if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 11724'/8472' 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,RE,ABI,CNL 23. CASING,LINER AND CEMENTING RECORD CASING Wr.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# N40 28' 108' 28' 108' 30" 390 sx Permafrost II 13-3/8" 72# L-80 27' 2395' 27' 2395' 17-1/2" 1850 sx PF'E',400 sx PF'C' 9-5/8" 47# L-80/S00-95 25' 10184' 25' 7532' 12-1/4" 500 sx Class'G',300 sx PF'C' RrEcEntz D 7" 26# NTBOS 10026' 11724' 7453' 8472' 8-1/2" 305 sx Class'G' NOV 12� 2;15 4-1/2" 12.6# L-80 11570' 15244' 8373' 8706' 6-1/8" 449 sx Class'G' A yG CC 24. Open to production or injection? Yes 0 No 0 • 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#L-80 11569' 11512'/8336' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes 0 No Per 20 AAC 25.283(i)(2)attach electronic and printed information SCANNED JAN DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 12394' Set CIBP 12365' 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 moi► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corn): Press 24 Hour Rate ""411. Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 �ubmit ORIGINAL only vUri-- i -/ /I., .4 z � RBDIV -;) Nov 13 2015 IC-( 28. CORE DATA Conventional Core(s) Yes 0 No RI • Sidewall Cores Yes 0 No RI 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 RI Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 12331' 8720' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. ZITS-Zone 2A 12020' 8612' Zone 1B 12196' 8681' TDF-Zone lA 12331' 8720' 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: Minge,David Email: David.Minge@bp.com Printed Name: Joe Lastufk0 Title: Drilling Technologist Signature: '9v"¼ / Phone: +1 907 5644091 Date: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 1 b.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 11/2015 Submit ORIGINAL Only • • • 15-07C, Well History (Pre-Rig Sidetrack) YPATE . . , .SUMMARY CTU 8, 1.5"coil, Scope: Whipstock Drift GR/CCL/Set CIBP MIRU CTU #8 - NF swab and SSV. N/U BOPE. MU BOT MHA-3.625"Whipstock Drift w/ PDS 2-7/8" Carrier(GR/CCL)w/3.69" Bar Bell Nozzle- PT lube. RIH clean to 12500'. Log up. Flag coil at 12350'. Log up to 11400'. POH. NF swab and SSV. Lay out PDS. Good data. M/U Baker CIBP BHA. Kill well with KCL. Freeze protect tubing with 38 bbl 50/50 meth. RIH with CIBP to flag. Correct to flag depth at mid element. Set CIBP at 12394' mid element depth. Tag CIBP. POH. BD Setting Tools - 1/2" Ball Recovered - MIT-T to 2500 psi Passed - RDMO CTU #8. 9/16/2015 ***Job Complete*** ***WELL S/I ON ARRIVAL SWCP 4521***(ctd) RIG UP SWCP 4521. 9/18/2015 ***CONTINUE WSR TO 9/19/15*** ***CONTINUE WSR FROM 9/18/15 SWCP 4521***(ctd) SET 4-1/2"X-CATCHER @ 11,478' SLM (11,491' MD). PULLED RK-DGLV FROM ST#2 @ 6,517' SLM (6,530' MD). SET RKP-CIRC VALVE IN ST#2 © 6,517' SLM (6530' MD). 9/19/2015 ***CONTINUE WSR TO 9/20/15*** T/I/O= 1042/1276/0 Temp. =S/I Assist Slickline with well circ. out (Pre CTD) Pumped 5 bbls neat Methanol spear, followed by 453 bbls 1% KCL Inhibited, and 175 bbls diesel, down IA, taking returns up TBG and down the FL. Pumped 44 bbls crude down FL to FP. U-tubed TBG/IA for FP. Bleed TBG/IAP to 400 psi. Bled back — 1.8 bbs. RDMO hung caution and info tags on IA and WV. Hung AFE sign on MV. FWHP's = 9/20/2015 400/400/0 SV, WV SSV =closed, MV= open, IA and OA= OTG. Turned well over to 9/20/2015 WHP : T/I/O Temp = Assist SL as needed. ***CONTINUE WSR FROM 9/19/15 SWCP 4521***(ctd) PULLED RK-CIRC VALVE FROM ST#2 @ 6518'SLM(6530' MD). SET RK-S/O (20/64") IN ST#2 @ 6518'SLM(6530' MD). PULL RK-DMY GLV FROM ST#3 @ 3,081' SLM(3,097' MD). SET RK-LGLV(16/64", 15OOpsi) IN ST#3 @ 3,081' SLM(3,097' MD). 9/20/2015 ***CONTINUE WSR TO 9/21/15*** ****Job continued from 09/20/15 ****WHP : T/I/O 100/190/0 Temp = S/I Pumped 4 bbls DSL down TBG to reach test pressure © 2500 psi 9/21/2015 MIT-T © 2500 psi FAIL 9/21/2015 ***Job cancelled due to permitting*** ***CONTINUE WSR FROM 9/20/15 SWCP 4521***(ctd) LRS PERFORMED SEVERAL FAILING MIT-T. PULLED STA#3 DOME @ 3081'SLM./3097'MD SET RK-DOME 1500#TRO IN STA#3 @ 3081'SLM/3097'MD PERFORMED MIT-T TO 2500 PSI, PASSED. RAN 4 1/2 " GR, SAT DOWN @ 11,478'SLM, PULLED CATCHER,EMPTY, RDMO. 9/21/2015 ***** LEFT WELL SHUT IN, TURNED WELL OVER TO PAD OPER. ***** 9/22/2015 T/I/O =SI/420/0. Remove Wellhouse. See log for details. ***Job Complete*** T/I/O =440/420/0. Installed CTD TS #05 . Torqued and PT'd to API specs. RDMO. 9/24/2015 ***Job Incomplete*** FWHP =440/420/0. T/I/O= SI/425/0. Start barriers list= SSVxWV. Removed and replaced SV platform. Installed slip blind flanged and torqued and PT'd to API specs. Note: Removed SV platform handrails and staged them along with the flange spacer in the 15-07 9/26/2015 wellhouse. RDMO***Job Complete*** SEE LOG FOR DETAILS. Final T/I/0=SI/425/0 T/I/O =SSV/390/12. Temp = SI. WHPs Pre CTD). No AL. IA FL @ surface. Ladder and swab platform are in place with no hand rails. 10/9/2015 SV, WV= ? unable to reach them. SSV= C. MV = 0. IA, OA = OTG. 16:30 • 4110 15-07C, Well History (Pre-Rig Sidetrack) T/I/O =SSV/390/VAC. Temp =SI. Bleed WHP's to 0 psi (pre rig). No AL. Well house removed, swap platform & ladder in place with no hand rails around platform. IA FL @ surface. Bled IAP from 390 psi to 0 psi in 1 hr(.5 Bbls). Monitor for 30 min, during monitor IAP unchanged. 10/12/2015 SV, WV=?. SSV=C. MV =0. IA, OA=OTG. 23:35. T/I/0 = 100/0/0. N/D 4-1/8"x 4-1/16"tapped blind from comapnion side of FC. N/U 4- 1/8" x 4-1/16"temp valve#31 to companion side of FC w/intergal blind & 1502 cap. 10/16/2015 Torqed to API spec&tested. See log for details. ***Job complete*** FWHP's = • • North America-ALASKA-BP Page 1 Of 6 Operation Summary Report Common Well Name:15-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/21/2015 End Date:10/25/2015 X3-017F7-C:(1,733,147.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time:8/16/1984 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UW:500292116600 Active datum:57.77 @57.77usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10/21/2015 09:00 - 10:00 1.00 RIGD P PRE PREJOB FOR RIG MOVE OFF OF WELL 15-49 WSL VERIFIED THE FOLLOWING: AGREED COMMAND FOR STOP DURING RIG MOVE, ESD/KILL SWITCH IN CELLAR MANNED BY NORDIC SUPTAND TESTED BEFORE JACKING UP THE RIG,WHEEL CHOCK (PHYSICAL BARRIER)IN PLACE BEHIND WHEEL TO PREVENT ROLLING BACK ONTO WELL,RADIO COMMUNICATIONS TESTED BY EVERY RIG TEAM MEMBER PARTICIPATING IN RIG MOVE. PRE-MOVE CHECK LIST COMPLETED BEFORE JACKING UP ON RIG. 10:00 - 10:50 0.83 MOB P PRE MOVE RIG OFF OF WELL 15-49. MOVE RIG OVER TO OPPOSITE SIDE OF PAD TO 15-07 10:50 - 11:30 0.67 MOB P PRE PJSM ON SPOTTING RIG OVER WELL. WSL VERIFIED ALL SAFETY BARRIERS IN PLACE:(WHEEL CHOCK,STOP COMMAND UNDERSTOOD,ESD STATION IN CELLAR IS MANNED AND TESTED,RADIO COMMUNICATIONS WITH RIG CREW TESTED). PRESSURES ON TREE:TUBING/IA/OA=0/0/0 PSI SPOT RIG OVER WELL AND SET DOWN SECURED CELLAR ***ACCEPT RIG AT 11:30 AM 10/21/2015*** 11:30 - 13:30 2.00 MOB P PRE CYCLE ALL VALVES ON THE TREE. INSTALL FUSIBLE CAP ON SSV ON THE TREE. LEAK TITE TEST VALVES ON TREE-NO VISIBLE LEAKS. INSTALL TRANSDUCERS ON IA AND OA. *SIMOPS:MOVE SATELLITE CAMP OVER AND SPOT IN PLACE. 13:30 - 16:30 3.00 BOPSUR P PRE NIPPLE DOWN TREE CAP NIPPLE UP BOP STACK CENTER STACK AND SECURE STACK *SIMOPS:PJSM AND RAISE COIL INTO REEL HOUSE.SECURE REEL IN REEL HOUSE. 16:30 - 18:15 1.75 RIGU P PRE FINISH RIG MOVE MAINTENANCE CHECKLIST. MAKE UP LUBRICATOR FOR STUMP WITH QTS. DRESS END OF NEW COIL. INSTALL GRAPPLE IN COIL TO PULL OVER TOP. THREAD WINCH CABLE IN INJECTOR AND THRU STUFFING BOX. 18:15 - 18:45 0.50 RIGU P PRE CONDUCT RIG EVAC DRILL 18:45 - 21:00 2.25 RIGU P PRE RU FLOOR TO STAB COIL INTO INJECTOR. INSTALL NITE CAP.FILL STACK WITH WATER. Printed 11/6/2015 3:49:08PM • • North America-ALASKA-BP • Page 2 of 6 Operation Summary Report Common Well Name:15-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/21/2015 End Date:10/25/2015 X3-017F7-C:(1,733,147.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time:8/16/1984 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292116600 Active datum:57.77'@57.77usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 23:00 2.00 RIGU P PRE PUL TEST GRAPPLE CONNECTOR.REMOVE SHIPPING BAR.PULL COIL ACROSS&STAB INTO INJECTOR. REMOVE STABBING WINCH CABLE FOR PULL BACK CABLE.CUT 5'OF COIL.SEAL END OF E-LINE.ADJUST GOOSENECK.PLACE INJECTOR OVER BUNG HOLE.CLEAN RF.RIG UP REEL IRON. 23:00 - 00:00 1.00 BOPSUR P PRE SHELL TEST OF BOPS IS GOOD,AGAINST SWAB. TEST BOPS BLIND RAMS,UPPER AND LOWER 2-3/8"PIPE/SLIP RAMS,2-3/8"x3-1/2" VBR'S,ANNULAR AND CHOKE VALVES& FLOOR VALVES.250PSI/3500PSI,PER SUNDRY #315-547. FUNCTION TEST BOP'S USING RIG FLOOR& OPS CAB PANEL. PERFORM DRAWDOWN TEST ON ACCUMULATOR. TEST WITNESS IS WAIVED BY LOUIS R. GRIMALDI,AOGCC. TEST IS WITNESSED BY WSL,TOURPUSHER AND DRILLER. NO FAILURES. 10/22/2015 00:00 - 04:10 4.17 BOPSUR P PRE CONTINUE TO TEST BOPE. NO FAILURES. TEST IS WITNESSED BY WSL,TOURPUSHER AND DRILLER. 04:10 - 06:00 1.83 BOPSUR P PRE FILL COIL WITH 5BBLS OF NEET METH FOLLOWED BY 1%KCL,DIVERT RETURNS TO CUTTINGS BOX.PUT NITE CAP ON WELL& TEST SAME.OPEN WELL TO CLOSED CHOKE -20PSI.BLEED OFF.CHECK TORQUE ON TREE BOLTS,SOME MOVEEMENT ON MASTER VALVE X TUBING HEAD NUTS.SSV- 4-3/4"STROKE LENGTH,INSTALL FUSEIBLE CAP.PULL NITE CAP.PICK UP INJECTOR. STAB ONTO WELL. 06:00 - 07:30 1.50 BOPSUR P PRE TEST INNER REEL VALVE&PACK OFFS. CONDUCT PRESPUD WITH BOTH CREWS AT CAMP DURING RESPECTIVE PTM. 07:30 - 08:50 1.33 BOPSUR P PRE PUMP E-LINE SLACK BACK INTO COIL-NO MOVEMENT IN E-LINE HEARD CUT 3'COIL TO GET TO E-LINE TEST E-LINE FOR CONTINUITY-GOOD TEST 08:50 - 13:00 4.17 BOPSUR P PRE INSTALL COIL TUBING CONNECTOR PULL TEST TO 35K HEAD UP BHI STAB INJECTOR ONTO STUMP PUMP 1 COIL VOLUME TO PUSH E-LINE SLACK FORWARD PRESSURE TEST CTC TO 4000 PSI PRESSURE TEST DUAL FLAPPER CHECK VALVES IN COIL. 13:00 - 14:00 1.00 BOPSUR P PRE SCHLUMBERGER MAINTENANCE INSPECTION ON COIL POWER PACK LO/TO OF POWERPACK POWER SUPPLY 14:00 - 15:00 1.00 BOPSUR P PRE MEETING WITH SENIOR MANAGEMENT Printed 11/6/2015 3:49:08PM • North America-ALASKA-BP Page 3 of 6 Operation Summary Report Common Well Name:15-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/21/2015 End Date:10/25/2015 X3-017F7-C:(1,733,147.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time:8/16/1984 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292116600 Active datum:57.77'@57.77usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 16:30 1.50 WHIP P WEXIT OPEN WELL TO CLOSED CHOKE-0 PSI. MAKE UP WHIPSTOCK AND WHIPSTOCK RUNNING TOOLS. MAKE UP 3"COILTRACK MWD TOOLS ORIENT WHIPSTOCK TO HOT MAKE UP LQC TO CTC STAB INJECTOR ON WELL 16:30 - 21:00 4.50 WHIP P WEXIT RUN IN HOLE WITH BHA#1(WHIPSTOCK). CIRC 8.3PPG 1%KCL THRU EDC AT 344PSI/1 BPM.STOP&STRAP TIGER TANK EVERY 1000'&THEN CONTINUE RIH.AT 7000', TAKE RETURNS TO PITS.WT CK AT 11400FT, 52K.RIWAT 11400FT25K.BLEED DOWN IA FROM 125PSI TO OPSI IN 5 MIN TO SLOP OIL CONTAINER,18:20.BLEED DOWN IA FROM 150PSI TO OPSI IN 5 MIN TO SLOP OIL CONTAINER,20:20. 21:00 - 22:00 1.00 WHIP P WEXIT LOG DOWN FOR TIE-IN FROM 11915FT.CIRC 8.3PPG 1%KCL THRU EDC AT 344PSI/1 BPM. MINUS 6.5FT CORRECTION.LOG DOWN FOR CCL FROM 11985FT.BLEED DOWN IA FROM 125PSI TO OPSI IN 5 MIN TO SLOP OIL CONTAINER,21:45. 22:00 - 22:30 0.50 WHIP P WEXIT TAKE RETURNS OUTSIDE.CIRC 8.3PPG 1% KCL THRU EDCAT784PSI/1.5BPM.REVIEW CCL.COLLAR AT 12351FT.CLOSE EDC.GET UP WEIGHT. 22:30 - 22:35 0.08 WHIP P WEXIT PRESSURE UP&SET WHIPSTOCK TOP AT 12365FT,OTF.SET 2K SURFACE WT DOWN, WOB NOT WORKING.GOOD SET. 22:35 - 23:50 1.25 WHIP P WEXIT NOT ENOUGH KCL FOR BOTTOMS UP WITH RETURNS GOING OUTSIDE.TAKE RETURNS OUTSIDE-DIESEL.CIRC 9.5PPG USED MUD THRU TOOL AT 3036PSI/2.97BPM.BLEED DOWN IA FROM 125PSI TO OPSI IN 5 MIN TO SLOP OIL CONTAINER,22:40.60BBLS AWAY, RETURNS CLEANED UP(VOLUME TO S.O.- GLM#2).DISCUSS WITH ODE.STOP& PRESSURE UP TUBING TO 1000 WHP.IA HOLDING AT 100PSI(S.O.IN GLM#2- HOLDING).BLEED OFF WHP&CONTINUE TO SWAP WELL TO 9.5PPG MUD.BLEED DOWN IA FROM 150PSI TO OPSI IN 5 MIN TO SLOP OIL CONTAINER,23:25. 23:50 - 00:00 0.17 WHIP P WEXIT 9.5PPG MUD AT SURFACE.FLOW CHECK-NO FLOW. 10/23/2015 00:00 - 02:10 2.17 WHIP P WEXIT POH.CIRC 9.5PPG USED MUD THRU TOOL AT 1600PSI/1.4BPM.PJSM REGARDING HANDLING BHA WHILE POH. 02:10 - 02:20 0.17 WHIP P WEXIT FLOW CHECK-NO FLOW. 02:20 - 02:50 0.50 WHIP P WEXIT POP OFF WELL.PLACE INJECTOR OVER BUNG HOLE.BLOW DOWN&LD BHA. SETTING TOOL APPEARS OK OFF LOAD BOT TOOLS. 02:50 - 03:00 0.17 WHIP P WEXIT PJSM REGARDING MU MILLING BHA. 03:00 - 04:00 1.00 WHIP P WEXIT MU MILLING BHA.STAB ONTO WELL.TEST QTS 250PS1/4000PSI.POWER UP&TEST TOOLS.SET COUNTERS. 04:00 - 05:40 1.67 WHIP P WEXIT RIH WITH MILLING BHA.CIRC THRU EDC. Printed 11/6/2015 3:49:08PM 410 • • North America-ALASKA-BP Page 4 of 6 Operation Summary Report Common Well Name:15-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/21/2015 End Date:10/25/2015 X3-017F7-C:(1,733,147.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time:8/16/1984 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292116600 Active datum:57.77'@57.77usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:40 - 07:00 1.33 WHIP P WEXIT TIE IN TO PDC DEPTH WITH-18' CORRECTION RIH AND TAG TOP OF WHIPSTOCK AT 12,365' OBTAIN SCR'S AND ESTABLISH PARAMETERS:PUW44K,SOW 21K,PUMP AT 2.72 BPM @ 3020 PSI 07:00 - 13:00 6.00 STWHIP P WEXIT TAG WHIPSTOCK AT 12,365' QINIX TIME MILL AT.1'/6MINUTES(1'/HR) FREE SPIN 3000 @ 2.72 BPM *-01T) RATE IN=2.72 BPM RATE OUT=2.72 BPM MW IN=9.45 PPG MW OUT=9.45 PPG ECD =10.92 PPG ROP=1FPH WOB=1.53 K CIRC PSI=3150 PSI IAP=139 PSI OAP=0 PSI S-RISER=0 PVT =196 BBLS MILL FROM 12,365'TO 12,369'. 13:00 - 18:30 5.50 STWHIP P WEXIT TIME MILL AT.1'/6MINUTES(1'/HR) FREE SPIN 3000 @ 2.72 BPM RATE IN=2.52 BPM RATE OUT=2.54 BPM MW IN=9.45 PPG MW OUT=9.41 PPG ECD =10.88 PPG ROP=.5FPH WOB=2.38 K CIRC PSI= 2930 PSI IAP=10 PSI OAP=280 PSI S-RISER=0 PVT=364 BBLS MILL FROM 12,369'TO 12,374'. **PERFORM COMPLEX WELL CONTROL KICK WHILE DRILLING DRILL FOLLOWED BYAAR** 18:30 - 21:30 3.00 STWHIP P WEXIT MILL 10FT OF RAT HOLE FREE SPIN 3000 @ 2.72 BPM RATE IN=2.52 BPM RATE OUT=2.54 BPM MW IN=9.45 PPG MW OUT=9.41 PPG ECD =10.88 PPG ROP=.5FPH WOB=2.38 K CIRC PSI= 2930 PSI IAP=10 PSI OAP=280 PSI S-RISER=0 PVT=364 BBLS MILL RAT HOLE FROM 12,375'TO 12,385'. 21:30 - 22:50 1.33 STWHIP P WEXIT BACKREAM-3 PASSES FREE SPIN 3000 @ 2.72 BPM RATE IN=2.52 BPM RATE OUT=2.54 BPM MW IN=9.45 PPG MW OUT=9.41 PPG ECD =10.88 PPG ROP=.5FPH WOB=2.38 K CIRC PSI= 2930 PSI IAP=10 PSI OAP=280 PSI S-RISER=0 PVT=364 BBLS DRY DRIFT-CLEAN. 22:50 - 23:00 0.17 STWHIP P WEXIT FLOW CHECK-NO FLOW. 23:00 - 00:00 1.00 STWHIP P WEXIT POH WITH WINDOW MILLING BHA.CIRC 9.5PPG USED MUD THRU EDC 3.3BPM/2784PS1. 10/24/2015 00:00 - 01:15 1.25 STWHIP P WEXIT CONTINUE TO POH WITH WINDOW MILLING BHA.CIRC 9.5PPG USED MUD THRU EDC 3.3BPM/2784PSI.PJSM REGARDING HANDLING BHA WHILE POH.RECOVERED LARGE PIECE OF DOWN HOLE TOOL RUBBER -KB PACKER ELEMENT. Printed 11/6/2015 3:49:08PM SA NOTES:COM POSTIE WRAP TREE= 4"ClIC 411) 15_0 7 C DO MIT-OA OVER 1200 PSI DUET REPAIR DESIGNED K WELLHEAD= FMC • ACTUATOR= BAKER C L 1 PRESSURE RATING OF REPAIR AND DO NOT PUMP M ETH OKB.ELEV= 57.80' /M ETH BLEND INTO OA D4JF TO CHFM INCOM PATIM,!TY BF.ELEV= 32.45' I w/EPDXXY RESIN"**3"X 6"PIECE OF WS POSSIBLY KOP= 11724' BEHIND SLTD LNR.WELL ANGLE>700 @ 12237'. Max Angle= 95°@ 14716' 20"CONDUCTOR — 110' f , Datum MD= 12317' 91.5#,1-40, r----------12186' -�4-1/2"HES X NIP,ID=3.813" Datum TV-0= 8800'SS D=19-124" , GAS LIFT MANDRELS 13-3/8"CSG,72#,L-80,ID=12.347" H 2395' ST MD TVD DEV TYPE VLV LATCH FORT DATE 3 3097 3087 16 MMG-M DOME RK 16 09/20/15 9-5/8"CSG,47#,L-80 BTC XO TO S0095 H 9391' X X 2 6530 5685 50 MMG-M SO RK 20 09/20/15 1 9966 7440 61 _MMG-M DMY RK 0 07/07/03 10026' H9-5/8"X 7"TIEBACK SLV,ID=7.50" TOP OF 7"LNRH 10033' 10033' 9-5/8"X 7" BKR MODEL-H PKR w/HMC LNR HGR,ID=6.19" 9-5/8"CSG,47#,L-80 S0095,ID=8.681" H 10243' 0----1 11474' -17"MARKER JOINT Minimum ID = 3.80" @ 11557' ' I 11491' H4-1/2"HES X NIP,ID=3.813" 4-1/2" MILLED HES XN NIPPLE E X 11512' —17"X 4-1/2"BKR S-3 PKR,D=3.875" 9-5/8"MILLOUT WINDOW(15-07A) 10193'-10243' I I 11536' —I4-1/2"HES X NIP,ID=3.813" 11557' —14-1/2"HES XN NIP,MILLED TO 3.80"(06/05/10) - 4-1/2"TBG,12.6#,L-80 IBT-M,.0152 bpf,ID=3.958" -I 11568' W TOP OF 4-1/2"LNR H 11577' \� 11569'_H4-1/2" LEG,ID=3.958" \01i • 7"LNR,26#,NT-80 NSCC,0383 bpf,ID=6.276" H 11724' 0:\ 11570' H6"LNR TIEBACK,D=5.25" 11577' H 7"X 5"BKR ZXP LW w/LNR HGR,ID=4.40" PERFORATION SUMMARY RI LOG: 11590' --I5"X 4-1/2"XO,ID=3.860" ANGLE AT TOP PERF:N/A 7"MILLOUT WINDOW(15-07C) 11724'-11736' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 12365' —14-1/2"WHIPSTOCK(10/23/15) 15-07C 2-1/2" 6 12400-12450 C 07/23/06 12394' —14-1/2"BOT CIBP(09/16/15) 2-1/2" 6 12580-12605 C 07/23/06 2-1/2" 4 12910-13110 C 07/07/03 4-1/2"MILLOUT WINDOW(15-07C L1) 12735'-12745' 2-1/2" 4 13158-13180 C 07/07/03 2-1/2" 4 13250-13290 C 07/07/03 _ \ 12761' 1 TOP OF LNR 2-1/2" 4 13350-13372 C 07/07/03 (15'OPEN JUNCTION @ LNR TOP) 2-1/2" 4 13450-13480 C 07/07/03 I \ 0 2-1/2" 4 13530-13650 C 07/07/03 2-1/2" 4 13710-13970 C 07/07/03 I 2-1/2" 4 14260-14310 C 07/07/03 I 2-1/2" 4 14360-14382 C 07/07/03 2-1/2" 4 14420-14560 C 07/07/03 2-1/2" 4 14690-14760 C 07/07/03 I 2-1/2" 4 14780-14960 C 07/07/03 \ 2-1/2" 4 15030-15120 C 07/07/03 I �\ 2-1/2" 4 15050-15070 C 07/07/03 I PBTD(0-RNG SUB) —I 14275' 15-07CL1 2-7/8" SLID 12761 -14276 SLOT 06/16/10 MID 15160' ,•**• 2-7/8"LNR,6.16#,L-80 STL, H 14297' ►�i�i�i 4 4.4 ♦ .0058 bpf,ID=2.875" 4-1/2"LNR, 12.6#,L-80 IBT-M,.0152 bpf,D=3.958" 15244' own) H 15050' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/01/85 NIES ORIGINAL COMPLETION 11/18/13 ICT/JMD GLV GO(11/16/13) WELL: 15-07C 02/25/94 D-9 SIDETRACK(15-07A) 06/17/14 TA/JMD PULLED WRP(06/16/14) PERMIT No: 2030970(2100400) 08/15/00 CDR-1 CTD SIDETRACK(15-07B) 08/13/15 SJW/JMD GLV C/O(07/31/15) API No: 50-029-21166-03(04) 07/08/03 N2ES CTD SIDETRACK(15-07C) 10/02/15 BLS/JMD SET CIBP(09/16/15) SEC 22,T11 N,R14E,1527'FNL&1354'FWL 06/15/10 NORDIC 1 CTD SDTRACK(15-07CLI) 10/02/15 GJB/JMD GLV C/O(09/21/15) 11/18/13 DU/JMD TREL C/O(11/08/13) BP Exploration(Alaska) Zai- c'1 Gyrodata Incorporated • • 20,252 23000 Northwest Lake Dr. gyroldata * Houston, Texas 77095 Precision Wellbore Placement T. (281) 213-6300 • F: (281) 213-6301 R EA V ED SEP21 eui AOGCC same) JUN 0 7 2016, SURVEY REPORT BP Exploration Drill Site: 15 #15-07C Wellhead Prudhoe Bay, North Slope Borough, AK AK0815GCM164 29 August 2015 RIGHT PLACE FIRST TIME www.gyrodata.corn moi' Gyrodata Incorporated • • 23000 Northwest Lake Dr. gyroldata, Houston,Texas 77095 Precision Wellbore Placement T: (281) 213-6300 • F: (281) 213-6301 September 17, 2015 State of Alaska - AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: Drill Site: 15, Well # 15-07C Prudhoe Bay, Alaska Enclosed, please find one (1) copies, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, Kelly Landram Senior Operations Assistant RIGHT PLACE FIRST TIME c� www.gyrodata.com • • 0 0 .Y tit0 U 0 O a o N o c ° 3art ° x8 o Z `•H o Z o tg 3 41, a p o a> • 0 a o N l -d 5 1 U a> b ' . N up U ° O ed o 0 o - r7 0 .�cn td) ct 1-6 `r�J aa)i c U a = = A g4 °J ° W E. F b ... 0 0 Q > U a a (I) o Z '.] Q Q � t A R: °' a 0 cl � 3 al 17 ,...1 > 0 al L.0 w b >` P. o 0 C7 A a d' eq 9i W H 2 >° a w UU az o cdb 1/40 g 0 (7 `r 3 0 N 0, • Q o 0 v as rn Z c0 a N N 0 cYd tY 0 •2O 1 Z Q N a) N N )°-, w 00 U C/D C/D • • N 44 3333 33333 33333 3344 O co M VI O1 --4 .1- CT O M --, 141 l M N 141 O M c/) O H O (.11 �t l: N 1/4O O. N N 71 o l; �D v? ^+ u•? N aw O W O O O --, --, -•-� N N N .-•. -, --, -, ., 0 0 H O �t z CO p ; ,_, QC� (-1 O M \OQ\ N el- 00 \OMO MN N00N ooQ, MpM O O O N VD O d: 00 ., M M N .-4 oo c; O? 10 V; W O O O 0 0 0 0 ti �-, .--i N N N (Ni N 4-4 -- 0 0 0 cn W v" t--- O NO H � W H O 444 N d- t� N -, M O 00 U ,. 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O Z Q)) � LU 4-i0 0 C N d r 7 r -0 N d" N .--I LU O a E -I O 2 W M 0 �_ O r�-1 Z w CO '-I CO 0 F-' "4 O O I 0 Ln O in Q m0 ° M m O O -- -----r - r-------y '- r '-- -r-' -r-- o M 0 _ o L() • N . r. U' Z O Z I O fY ' - N0 Z O O Ln 10 cn -. to CD Q I - C I CT , o (_ '- •-: -F--- --- - --F- -+- -1- 0 N LO I . .,-'1 Co V Q I -. u O I -C' � ��, 0 .-1 O in z -- Cl) t0 in -Q N N _C O a) 1 ' -"-----I----._.._.- _._I-...------I -_-4`--------- ._i. --`---+-- -- -- ---- —0 (B = I I I s.. C I Q 0 I i i i I l i l I I I I 1 1 1 1 1 1 1 1 I : I 1 I I 1 1 1 1 11 I 1 • I I I 1 1 1 1 1 1 I I I , 1 .1_ )( _ ;yamI I 1 I I I I I 1 wr— a 0 0 0 0 0 0 0 o O o a 0 o 0 o 0 o 0 0 0 0 0 m - J LLn d' d' M � N N a 11) (4) 9NILSV3 • • >- ro W • ,, , L. •V W p O 0 r--I ®! V) ® p > t-. I0 ® O 1--4 CIJ .1Q O 0 03 0 •., _____-----. Iq 1 • - * i o o i ...smalls ,�1-1 o a 0 - _ o a) ..„„„„...a. o r.... '..... ..,..,. - • ,-1 al O I I 1 I • I • • •- ; + O O O I , O O 0 0i I I I , I .. p a► - 00 •,_... I F- MI 0- I N. Ill Ce _. O ,,_._.._._ -. O W , , I d. ' • d 0 .o r .. o _ 1erie► O O ""' d O • - O U O • 0 iC= •1 C ,1 . - -_r- I ..... • O Ln -6 N C 4..) I O O O O u (n � O O L • C 0c)O ' >4 4 • L1.1 CO 1 O a j O 'er N 0 o t® I' N 0 ml ,®t ,-i r-1 (1j00i/6ap) uR J]AJs 991900 . i i Survey QC - RGS-CT Specification Sheet gyroidata SURVEY QUALITY CONTROL-SPECIFICATION DATA PRE-30B CALIBRATION VERIFICATION CHECK(ROLL TEST) Station Tool Face Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 64 270.21 96.41 0.00002409 -1.07 63 270.21 103.37 0.00002583 -0.18 62 224.62 -407.89 -0.00010200 -3.98 61 224.62 -403.15 -0.00010082 -4.92 60 46.45 -344.14 -0.00008607 -5.25 59 46.45 -349.41 -0.00008738 -5.68 58 240.40 -310.58 -0.00007765 -1.47 57 240.40 -308.26 -0.00007707 -0.14 56 0.81 -1.23 -0.00000031 -5.65 55 0.81 6.26 0.00000157 -5.02 54 330.42 323.20 0.00008080 -4.02 53 330.42 324.37 0.00008109 -3.45 52 300.80 378.68 0.00009463 0.40 51 300.80 376.38 0.00009405 -0.85 50 270.43 106.02 0.00002649 0.72 49 270.43 104.27 0.00002606 -0.87 48 209.28 -374.56 -0.00009368 -4.56 47 209.28 -374.60 -0.00009369 -5.40 46 180.73 -43.69 -0.00001093 -5.18 45 180.73 -39.43 -0.00000986 -6.15 44 150.48 301.75 0.00007543 -5.86 43 150.48 301.42 0.00007535 -5.12 42 120.50 386.31 0.00009654 -4.81 41 120.50 387.37 0.00009680 -4.06 40 91.31 146.18 0.00003653 -3.70 39 91.31 152.13 0.00003802 -4.01 38 60.90 -251.97 -0.00006300 -6.46 37 60.90 -250.26 -0.00006257 -5.76 36 30.38 -337.87 -0.00008451 -7.42 35 30.38 -334.47 -0.00008366 -7.68 34 0.10 -5.75 -0.00000144 -4.17 33 0.10 -12.17 -0.00000304 -4.47 32 270.57 79.70 0.00001992 12.67 31 270.57 85.59 0.00002139 11.31 30 226.52 -440.41 -0.00011012 -9.85 29 226.52 -434.52 -0.00010865 -9.79 28 46.78 -373.10 -0.00009330 -7.51 27 46.78 -373.54 -0.00009341 -7.51 26 1.19 -43.54 -0.00001089 -7.85 25 1.19 -32.67 -0.00000817 -8.71 24 330.29 291.67 0.00007291 5.94 23 330.29 294.42 0.00007360 6.05 22 300.96 356.23 0.00008901 11.93 21 300.96 356.88 0.00008918 10.71 20 269.67 71.69 0.00001792 14.41 19 269.67 82.59 0.00002064 14.35 18 209.41 -399.44 -0.00009990 -10.12 17 209.41 -398.99 -0.00009979 -10.37 . 16 240.33 -302.38 -0.00007560 1.11 15 240.33 -304.31 -0.00007608 2.78 14 180.58 -78.84 -0.00001972 -9.66 13 180.58 -77.16 -0.00001930 -8.86 12 151.43 272.05 0.00006801 1.57 11 151.43 271.57 0.00006789 1.69 10 120.75 387.35 0.00009680 7.85 9 120.75 387.76 0.00009690 7.91 8 91.05 163.22 0.00004080 6.57 7 91.05 171.82 0.00004294 6.56 6 60.55 -242.27 -0.00006058 -2.45 5 60.55 -242.01 -0.00006051 -2.40 SURV-Q167 COPS SUR-MA-003) 19th Nov 03/Rev 15 Page 1 of 7 AK0815GCM164 Survey QC - RGS-CT Specification Sheet WV*ta 4 31.25 -350.65 -0.00008771 -11.81 3 31.25 -353.17 -0.00008834 -12.23 2 0.17 -41.99 -0.00001050 -8.87 1 0.17 -46.56 -0.00001165 -7.32 MBO = -0.31 Gravity Error= -29.97 Scale Factor Uncertainty= -0.00000751 Rate Error= -2.16 POST-30B CALIBRATION VERIFICATION CHECK(ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 18396 270.79 122.74 0.00003067 1.29 18395 270.79 126.34 0.00003158 0.72 18394 225.45 -390.89 -0.00009775 -8.49 18393 225.45 -390.05 -0.00009754 -9.54 18392 45.62 -312.09 -0.00007806 -1.53 18391 45.62 -305.10 -0.00007631 0.35 18390 0.53 12.64 0.00000316 1.78 18389 0.53 19.53 0.00000489 0.73 18388 332.20 330.47 0.00008263 3.92 18387 332.20 332.79 0.00008320 3.08 18386 301.53 398.65 0.00009962 4.14 18385 301.52 401.41 0.00010031 6.42 18384 271.18 134.98 0.00003373 2.98 18383 271.18 145.38 0.00003633 5.78 18382 240.85 -271.51 -0.00006788 -4.01 18381 240.84 -265.19 -0.00006630 -3.51 18380 210.67 -365.97 -0.00009154 -10.15 18379 210.67 -371.73 -0.00009298 -8.47 18378 179.90 -12.85 -0.00000321 -10.22 18377 179.90 -10.49 -0.00000262 -11.58 18376 149.19 348.27 0.00008707 -7.94 18375 149.19 354.27 0.00008857 -7.81 18374 120.86 440.67 0.00011013 -4.36 18373 120.86 443.75 0.00011090 -5.02 18372 90.12 194.50 0.00004862 -2.24 18371 90.12 198.63 0.00004965 -2.86 18370 61.09 -180.70 -0.00004519 -3.45 18369 61.09 -183.49 -0.00004588 -1.81 18368 31.04 -287.38 -0.00007189 -1.87 18367 31.04 -288.45 -0.00007216 -0.84 18366 0.67 0.06 0.00000001 1.10 18365 0.67 -2.43 -0.00000061 0.89 18364 271.00 132.98 0.00003324 3.82 18363 271.00 136.38 0.00003408 3.11 18362 225.55 -421.09 -0.00010529 -4.99 18361 225.55 -426.09 -0.00010654 -7.11 18360 43.99 -343.96 -0.00008603 -0.99 18359 43.99 -342.83 -0.00008574 -1.17 18358 0.97 -29.34 -0.00000734 1.85 18357 0.97 -29.65 -0.00000742 -0.10 18356 332.71 286.15 0.00007154 5.88 18355 332.71 284.81 0.00007120 6.41 18354 301.88 389.95 0.00009745 4.72 18353 301.88 392.01 0.00009796 5.61 18352 271.59 151.27 0.00003781 5.00 18351 271.60 155.06 0.00003875 5.81 18350 240.79 -270.96 -0.00006775 1.04 18349 240.79 -273.96 -0.00006849 -1.08 18348 210.66 -396.87 -0.00009926 -6.60 18347 210.66 -395.20 -0.00009884 -5.38 18346 180.34 -79.41 -0.00001986 -9.82 18345 180.35 -71.52 -0.00001789 -9.02 18344 150.86 287.43 0.00007185 -6.99 SURV-Q167(OPS SUR-MA-003) 19"Nov 03/Rev 15 Page 2 of 7 AK0815GCM164 • • C Survey QC - RGS-CT Specification Sheet gyrodata 18343 150.87 289.54 0.00007238 -8.35 18342 121.25 439.26 0.00010978 -4.80 18341 121.25 438.91 0.00010969 -3.82 18340 91.17 247.33 0.00006183 -5.53 18339 91.17 254.96 0.00006373 -5.75 18338 61.48 -157.53 -0.00003939 -1.59 18337 61.48 -150.77 -0.00003770 -4.63 18336 31.70 -329.63 -0.00008245 -1.54 18335 31.70 -326.02 -0.00008155 -0.99 18334 1.27 -89.20 -0.00002231 2.44 18333 1.27 -88.13 -0.00002204 1.32 MBO= -0.33 Gravity Error= 0.48 Scale Factor Uncertainty= 0.00000010 Rate Error= -1.81 INITIALISATION Gyro Compass Reading /Station Raw Inclination Raw Azimuth Abs(ERN...-ERrmeo) 18282 10.91 74.77 0.0030 18283 10.91 74.54 0.0900 18284 10.91 74.63 0.0170 18285 10.91 74.81 0.0293 18286 10.91 74.59 0.0727 18287 10.91 74.47 0.0509 Average 10.91 74.63 0.0438 Tolerance on Average* 0.0816 Standard Deviation 0.00 0.13 0.0335 Tolerance on St. Dev.** 0.10 0.20 0.0368 Advanced Initialisation Azimuth Advanced Initialisation Standard Deviation Tolerance =TBA * Tolerance on Average of earth horizontal rate difference is given by (1/Cosl)*J[(CosA*SInI*0.1)2+0.0821 0/hr ** Tolerance on Standard Deviation of earth horizontal rate difference tolerance is given by (1/Cosi)*J[(CosA*SInI*0.1)2+(0.082/(n-1))] °/hr DRIFT TUNES Drift Tune Ending Ending Ending Ending Residual Gx Bias Residual Gy Bias Number Time Depth Inclination Azimuth Start End Start End 1 906.89 3850.14 24.94 42.20 -0.000 0.002 0.002 -0.001 2 595.30 4400.07 40.05 44.67 -0.004 0.004 -0.001 0.001 3 1290.22 6450.16 48.04 50.30 0.001 0.000 0.003 -0.003 4 1369.70 8800.01 57.41 46.53 0.001 0.000 0.005 -0.005 5 1162.19 10300.12 54.54 57.81 0.003 -0.002 0.002 -0.002 6 973.66 11400.03 50.19 59.29 -0.001 0.002 0.001 -0.001 7 765.73 11898.37 66.48 66.11 -0.073 0.072 0.033 -0.034 8 799.75 11400.03 49.86 58.59 -0.002 0.002 0.001 -0.001 9 1356.16 10300.03 53.67 58.65 -0.002 0.003 -0.001 -0.000 10 1051.15 9500.03 61.14 49.00 -0.001 0.002 -0.002 0.001 11 964.64 8800.03 57.40 46.59 -0.001 0.002 0.000 -0.001 12 1341.27 7700.08 61.45 46.84 -0.002 0.004 -0.001 -0.000 13 1501.72 6450.02 48.18 50.49 0.000 0.002 -0.002 0.001 14 1313.66 5399.92 48.72 47.46 -0.001 0.003 -0.000 0.000 - SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 3 of 7 AK0815GCM164 e 0 • Survey QC - RGS-CT Specification Sheet gym ta 15 1268.34 4400.01 40.53 44.73 -0.001 0.004 -0.000 0.001 16 827.50 3850.12 25.09 42.15 0.000 0.001 0.001 0.001 17 1338.06 2870.21 10.83 77.13 0.009 -0.004 -0.003 0.002 Average -0.004 0.006 0.002 -0.002 Standard Deviation 0.018 0.017 0.008 0.008 Tolerance for both the Average and the Standard Deviation 0.033°/hr 0.033°/hr 0.033°/hr 0.033°/hr INCLINATION AND AZIMUTH INRUN AND OUTRUN COMPARISON Depth I Corrected Inclination Corrected Azimuth Inrun * I Outrun * I Difference Inrun * I Outrun * I Difference 100.00 0.09 0.00 0.09 286.16 123.63 162.53 200.00 0.15 0.13 0.02 211.49 196.56 14.93 300.00 0.22 0.18 0.04 230.81 212.94 17.87 400.00 0.31 0.21 0.10 225.16 221.02 4.14 500.00 0.36 0.24 0.12 227.69 222.26 5.43 600.00 0.34 0.26 0.08 224.90 222.46 2.44 700.00 0.26 0.20 0.06 220.81 221.76 -0.95 800.00 0.13 0.13 -0.00 212.52 220.58 -8.05 900.00 0.09 0.15 -0.06 155.23 154.37 0.86 1000.00 0.10 0.17 -0.07 62.46 78.66 -16.20 1100.00 0.10 0.22 -0.12 79.51 52.83 26.68 1200.00 0.15 0.27 -0.12 51.30 33.22 18.08 1300.00 0.24 0.26 -0.02 11.18 29.43 -18.25 1400.00 0.31 0.24 0.07 13.32 27.91 -14.59 1500.00 0.41 0.34 0.08 57.52 42.92 14.60 1600.00 0.41 0.45 -0.03 75.07 60.58 14.49 1700.00 0.47 0.44 0.02 69.39 67.17 2.21 1800.00 0.48 0.42 0.06 65.45 71.95 -6.50 1900.00 0.46 0.46 -0.00 73.03 62.69 10.34 2000.00 1.03 1.21 -0.18 58.97 57.58 1.39 2100.00 1.54 1.52 0.02 79.15 79.43 -0.28 2200.00 1.46 1.39 0.08 87.69 85.91 1.79 2300.00 0.99 1.04 -0.04 92.18 93.95 -1.77 2400.00 0.97 0.99 -0.02 102.56 92.12 10.44 2500.00 1.32 1.77 -0.44 72.61 71.41 1.20 2600.00 5.87 5.87 0.01 66.04 65.62 0.42 2700.00 7.70 7.65 0.05 63.59 63.68 -0.08 2800.00 8.74 8.93 -0.19 80.02 79.65 0.37 2900.00 11.80 11.97 -0.17 76.22 76.31 -0.09 3000.00 14.63 14.76 -0.13 72.22 72.57 -0.35 3100.00 16.40 16.57 -0.17 69.94 69.77 0.17 3200.00 16.50 16.53 -0.03 63.58 63.36 0.22 3300.00 16.42 16.56 -0.13 60.32 60.48 -0.17 3400.00 17.92 18.03 -0.11 59.42 59.42 -0.00 3500.00 19.73 19.88 -0.14 55.64 55.63 0.01 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 4 of 7 AK0815GCM164 r 0 • Survey QC - RGS-CT Specification Sheet gymdata 3600.00 20.73 20.86 -0.13 52.01 51.94 0.07 3700.00 20.59 20.74 -0.16 45.72 45.88 -0.16 3800.00 22.41 22.72 -0.31 44.79 44.68 0.11 3900.00 26.05 26.24 -0.19 42.00 42.03 -0.03 4000.00 28.83 29.06 -0.22 42.46 42.54 -0.08 4100.00 31.70 31.82 -0.12 43.38 43.42 -0.04 4200.00 33.70 33.84 -0.14 44.16 44.19 -0.03 4300.00 37.22 37.38 -0.16 44.31 44.33 -0.02 4400.00 40.20 40.25 -0.06 44.66 44.67 -0.00 4500.00 42.91 42.98 -0.07 45.11 45.08 0.03 4600.00 46.08 46.15 -0.08 45.55 45.53 0.02 4700.00 48.72 48.80 -0.08 45.80 45.76 0.04 4800.00 51.04 51.09 -0.04 45.91 45.85 0.06 4900.00 50.89 50.88 0.01 46.07 46.02 0.05 5000.00 50.52 50.51 0.02 46.18 46.12 0.06 5100.00 50.12 50.08 0.05 46.52 46.49 0.03 5200.00 49.45 49.43 0.02 47.03 47.01 0.02 5300.00 49.46 49.42 0.04 47.68 47.63 0.05 5400.00 48.72 48.71 0.01 47.46 47.40 0.06 5500.00 48.65 48.62 0.03 48.20 48.20 -0.01 5600.00 48.45 48.44 0.01 49.64 49.62 0.01 5700.00 48.11 48.09 0.01 50.22 50.21 0.01 5800.00 47.69 47.70 -0.01 50.39 50.43 -0.03 5900.00 47.57 47.56 0.01 51.15 51.11 0.04 6000.00 47.73 47.71 0.02 51.92 51.85 0.07 6100.00 47.94 47.94 0.00 52.13 52.10 0.03 6200.00 48.03 48.00 0.03 52.28 52.35 -0.08 6300.00 47.27 47.12 0.16 50.07 49.94 0.13 6400.00 47.23 47.23 0.00 49.12 49.33 -0.21 6500.00 49.04 49.04 -0.00 50.43 50.52 -0.09 6600.00 50.82 50.85 -0.03 50.39 50.41 -0.02 6700.00 52.50 52.51 -0.01 49.90 49.90 0.00 6800.00 54.45 54.45 -0.01 49.50 49.52 -0.03 6900.00 56.22 56.26 -0.04 48.89 48.92 -0.04 7000.00 57.97 58.00 -0.02 48.51 48.56 -0.05 7100.00 59.87 59.89 -0.03 48.11 48.14 -0.03 7200.00 60.56 60.55 0.02 47.46 47.45 0.01 7300.00 60.34 60.33 0.00 47.26 47.31 -0.04 7400.00 61.26 61.25 0.01 47.17 47.20 -0.03 7500.00 60.78 60.71 0.07 47.06 47.10 -0.03 7600.00 61.24 61.21 0.03 46.89 46.90 -0.01 7700.00 61.46 61.43 0.04 46.81 46.85 -0.04 7800.00 62.16 62.19 -0.04 46.59 46.64 -0.05 7900.00 62.17 62.12 0.06 46.48 46.50 -0.02 SURV-Q167(OPS SUR-MA-003) 19"Nov 03/Rev 15 Page 5 of 7 AK0815GCM164 • 0 Survey QC - RGS-CT Specification Sheet gymidata 8000.00 61.96 61.98 -0.02 46.41 46.44 -0.04 8100.00 61.99 61.91 0.08 46.20 46.25 -0.06 8200.00 61.28 61.27 0.01 46.20 46.24 -0.04 8300.00 60.77 60.72 0.05 46.12 46.14 -0.02 8400.00 60.38 60.33 0.05 46.11 46.12 -0.01 8500.00 59.96 59.94 0.02 46.22 46.22 -0.00 8600.00 59.14 59.09 0.05 46.32 46.39 -0.06 8700.00 58.62 58.59 0.03 46.52 46.59 -0.07 8800.00 57.52 57.46 0.05 46.53 46.58 -0.05 8900.00 57.07 57.11 -0.04 46.42 46.52 -0.10 9000.00 58.00 57.98 0.02 46.82 46.90 -0.07 9100.00 58.86 58.90 -0.04 47.16 47.22 -0.06 9200.00 59.68 59.65 0.03 47.61 47.66 -0.05 9300.00 60.20 60.24 -0.04 48.08 48.15 -0.07 9400.00 60.81 60.78 0.04 48.50 48.54 -0.04 9500.00 61.02 61.07 -0.05 48.92 48.96 -0.04 9600.00 61.64 61.63 0.02 49.25 49.29 -0.03 9700.00 61.47 61.56 -0.09 49.62 49.60 0.01 9800.00 61.27 61.22 0.05 49.24 49.27 -0.03 9900.00 61.07 61.07 -0.00 49.23 49.22 0.01 10000.00 60.35 60.37 -0.02 49.20 49.17 0.03 10100.00 60.02 59.96 0.06 49.12 49.06 0.06 10200.00 59.82 59.73 0.08 50.03 50.09 -0.06 10300.00 54.59 54.31 0.28 57.80 58.01 -0.21 10400.00 51.60 51.51 0.09 61.35 61.36 -0.01 10500.00 50.28 50.24 0.04 62.28 62.26 0.02 10600.00 51.99 51.97 0.02 60.33 60.28 0.05 10700.00 53.15 53.23 -0.08 59.80 59.78 0.03 10800.00 54.14 54.03 0.11 59.06 58.99 0.07 10900.00 52.07 52.11 -0.04 59.14 59.09 0.05 11000.00 52.74 52.73 0.01 58.66 58.57 0.09 11100.00 54.74 54.78 -0.04 58.40 58.43 -0.03 11200.00 53.42 53.30 0.13 60.56 60.58 -0.02 11300.00 51.29 51.22 0.07 61.25 61.07 0.18 11400.00 50.26 50.19 0.08 59.29 59.22 .0.06 11500.00 49.11 48.93 0.18 58.98 59.02 -0.04 11600.00 49.93 49.63 0.31 58.75 58.90 -0.15 11700.00 50.75 50.51 0.24 58.30 58.40 -0.10 11800.00 57.60 57.65 -0.05 62.51 62.40 0.11 Average -0.0076 -0.0081 Standard Deviation 0.1018 0.0740 Tolerance for both the Average and the Standard Casing 0.3° Casing 0.5° Deviation Drillpipe 0.3° Drillpipe 0.75° * Inclination and Azimuth interpolated to same depths as shown. SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 6 of 7 AK0815GCM164 • • Survey QC - RGS-CT Specification Sheet gYr0/Ciata SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 7 of 7 AKO815GCM164 P • • Survey QC - RGS-CT Analysis Sheet SURVEY QUALITY CONTROL- DATA ANALYSIS REFERENCE SYSTEMS Grid System I I Grid Correction 10.00 Azimuth reference: Grid/True North TRUE NORTH Vertical reference: RKB/MSL/Other RKB I If other give details I TIE ON DATA Depth 0.00 Inclination 0.00 Azimuth 0.00 I TVD 10.00 Northings 0.00 Eastings 0.00 Latitude 70.2962 Az. Ref:Grid/True True Grid Corrected Y/N? N Description I CALIBRATION Tool Number I F0007 I Calibration Date 122 Apr 2013 OPERATING TEMPERATURE Calibration range From 49.49 To 119.45 Gyro operating range From 73.85 To 82.76 j Spec'-Within calibration range FIELD ROLL TEST (Only valid on fixed structures. When not possible input roll test data performed after return to base) Cal value Pre job offset Post job Abs dif.cal.post Abs dif.pre.post Spec' offset Accel Scale 0.000055 -0.000008 0.000000 0.000000 0.000008 Cal/Post- 0,00015 Mass Unbalance 0.90 -0.31 -0.33 0.33 0.03 Pre/Post-0.4°/hr INITIALISATION Depth(Approx) 2870.21 No of stns 6 Spec'- Min No. - 6 Azimuth Mean 74.63 Std deviation 0.13 Spec'-Azi SD 0.2° Inclination Mean 10.91 Std deviation _ 0.00 Spec'-Inc SD 0.1° Earth Horizontal Rate Mean (Abs(meas-theor)) 10.04 Std deviation 0.03 Spec'- See Q167 DRIFT TUNE Residual x gyro bias Mean _ 0.006 Std dev' 0.017 Spec's- Mean and SD-0.333°/hr Residual y gyro bias Mean -0.002 Std dev' 0.008 Spec's- Mean and SD -0.333°/hr TOOLFACE RATE Maximum toolface rate 155.28 I Spec'-400°/sec IN/OUT COMPARISON (AZI'N/A IF INC' <15°) Inclination Difference Mean -0.01 Std dev' 0.10 Spec's- Casing 0.3°/Drill pipe 0.3° Azimuth Difference _ Mean -0.01 Std dev' 0.07 Spec's- Casing 0.5°/Drill pipe 0.75° Lateral Divergence/1000 0.41 Spec-5.0/1000 Vertical Divergence/1000 0.08 Spec'-2.0/1000 DEPTH CONTROL Wireline Company Schlumberger I Line type 7/32" Encoder SF I Schlumberger Max Depth (TD) 11898 CCL Corrected NO Zero Depth(Rig up) RKB @ 57.77 ft AMSL Rezero Depth 13.05 Given pup joint depth NA Measured PJ NA Strech cor.At TD divided by TD/1000 .5084 Spec'- 1.5/1000 Dif. Between rigup and rezero depths divided by TD/1000 1.1059 Spec'-2.0/1000 Dif. Between given and meas depth divided by meas/1000 NA Spec'-2.0/1000 SURV-Q165(OPS SUR-MA-010)22"d Jan 2004/Revision 20 Page 1 of 1 AK0815GCM164 S ir I ata Survey QC - RGS-CT Acceptance Sheet FIELD AND SURVEY INFORMATION Operator BPXA Field/ Platform WELLHEAD Well Number PRUDHOE BAY DRILLSITE 15 WELL 15-07C Survey section From 0.00 ft. to 11898.00.00 ft. Date 29 Aug 2015 Gyrodata Job No AK0915GCM164 Gyrodata Surveyors Henry Drew,Adam O'Connor Job Objective High Accuracy Gyro Survey SURVEY PERFORMANCE In Spec' QC Parameter Yes/No/NA Possible Actions Contact Duty Engineer to discuss options: Operational temperature within Yes 1. Recalibrate tool to higher temperature specification 2. Resurvey with backup tool 3. Resurvey'Hot'section at higher speed Roll test data within specification Contact Duty Engineer to discuss options: Only valid on land/fixed installations Yes 1. Recalibrate tool and reprocess survey 2. Resurvey with backup tool Continuous initialisation within Take new initialisation,after three failures: specification Yes 1. Contact Duty Engineer or, 2. Resurvey with back up tool. Contact Duty Engineer to discuss options: Toolface rate within specification Yes Resurvey section from previous bias check Investigate and comment if effects are negligible Contact Duty Engineer to discuss options: Drift tunes within specification Yes 1. Reprocess with different software settings 2. Resurvey with backup tool Inrun/Outrun comparison within Contact Duty Engineer to discuss options. specification Yes Resurvey is usually not required if either inrun or outrun meet all other QC parameters Depth control within specification Yes Contact Duty Engineer to discuss options. Action taken: Note: Provided satisfactory action has been taken, parameters out with specification will not necessarily fail a survey. SURVEY ACCEPTED Gyrodata Representative Client's Representative SURV-Q166(OPS SUR-MA-003)13th Nov 03/Revision 12 _ Page 1 of 1 AK0815GCM164 : OF TEi� eS.AP\ �j� s THE STATE Alaska Oil and Gas �r� ,;,—s���, ofALASKA Conservation Commission _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS'" Fax: 907.276.7542 www.aogcc.alaska.gov John McMullen SCO" t� 1 Engineering Team Leader BP Exploration(Alaska), Inc. C Q 7 P.O. Box 196612 �,� / Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-07C Sundry Number: 315-547 Dear Mr. McMullen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, OA/)(;11..e.4,-57&_ Cathy P. Foerster Chair DATED this U day of September, 2015 Encl. RBDNISqe0EP 0 I � STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMF JN APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations o Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill H. Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 203-097 . 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development H• 99519-6612Stratigraphic 0 Service ❑ 6. API Number: 50-029-21166-03-00 , 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exceptions Yes 0 No H PBU 15-07C RE E D 9. Property Designation(Lease Number): 10. Field/Pools: 0,I> 'yg ,? L e ADL 028306&028307 • PRUDHOE BAY,PRUDHOE OIL • SEP 0 2 2015" 11 PRESENT WELL CONDITION SUMMARY_ — _ Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): a=(ra►f�et'(./' 15250 • 8724 • 15160 • 8724 • None None Casing Length Size MD TVD Burst collapse Structural Conductor 80 20" 28-108 28-108 1490 470 - Surface 2367 13-3/8" 27-2395 27-2395 4930 2670 Intermediate 10159 9-5/8" 25-10184 25-7549 6870/8150 4760/5080 Liner 1698 7" 10026-11724 7469-8491 7240 5410 Liner 3674 4-1/2" 11570-15244 8392-8724 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12400-15070 8748-8723 4-1/2"12.64 L-80 23-11569 Packers and SSSV Type: 4-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and TVD(ft): 11512/8354 No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal H 13.Well Class after proposed work: • BOP Sketch H Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development H Service 0 14 Estimated Date for Commencing Operations' September 10,2015 15. Well Status after proposed work: , Oil 0 Gas 0 WDSPL 0 Suspended l • 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG 0 Abandoned o Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Minge,David Email David Minge@bp.com Printed Name John McMullen Title Engineering Team Lead Signature Cr'? Phone +1 907 564 4711 Date 9 4 j ji �/j COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 316 - 5q7 Plug Integrity 0 BOP Test a Mechanical Integrity Test 0 Location Clearance 0 Other: �Gp 1157` to 5v✓�-c)p5/9-�/ SP i3 24 33 p5/ ) �vr,„?( / 2v- n►-tv'v2ftr 1L- 5r ft__ 2 "5 vP5r U �ftC' z5 . l L<<, 4 / r r7 GC to pl v 7 `J�1�"l v✓/7'v2 / GC���J rvt/tC(/2T / ZA Spacing Exception Required? Yes 0 ✓ No Subsequent Form Required: /6 - 4 G APPROVED BYTHE Approved by: // COMMISSIONER COMMISSION Date. —g-is-- a477-1, S-- VTC a/.1-/✓ ORIGINAL . REIDNiec SEP 0 9 1°15 Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission 144.114 From: David Minge lk by CTD Engineer ,t Date: August 28th, 2015 Re: 15-07C, 15-07CL1 Sundry Approval Sundry approval is requested to plug the 15-07C and 15-07CL1 perforations and slotted liner as part of the drilling and completion of proposed 15-07D coiled tubing sidetrack. History and current status: 15-07C is a Zone 1 producer that was drilled in 2003. The 15-07CL1 zone 1 lateral was added in 2010. The well is still producing but with a rapidly increasing GOR, and it is not expected to remain competitive. There are no remaining well work options to enhance production. Proposed plan: 15-07D will be drilled from well 15-07C by the Nordic 2 Coiled Tubing Drilling rig on or around September 25th, 2015. The 15-07D sidetrack will exit through the existing 4-1/2" liner and kick off in the Ivishak, and target Zone 1 reserves. The proposed sidetrack is a —3,000' horizontal lvishak Zone 1 producer, which will access a —35 acre reserves target off of DS15. The lateral will be completed with a 3- 1/2" X 3-1/4" X 2-7/8" L-80 liner which will be fully cemented and perforated. This Sundry covers plugging the existing 15-07C and CL1 perforations and slotted liner via a CIBP set pre-rig as well as the 15-07D liner cement job 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. G L /114 r,lie4( Concur Pit well lvGf P i �►c r Dlo, �G �a/ fe570red lbw / O� (u fer01 vas Med 114 frods Gt,'or ro %�,P h/(11 �vt ik,) 0/4sf orr `Ii'vtd as ►'n older. q G of, (i( 5 P� JV WI o I f Nei kve4 4�6►f✓t I�< w� // yec D� /f c�i'��7�s,1,� soccrais �c car �/f6' 1uGf C UC W /YIOd J� f y re a cc/,e, 0 Gt 9/64(% jave- ✓10wN i( _co, fa.dr;l/ fiould a//ot , 'Dl itlfPrb'/"9' ca veil 74i°`4 Tis or 641 °� t° poof. Pre-Rig Work(scheduled to begin September 10th,2015) 1. E Run Gyro. 2. C Dummy whipstock drift. 3. C Set and test CIBP to 2,500 psi. 4. S Change GLVs in preparation for flushing annulus. 5. F Load annulus with 1% KCI. 6. V Pre-CTD tree work (S-Riser planned to be left on). 7. 0 Remove wellhouse and level pad. Rig Work(scheduled to begin September 25th,2015) 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (MASP 2,433 psi) 2. Set 4-1/2" Mono-Bore whipstock at-12,370' MD. 3. Mill 3.80"window and 10'of rathole. 4. Drill PB1: 4-1/4" OH, 880' (16 deg DLS planned). 7. Set OH billet at-13,100' (will change based on actual surveys). 8. Perform OH sidetrack from billet. 9. Drill lateral: 4-1/4"OH, 2,350' (12 deg DLS planned). 10. Run 3-1/2" x 3-1/4"X 2-7/8" L-80 liner leaving TOL at 11,900' MD. 11. Pump primary cement job: 36.6 bbls, 15.8 ppg, TOC at TOL* 12. Perform liner cleanout and GR/CCL log. 13. Perform liner lap test to 2,400 psi 14. Perforate liner based on log interpretation (-500'). 15. Freeze protect well to 2,500' MD. 16. Set TWC; RDMO. Post-Rig Work 1. 0 Re-install wellhouse and pull TWC 2. S Set 45KB liner top packer if needed * *Approved alternate plug placement per 20 AAC 25.112(i) David Minge CTD Engineer 250-2917 CC: Well File Joe Lastufka WE£ a"CM/ 15-0'7 C t SAF �"M°'�COM 2000E PSI DUE TO D RGA K WM1'rgLFEAD= FMD ACTUATOR= BAKER C P1:61 U iE RATING OF REB'AIRAM)DO NOT PUMP METH Oka.ELEV= 57.80' Ll I METH BLEND INTO OA DUE TO CHEM INCOMPATIBIUTY BF ELEV= 3245' I w 1 B'OXXY RESIN"'3"X 6"PIECE OF WS POSSIBLY KOP= 11724' BEIiND SLTD LNR WELL ANGLE>70'@ 12237'. 20"CONDUCTOR, — 110' 11 Minx Angle= 95"@ 14716' I r\ Dotum MD=�..__ 12317 31-5#,I S 40, 2186' H4-1/2"HES X NP,D=3.813" Datum TVD= 8800 SS D=19-124" , GAS LFT MANDRELS 13-3/8"CSG,72#,L-80,D=12.347' —1 2395' ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3097 3087 16 MMG-M DOME RK 16 11/16/13 9-5/8'CSG,47#,L-80 BTC XO TO SO095 --{ 9391' I--4K X 2 6530 5685 50 MMG-M DOME RK 16 11/16/13 1 9966 7440 61 MMG-M DMY RK 0 07/07/03 /� 10026' --19-5/8'X 7'TEBACK SLV,D=7.50' TOP OF 7"LINER --Il 10033' I ' 10033' -9-5/8'X 7" BKR MODEL-H PKR w/HMCLNRHGR,D=6.19' 9-518"CSG,47#,L-80 S0095,D=8.681' --( 10243' /�-- 40,---.1 11474' H 'MARKER JOPfT Minimum ID = 3.80" @ 11557' I 1111491' —I4-112"Hal X NP,D=3.813" 4-1/2" MILLED HES XN NIPPLE g-- 11517 --17'X 4-1/2"BKR S-3 PKR,D=3.875" 9-5/8"MILLOUT WEDOW(15-07A) 10193'-10243' 11536• 1-14-1/2"I lLS X NP,D=3.8131] 11 I ' 1155T --r4-12'HES XN NP,MDL®TO 3.80"(06/05/10) 4-1/2"TBG, 12.64,L-80 BT-M,.0152 bpi,D=3.958" --1 11568' TOP OF 4-1/2"LNR —1 11577' �� 11569' H4-1/2"WLEG,D=3.958" 7"DNR,26#,NT-80 NSCC,0383 bpf,D=6.276" H 11724' 11570' —16"Lt'R TRACK,D=5.25" PERFORATION SUN/MARY11577' --1 7"X 5'BKR ZXP LTP w/LNR HGR,D=4.40" Rim LOG: 11590' —15"X 4-12"XO,D=3.860" ANGLE AT TOP PERF'WA { Note:Refer to Production DB for historical perf data 1 7"MLWINDOW NDOW(15-07C) 11724'-11736' SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 15-07C 2-12" 6 12400 12450 0 07/23/06 4-1/2"MLLOUT WM'DOW(15-07CL1)12735'- 12745' 2-1/2" 6 12580-12605 0 07/23/06 2-1/2' 4 12910-13110 0 07/07/03 2-1/2" 4 13158-13180 0 07/07/03 , 12761' —TOP OF LM 2-1/2" 4 13250-13290 0 07/07/03 (15'OPEN JUNCTION @ LW TOP) 2-1/2" 4 13350-13372 0 07/07/03 2-1/2' 4 13450 13480 0 07/07!03 I 2-1/2" 4 13530-13650 0 07/07/03 2-1/2" 4 13710-13970 0 07/07/03 ' 2-1/2" 4 14260-14310 0 07/07/03 2-1/2" 4 14360-14382 0 07/07/03 2-1/2' 4 14420-14560 0 07/07/03 \ -. 2-1/2" 4 14690-14760 C 07/07/03 I 2-12" 4 14780-14960 C 07/07/03 I 2-1/2" 4 15030-15120 C 07/07/03 2-12" 4 15050-15070 C 07/07/03 15-07CL1 I I PBTD(O RING SUB) 14275' 2-7/8" SLTD 12761-14276 SLOT 06/16/10 MT!) 15160' ii I TRE= 4"CEW SAFETY NOTES:COMPOST1EWRAP REPAIR SH LEAK- IAELLI-EAD= FMS 1 5-07D DO r IIT-OA OVER 1200 PSI DLL TO DESIGNED ACIUA'i'OR= BAKER C PROP(.. _,E DPRS E RATING OF REPAIR AND DO NOT PI N P METH OKE.BP/= 57.80" I METH BLEED INTO OA DUE TO CIEM INCOMPATIBILITY BF.e--EV= 32.45' 1 w/B'OXXY RESIN'CHROME NPPLES"'WELL ANGLE> ROP= 11724' 70'@_. _..l `___. 20"CONDUCTOR, - 110' OAax Angle= 95' 14_716' i tum MD= 12317 91.5#,H-40, 2186° H -1/2"HFS X NP,D=3.813" datum TVD= 8800'SS D=19-124" GAS LFT MANDRELS 13-3/8"CSG,72#,L-80,D=12.347" ---1 2395' LI I ST MD TVD DEV TY VLV LATCH PORT DATE '`{I 3 3097 3087 16 MMG-M DMY RK 0 07/31/15 2 6530 5685 50 MMG-M DMY RK 0 07/31/15 1 9966 7440 61 MMG-M DMY RK 0 07/07/03 10026' H9-5/8"X 7"TEBACK SLV,D=7.50" TOP OF 7"LNR -i 10033' ri 10033' -i9-5/8"X 7" BKR MODEL-H PKR w/HMC LNR HGR.D=6.19" 9-5/8"CSG,47#,L-80 BTC/S0095,D=8.681" -{ 10243' .........---1 11474' 7"MARKE3R JOINT Minimum ID = 2.377" @ —13200' I I 114,91;-1--14-1/2"HES X NP,D=3.813' 3-3/16"X 2-7/8" XO rX 11512' -17"X 4-1/2"BKR S-3 PKR,ID=3.875" 9-5/8"MILLOUT WIDOW(15-07A) 10193'- 10243' 11 I 1 11536' H4-1/2"HES X NP,D=3.813' • IF 11557' 1-I4-1/2"I-ES XN NW,ELLE)TO 3.80"(06/05/10) 4-1/2"TBG,12.6#,L-80 BT-M, .0152 bpf,D=3.958" H 11568' . 11568' 4-1/2"WLE G.0=3.958" TOP OF 4-1/2"LNR 11577ir7.-.......,.. 1 11570' --16"LNR TEE BACK,D=5.25" --.--....---'s- 11577" -17-X 5"BKR ZXP LTP w/LNR HGR.D=4.40" \ 11590' -(5"X 4-1/2"XO,D=3.860" 7"LNR,26#,NT-80 NSCC,0383 bpf,D=6.276" - 11724' 7"MILLOUT WINDOW(15-07C) 11724'- 11736' TOP OF 3 1-2X3 3-16X2 7-8-u LNR/CMT 11900' 11904+` -13.70'DEPLOY SLV ID=3.00" 3-1/2"LNR, #,L-80 STL,.0087 bpf,ID=2.992" -{ 12360' 4-1/2"PKR WHIPSTOCK(XX/XX/XX) -I 12370' 4-12"LNR,12.6#,L-80 BT-M,.0152 bpf,D=3.958" -1 ^12370' I 12360' H3-1/2"X3-3/16'XO,D=2.786' FE RFORATTON SUMMRY 4-1/2"MLLOUT Y OOW(15-07D)12370'-12379' REF LOG: ON XX/XX/XX ANGLE AT TOP FEW:°@' Note:Refer to Production CB for historical pert data SIZE SFF INTERVAL Opn/Sqz DATE SOZ 1 / 113200' -I3-3/16'X 2-7/8'XO,13=2.377" / I ? HPUP.Tw/RA TAG 1 3-1/4"LNR,6.6#,L-80 TCI1,.0079 bpf,D=2.85" --1 --13200' PBTD - 2 'B"LNR,6.5#,L-80 STL,.0058 bpf,D=2.441" - 15450° `' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY t1NT 10/01/85 N1ES ORIGINAL COMPLETION 08/14/15 JMD BIILT FROPC.•:' ' WELL: 15-07I-' 02/25/94 D-9 SIDETRACK(15-07A) _ — PE2MT No: 2030970(2100400)( ) 08/15/00 CDR-1 CTD SIDETRACK(15-07B) AR No: 50-029-21166-03(0 ) 07/08/03 N2E S CTD SIDETRACK(15-07C) SEC 22,T11 N,R14E, 1527'RI_&1354'ANL I 06/15/10 NORDIC 1 CTD SDTRACK(15-07CL1) ! XX/XX/15 CTD SDTRACK(15-07D) BP Exploration(Alaska) 1 r - - --1 ih 1 1 111.111 \01h. iess. 'el II 7 \ 1 V 5 \ I a i i U U \ I 1 ar 1 e N 1 11 01 I Ill / 1 1 1111 4.0 ' i k ... �" • •1 ►C� : . l■ ma a- t N I g 3 14. 011 I'm i i it $ 44 1 II I III I 1 Ur 1 Q r►' i I 0 1 a J "in0 J' Q i LI-- .,..• ; Mk. Q =art�� 1 1 1 O i --7 _ I F I I— u J I awl/opus s J g f 11 i" ul i • . 1,, i i 0— f I 1 Ir I \ o W 1 _ ill. 1.. 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H a a JP /U. ea /Image F-, Jject Well History File Ct. .~r 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. :1œ -- 0 ç 7 Well History File Identifier I Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed I RESCAN DIGITAL DATA ~skettes, No..:L o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: BY: Helen ~CMaria) o Other:: , I O art) ¡ ¡)J)~ Date: . c..JJ () t$"" Isl V r I ; 11 I Date: 0 30 f)!; Isl mD NOTES: Project Proofing BY: Helen ~ I I Scanning Preparation BY: Helen~¡M;ï;) I x 30 = 30+ I ~z = TOTAL PAGES b7 ~ aunt doe~.. not inc-ude cover sheet) iliA.' f\ Date: (; ,"·~rJ fJS7s1 r r t J I I Production Scanning Stage 1 Page Countfrom Scanned File: ¡t;- ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES , Heien ~ Date:C'" 30 Stage 1 BY: If NO in stage 1 page(s) discrepancies were found: YES NO , ~ /s/ NO m~ BY: Helen Maria Date: Isl 11111111111111 11111 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned I BY: Helen Maria Date: Isl Comments about this file: Quality Checked 1111111111111111111 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 • Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue ~J~ " ~ 7 Anchorage, Alaska 99501 ~ ~, ~ 5.. ©~l Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 nata~ 01/OS/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-016 2042570 50029206960200- NA Sealed NA 15-028 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-046 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-O6A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-O8C 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-116 2041460 50029206530200 NA Sealed NA 15-126 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2D50930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-258 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-26B 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-298 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-316 2050860 50029222850200 NA 1.2 NA 3.4 11/11/2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-336 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11 /10/2009 15-366 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-37B 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11!9/2009 15-418 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-428 2090730 50029226240200 NA 1.5 NA 11.9 11!11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-45B 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-486 2051660 50029226350200 NA 1.2 NA 10.2 10!8/2009 15-496 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 ~ • M~~nd+~r, 7h~n~~~ ~ ~C?A From: Preble, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Monday, July 13, 2009 1:23 PM To: Maunder, Thomas E (DOA) Subject: Emailing: 15-07C-203-097-WORK SUMMARY-REV.PDF, H-02A-202-160-WORK SUMMARY-REV.PDF Attachments: ~15-07G2~097-WORK~UMMARY-REV.PDF; H-02A-202-160-WORK SUMMARY- ~ R .PDF ~ ~ ~ 5-a~c-zp3-t~9~-w ~-c)za-2~z-~so-wQ ~ltK St1MP91~RY-RE,.~c SUMMA~Y-R~V.. Tom, Sorry for the error. E-26a was correct and the attachments contain the corrected data for H--02A 202-160 and 15-07c 203-097. Glad you are s~ill reading everything. Tk~e mess~ge is ready to be sent with the following file or link attachments: 15-07C-2~3-097-WORK SUMMARY-REV.PDF H-02A-202-160-WORF~ SUMMARY-REV.PDF Note: `I'o protect against computer viruse5, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. «15-07C-203-097-WORK SUMMARY-REV,PDF'» «H-02A-202-160-WORK SIJI`?MARY-REV,PDF» Page 1 of 1 Maund~r, ?hQmas E (DOA) ~'~:'~~~~~~' `~U! `" ~' Z~~~~ ~rorr~t Maunder, Thomas E (~OA) Sent: Monday, July 13, 2009 90:19 AM To: Ga~ Preble (SA1C) Subject: E-26A (197-141), H-02A (202-160), D~ 15-07C (203-097) Gary, 1 am rev~ewing the 4p4s for the recent Furmanite st~~ting head r~pairs on these wells. Operations ~umrr~ri~es wEre attaeh~d howEV~r it appears, for the most part, that the summaries are iden#ical. The same surrimaries arE attached to all 3 40~5 for activities 5tated to occur May 18 - June ~, 2009. Identical operations are described for M~y 7- May 17 f~or pS 15-07C and E-261~. There ~rt some uniqu~ activities d~scribed at the b~gir~ning Af pS 15-07C and the end of H~02A. Pd appreciate your recqnciling these reports. While I can under~tand similar overall operations, it is not valid for the operations ta agree down to the individual pressure readings or water level soundings in the cetlar, Thanks in advan~. Tom lulaunder, PE AOGCC STATE OF ALASKA : '~ ALAS OIL AND GAS CONSERVATION COMM~ON REPORT OF SUNDRY WELL OPERATIONS ~~~~ ~~ 1. Operations Abandon ~ Repair Well Q Plug Perforations ~ Stimulate~ Other ~ Furmanite Wrap Performed: Alter Casing ~ Puli Tubing ~ Perforate New Pool ~ Waiver~ Time Extension ~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re~nter Suspended Well ~ 2. Operator BP Expioration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: De~lopment ~ Exploratory [-` 2o3-os~o 3. Address: P.O. Box 196612 Stf'8t1g1'BphIC ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21166-03-00 7. KB Elevation (ft): 9. Well Name and Number: 57.77 KB PBU 15-07c 8. Property Designation: 10. Field/Pool(s): ADLO-028307 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 15250 feet Plugs (measured) 11568' true verticai 8724.17 feet Junk (measured) None Effective Depth measured 15159 feet true vertical 8724.31 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 SURFACE - 80 SURFACE - 80 1490 470 Surface 2395 13-3/8" 72# L-80 SURFACE - 2395 SURFACE - 2395 4930 2670 Production 10193 9-5/8" 47# L-80 SURFACE - 10193 SURFACE - 7553 6870 4760 Liner 1710 7" 26# NT-80 10014 - 11724 7463 - 8392 7240 5410 liner 3674 4-1/2" 12.6# L-80 11570 - 15244 8392 - 8724 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 11568' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BKR S-3 PKR 11512' 7"X5" BKR ZXP LNR TOP PKR 11577' 0 0 ~ o RECEIVED 12. Stimulation or cement squeeze summary: ~ ~n~t~l~~~ ~~l~l-F3~ JUN 3 200~ ~nt ~ t t d d erva rea (measure s e ): ~"~~ Alaska Qil ~ Gas Cans. Commission Treatment descriptions inciuding volumes used and final pressure: An~1~pt~~~~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Weli Class after oroposed work: Copies of Logs and Surveys Run Exploratory ~ Dev~elopment ~ Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~ WAG ~ GINJ ~ WINJ ~ WDSPL ~`" 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary P.eble Title Data Management Engineer Signature Phone 564-4944 Date 6/29/2009 tS~'~ JUL ~ ~ 1D09 Form 10-404 Revised 04/2006 ~,y submit Original Only ~-~-~ ~~~ ~`~,~ _~-~:~~ <„~,. 15-07C 203-097 PFRF ATT~4CHMENT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 15-07C 7/7/03 PER 12,910. 13,110. 8,763.97 8,764.45 15-07C 7/7/03 PER 15,030. 15,120. 8,721.87 8,723.84 15-07C 7/7/03 PER 14,780. 14,960. 8,723.89 8,720.4 15-07C 7/7/03 PER 14,690. 14,760. 8,730.2 8,725.02 15-07C 7/7/03 PER 14,420. 14,560. 8,737.2 8,732.77 15-07C 7/7/03 PER 14,260. 14,310. 8,744.63 8,742.37 15-07C 7/7/03 PER 14,360. 14,382. 8,740.69 8,739.42 15-07C 7/7/03 PER 13,530. 13,650. 8,754.01 8,754.56 15-07C 7/7/03 PER 13,710. 13,970. 8,753.81 8,752.55 15-07C 7/7/03 PER 13,250. 13,290. 8,761.39 8,759.65 15-07C 7/7/03 PER 13,158. 13,180. 8,763.65 8,763.28 15-07C 7/7/03 PER 13,450. 13,480. 8,754.76 8,754.42 15-07C 7/7/03 PER 13,350. 13,372. 8,756.98 8,756.18 15-07C 7/23/06 APF 12,400. 12,450. 8,748.48 8,751.33 15-07C 7/23/06 APF 12,580. 12,605. 8,754.17 8,754.97 15-07C 10/20/08 BPS 11,568. 15,120. 8,390.8 8,723.84 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~ • ~J~-~~~ DESCI~~PT~UN t3F WORK COMPLET~D l~RWO OPERAT~4NS EVENT SUM~A~Z.Y T/l/O = SSV/50NAC. Ternp=Sl. WHPs post-tA & OA bieed ~furmanite). No AL. Integral insta(le8 on IA, lAP increased 35 pst. SV,WV,SSV=C. MV=C1. IA,OA=QTG. NQVP, 4/28/2009;T1[iq - S51l/11a/VAG. Temp=Sl. Place heater in ceilar (furmanite~. Heater ~placed in WH celiar. ~SV,WV,SSV=C. MV=O. IR,DA-OTG, NOVP, ..... _.... _....,.............,.._...._ ................................................._..._~......~..._...__.._....._.._...._..._._..~............w...._...............~..........,.....,...,....~..._..._......._.........._.. . 4/29/2009;Tl110=SSVl130Nac. Ternp=SI. Man+tor cellar, ~'ake gravel sampls to Arctic ~ Fox (Furmanite}. Integra! on IA. IAP increased 20 psi & OAP was unchartged !overnight. GraveE sample was taken & delivered to Arctic fox. Heater is `installed & eellar gravel has thawed o~t. ~SV, WV, SSV-Clased. MV=Open. tA & CJA=OTG. Ni~VP. . ~.._._...___...__...,_!.._......_.._........_..._ .............r.._._..__........,..................~...,.~.....,........~......................._.. __.,.~_...._.__.,...,.._.....~........~............................. 4I3012009(711/0~ 55VI100I10. Temp= SI. 5uper suck g~avel < 48" ceilar depth {prep for ~furmanite WH repair}. ~do AL. Suqer suck cellar aravel down 26" before hittirt< Icontinus tamorrow. iSV,WV,IAC=G~.OSED. SSV,MVTOPEN. IA,OA=~7G. NOVf'. . _.__._.._.__..._. _.. ...__---~-._.._...._.. ...___---~-__.._..__.......__........--~_._---- ....................~_......_.............._....._.........._......_......._...__...._.,..._._.._.... 5/1l2009~T/U0=5SVl130/10. Temp=St. Super Suck/ ciig gravel to < 48" cellar cfepth ~(Prep for Fumanite WH Repair). Integra{ on IA. AL, disconnec#ed. Installed 24" jcontainment & put cell~r grating back in welt house. Relsased heater that was •in well hause. _.:...._._..__ ............._ ~SV, WV,_SSV=Ciosed. .MV=Open. ]A & C)A=OTG._.NOVP.. .. _....._......_..._...._..........._......._ 5/25/2009>T/l/Q = SSV/310/0+. 'femp = St. Puii cellar grating and remove sornbrero from ~cellar, instali N2 cap (Furmanite wrap}. Aemoved cellar grating and sombrero ~f~am ce€far. . .. .. .. ....... ...:SV, ,WV,.SSV=C. _ MV-O.._.IA, OA=OTG. NOVP. .......~ ..............~...._..:...._._......___,.-•--~._._- -.,_...,.__......._.___.e.___................. 5/26/2~09~1"11/Q = SSV/310/15. Temp = St. Hold upen bleed on OA {Furmanite wrap}. +No Al. line. IA companion valve has integra[ instafied. Assisted Cornpsitech =durin sandblastin SFi. ~urmanite installed e- lass la er of com osite wra . e fo 0 psi m i min 9nto i", held open b1~ed for 7 hours 20 m(n, ~ina1 ~WHPs = ~aSV/310/0. ~ WV, SV, SSV = cEosed. MV = opert. (A, QA = ~TG. ! .................a........._..........~._._. _ ~...._......_ .................._....,..._.._._......__..........,..... _..........................e..............-..........................................._......,........_.. ._..,. __...J-...._._................ 5J26/2009~TIIK7=SSVI3i0/Vac. 7emp=51. Pu3[ cellar graiing & remove sombrero fram ' ce3tar, instail N2 cap (Furmanite wrap}, No Al.. OA FL near surface. OAP ;tfecreased from 0* psi #o Vac since dayshifi. Instatled 20 psi N2 cap on OA. ; Finat T/110=SSV/310120. iSV, WV, SSV=C. MV~O. tA, OA=OTG. NOVP. ... ..: .....................~_....._......~...............~~..........~...........,._.............,w.......:.: .._... :..._.., ..._.~.._.._---..........._...._._.._......._._...... .._..._......__...._.._......._..._.,...._.. 5127/2049;T/IlQ=BSV/~10/4. Temp=Sl. Hold open bleed on OA (Furmanite wrap}. ~40 i AL. r` Continued from day shifE "" Maintained open OA bleed for Furmanite ~cure, ~inal T!I/~=SSV/310I0. fSV, WV, SSV=C. MV=Q. EA, OA=OTG. NQVP. ~ ~ .. .. .................................. .a..,.._..~._.._.._____.,....,......................~...~.._ _..__ e......_. ..~............_.._._.__.........._....._... ...._...... __.._.__,.........._......._.... ........._. ........__ 5I2712009 `TII/O=SSV/310/0, Temp=Sl. F#old open bl~ed on aA {Furmani#e wrap). Mo AL ~ line. EA companion vaEve has in#egral installed, Furmanite insiaEled 1st set af l la ers of com si e wr . Maintain open b{eed on ~A for 12 hr. Final ~ { WHPs=SSVl3t 01Q. ........ - - ~-- - --;..........~....._........._........_......._ ................_......_........_......._....._._..._...._.......___......................_.........~............._.._.._......,...,...,_.._........_.__; 5/2812009;Ti1/4~SSVl310/0, Terr-p=51. Fiold open bleed on OA {for fiurmanite wrap}. No ~ FAL. "` Continued from dayshift *` Maintained an open QA b3eed for 12 haurs. ~ ;WHPs unchanged. Final'f/1/4=.SSV/3~0/0. ~ ~SV, WV, SSV=C. MV~Q. IA, OA=QTG. NOVP, ? : ._ ..........:................_......_....._. ;......._~....._........_.....__. : 5/28J2009 ~ T/!/~=SSVl310%0....Temp=S1.....Ho1d~.o ...__..._._.._..~.........._ ........................................................._._..... ..._.........: ' pen bieed on OA (i4r Furmanite wrap}, tVa ; ~AL. ~`* Continued from dayshif# ** Maintained an open tJA bleed for Furmanite i ;cure. ~ina! TIllO=SSV/31U/0. ; SV, W V, SSV=C. MV~O. IA, OA=07G. NOVP. ; ~ _,. ....... _...._............~._ :. .._._,.._......._.,_........._._~,..._ ...............~_.._.._,__...._.._............__.....__...._..._.....__........._....................._.~_..._......_..._._.__.....____......._._.......; 5/28/2009!T/Vd=SSV/314/0. Ternp=Sl. Haid open bleed on OA j~urmanite wrap). ~to ~ ~AC.. *'Continue frorra night shift"'k Maintain_open UA bleett for Fumanite cure. i SV, WV, SSV=CIosede. MV=Open. 1A&4A=QTG. NOVP. ..__-_. --.___......t......._..__.._._...__.._..____.._..,..._.......__..........._....._..~...._ ..............._........._...._..~,..r_....~..~......~...............~........~.....__._..._----...~..._........ 5J2912009~711/0-5SV1310J4. Temp=S[. Hold open bleed on OA {Furmanite wrap). No ~AL `"Continued from night shift"`* Maintaina~ open ~or Furrnani#e cure. ~inal ~ WHP's~SSV/310ffl. jSV, WV, SSV-CIosed. MV-C3pen. IA & dA=UTG. NOVP. T/!/0=S8V/310/0. Ternp=Sl. Hnld npen bleed Qn {?A {for Furmani#e wrap). N~ AL *t Continued from dayshi€t " Maintained ~n open OA bleed for Furmanite cure. F€nal T/1/OwSSV1310/0. SV, WV, SSV=C. I'u1V=(~. IA, OA=~TG. NOVP. _.._............----.__ ....................._........ ... ... . . .. . .. ......... ........... ..._........._.........._...................... ................._ ... ........,. ..... 1'll/(~= SSV/310/0. ~'emp- S!. Hofd open bleed on OA {~urman'ste vurapj. No AL. "`Cnntinued from night shift** Maintained open bleed for Furmanite cure. Finaf WHPs= SSU/370/0. SV,WV,SS1~= C. MV= O. IA,OA= OTG, NOVP. Tfl/a= 5SV1310/0. Temp= ~I. Shut-in open bleed an OA monitor BUR (Fu~manite Wra~}. No AL, Shut-fn pA bleed and started monitoring BU ,W V to gaug~e. --~ --..._.. - ..._... ......_. _..__. _...._... . . .~...........................,. ..............~.......... a.....,..........................................~...__. __... _ _ _-. _; ' ~.. 5/31/2009iT/1/O=SSV, 31010. Temp: SI. Maniior WHP's, bieed if needed (Furmanite F ~clamp). Na AL. ~ , ~SV, WV, SSV-C. MV=b. IA, ~A=~TG. NOVP. f ~--.........._.~............~...._...._~.~....._..._...._...._._....._...._......_...._~_......_.._._...._ ........ ..........._.....,................_...._...._...._......._..........._........._.........................................,..~ 1 5/31l2009:T/l/0-S5V/31010. 7emp=S1. WHPs (~urmanite clam}~). 1Vo AL. WHPs ~ i #unchanged overnight. Furmanite wrap looEcs ood, d to the to~ach. j ' ~SV, WV, SSV=Closed. = pen, A~ . N . ; ~ ...... ................_._...__... .._........:.......~.~............._..._.... ~...._........................................_...._.... ...._....d........~....~..~.~_.........._.......,........_........ ._..........~........ ......._... ....._................~.....; ! 6/712009;TI1/0 5SV13i0/0. Temp= SI. WHP's, (bleed if needed (keep < 1Q psE) } ' ~(~urmanlie clamp). hleater installec3 on weA & working properly. IVo AL, ~ ~ j ;fntegra{ insta![ed on IA, TP, IAP,OAP unchanged overnight. ; ~ i ;SV,INV,SSV=C. ,MV=fl. lA,OA= Oi'G. NOVP ~ J ~ ^ ~ ~ _..,_.._a......_.~._ ._._..~...._.._._......_ .... ....................._...._...._........_~__..............._....._~_._....._..._......_........._...._........._.......................... T/iI~=SSV/8d01O. 7emp= Sl, WHP's, bleed if needed (keep < td psi), check heater still in celfar (Furmanite clamp). TP unchanged, 1AF increased 34 psi, OAP unchanged overnight. Heater instaEled correctly in cellar. No visibie signs oi seepage #rom Furmanite clarr~p. SV,SSV,WV= CEosed. MV~ Open. IA,OA_ OTG. NOVP. ___ ........... .....__.,_.._..._......--___.._................_..........~................_._._.....__._...._..........~......_.._....,._.._....--.__..__._._._._...........__..._..,._.........- _....._..._...._. ~6/312409;TlIifl = SSV/340/0. Temp ~ S!. Monitor WHP's, bteed if needed {keep < 14 ;psi), chee~ heater still in cellar (Furmanite clamp}. No AL. 2" infegrat inskafled ;on iA. No visible leaks on SH. Fieater is v~rork9ng properly. ;SV, WV, 5SV = C. MV W p, IA, OA = OTG. NQVP. ....._...._.._..,...~ ........................~,,...~._.._._.,...__.........__.._......._............._. ~........_._............._.............._....._......,..............._..._........................__.......................................,_...._..,......., 6l4I2409~TIV0 = SSV/340/0. 7emp = St. Monitor WFiP's, blee~i iE n~eeded {keep < i0 I ps~}, check heater stii! in cellar (Furmanite clamp). i~o AL. 2" integral instailed 1on IA. No visibi~ I~aks on SH. Heater is working properly. FSV WV SSV ~ C. MV ~ O. 1A, OA = U7G. NOVP. _I _.... ' _' _.._..,--.:.- ....................... ~. _....... .,.,..._.._......~__....__~._..._................._................._........_..........._._....__......_..__............................~......... 6/5/2009; T/l10=1901340l0+. Terr~}~ SI. *PASS~D* MIT-OA ta 7 200 psi w/ diesel i{~urmanite Wrap). No Al.. OA Fl. near surface. Increased OAP from 0+ psi to ;120b nsi usinn 2.75 bbl of diesel. ~AP losf 6{3 ps n t e~rst mtn. an psi s psi to ~+ psi in ~ u m~n, n~o visibie ieaKS netectea arouna or on rurmantte wrap ~on i~f+7~onifore or 3fl min, wit no change in s, inal WHPs= [ 190I340/0+. ;SV,WV= C. SSV,MV~ O. IA,OA= {JTG. N~VP, ~ i .....__...._..~.,......__......._........- ......_.~~....._....._..._........_ ................_........,_...___-_...__:._.~.............:_...............__..............._............_..._..........._.......__ • • _-~- ~= _~ .,~~.~ ~.r. MICROFILMED 03/0112008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:1l.aserFiche\C~rPgs_InsertsiMicrofilm Marker.doc 09/10/07 Scblumbepger NO. 4406 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth 5'GANNED SEP 1 8 2007 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 WII J b# L D . f D t BL Field: Prudhoe Bay Endicott C I CD . e 0 og I eSCrlpllon ae o or 17-14 N/A JEWELRY/SBHP HMI\- J~4 -, ¿'(A 08/17/07 1 MPC-10 11767137 MEM INJ PROFILE I )Tl': /A¡c,_f")/<" 08/13/07 1 17-01 11824337 SBHPS/JEWELRY LOG 1'l1(', - OS~ 08/15/07 1 P2-30 11686776 PRODUCTION PROFILE I C) ~ - ("')'1.~ 08/25/07 1 L1-31 11865639 LDL IA~ ,- C- 08/14/07 1 P2-10 11846804 PRODUCTION PROFILE ¡crð' -t'A~ 08/17/07 1 17-03A N/A JEWELRY/SBHP ¡ClF;J-- /::u /_ 08/17/07 1 C-26 11824342 LDL Iq'ÍÇ' - IL.J~ 08/22/07 1 15-07C 11594517 SBHP SURVEY .;:)l"'\ "'? - 0£1 <:¡ 08/23/07 1 D-04B 11591451 SBHP SURVEY ;Jö3 - 1/ D 08/24/07 1 P2-24 11865643 PRODUCTION PROFILE 10I'7( - ('\(")'1< 08/21/07 1 P2-03 11855502 PRODUCTION PROFILE ''1~ - fY../4 08/19/07 1 09-44 11855501 SBHP/JEWELRY IO¡(.... - Q(~ 08/16/07 1 09-23 11824337 SBHP/JEWELRY ¡ ~ - f.t..., -.. 08/16/07 1 2-52/S-41 11846807 PRODUCTION PROFILE j~~ -()~~ 08/18/07 1 F-08A 11638646 USIT :J(}øq -0 06/28/07 1 02-16C 11628790 SCMT d(')1--0 '7'15 08/24/07 1 L2-32 11695060 RST I )"'I"I'. I~"=\o _I~~ .... I.'" Ii.¡ (,. OS/23/07 1 1 L5-09 11492259 RST /Cit'! - I::J'-I -- I~UI":J. 11/11/06 1 1 02-12B 11767132 MCNL EJO'.} -",""",,~ .. I~/.... 06/21/07 1 1 18-09B 11366500 MCNL 1C\'Sr-- (Y":}* :# 1...:;-4 IC¡ 10/23/06 1 1 G-14A 11485777 MCNL 1t:1~ -()~~ 'it 15'-/Q-6 11/27/06 1 1 05-20B 10942220 MCNL ::J{')L/ _ ~~¿I it- 1..c;-<"/1J / 06/26/05 1 1 . PLEASE ACKNOWLEDGE RECEIPT BY SI~'~!~~I~ rp~I~ONE COPY EACH TO: BP Explor~tlon (Alaska) Inc. ii,'" ii,,, ß ;L..,,8 '\!'i ìl",~~ ,1,.,,1i Petrotechßlcal Data Center LR2-1 1.1,.,..,. ,. 900 E. Benson Blvd. Anchorage. Alaska 99508 ('CD ", d ')[)fì7 ,)l.1 ). ' . u Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 -..~ AAiJ2, "~": ATTN: Beth I Received by: Å...--- Date Delivered: "j.. "," f¡ '>,," Ci)P~ \,,()IIIIIÜ,,3ioR }\!j~:~~~h\'H Î".,lj! \'.~ \:H!,':' ,J" ",' ",-"'-- . 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Ope rat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: . STATE OF ALASKA _ ALA Oil AND GAS CONSERVATION COM~ON REPORT OF SUNDRY WELL OPERATIONS o o o RECEIVED SEP 2 7 2006 P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Stimulate 0 A~ Oth¡¡¡. ~ W· 0 T· axtSKa .utl Gas CaRS. Cemmissio alver Ime enslon Re-enter Suspended Well []Anchorage 5. Permit to Drill Number: 203-0970 3. Address: Exploratory Service 6. API Number: 50-029-21166-03-00 57.77 KB PBU 15-07C ADLO-028307 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool 8. Property Designation: Total Depth measured true vertical 15250 8724.17 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 15159 feet true vertical 8724.31 feet Casing Length Size MD TVD Burst Conductor 80' 20" 91.5# H-40 Surface - 80' Surface - 80' 1490 Surface 2395' 13-3/8" 72# L-80 Surface 2395' Surface - 2395' 4930 Production 10193' 9-5/8" 47# L-80 Surface - 10193' Surface - 7553' 6870 Liner 1710' 7" 26# NT -80 10014' 11724' 7463' - 8392' 7240 Liner 3674' 4-1/2" 12.6# L-80 11570' - 15244' 8392' - 8724' 8430 Collapse 470 2670 4760 5410 7500 Perforation depth: Measured depth: 12910' - 15120' True Vertical depth: 8764' - 8724' Tubing: (size, grade, and measured depth) Sf...· ~ t,.\N~r y '4.tr,.J\c1, ,.J'_....-- 4-1/2" 12.6# L-80 t· ¡ é. Surface - 11569' Packers and SSSV (type and measured depth) 7"x4-1/2" BKR S-3 11512' t*, 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft OCT 032006 Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 501 203 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 29923 0 0 6223 3 0 15. Well Class after Droposed work: Exploratory Development 16. Well Status after proposed work: Oil ,r;¡ Gas WAG Tubing pressure 1114 1157 13. Service Contact Gary Preble WINJ WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature Title Data Engineer Phone 564-4944 Date 9/22/2006 Form 10-404 Re.· ed 04/2004 () R \ G \ L Submit Original Only . . ,... C T ,. 15-07C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY MEM GR/CCL/ Adperf. CTU #9. MIRU. RIH with PDS logging tools and 2.75" nozzle. Log interval 12,900' - 12,200' ctmd. Flag pipe at 12,553'. POOH. Good data - +1 (tied into Sperry Sun MWD 6/26/2003). MU and RIH with SLB 2.5" - - HMX - 10.5gm - EH=.32" - Pen = 25.2" TCP guns. Tie in at flag and Perforate:12,580' - 12,605', POOH and MU gun run # 2.RIH. **** Continued on WSR **** #9 w/1. 75" CT. **** Continued from 07/22/06 WSR **** Tie in at flag and perforate 12,425 - 12,450' POOH and MU gun run #3. RIH. Tie into coil flag and perforate 12,400' - 12,425'. POOH. Well left shut in and freeze protected with 50/50 meth. Perform weekly BOP test. RDMO. Notify DSO of well status and request to POP. ***Job Complete*** FLUIDS PUMPED BBLS 29 50/50 meth. 205 1 % filtered KCL 234 TOTAL . . WELL LOG TRANSMITTAL [) L.' , .', å,' '.- ~\ I ~ ~"'Ì: ~ \ I \. "r ,. ProActive Diagnostic Services, Inc. AUG 2 9 ZUUG t\laska Oil & Gas Cons. Commission Anchorage To: AOGCC Records Department 333 W. 7th Ave Suite 100 Anchorage. Alaska 99501 RE : Cased Hole/Open Hole/ Mechanical Logs and / or Tubing Inspection(Caliper / MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 EDE Disk D.S. 15-46L 1 21-Jul-06 i~/(Y?t- ;)6'-1-103 é)ó3 -oij) I ( I D'T <.0 1] 2J 3) 4) 5) 6) 7] Coil Flag Æ Coil Flag * ,?lQO..6e. AJùte - b.~ l~~_L/~t-1 - ()\¡{ "'D\å; \'QJ Î8cJC\ - \-t.e.- AP, "* '¡~ wrO() - i\- <'Skødo) \,0 a -$'()-O~ -8Q<O"~--~b §~A.NNED AUG 3 0 2D05 EDE Disk D.S. 15-07C 22-Jul-06 Print Name: cpL Q/JI r~ítlA (/ /Ì1-ß(At(rl-P/(,1 Date: "i5' I f'Jq I f¡¿, Signed: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: E..[)_SANCHºßl'-G.É.@~tEMO_~.YhOG.£.9.M WEB SITE : Y't.WW.M~MOB..Y_'=9_G.cQr~ C:IDoclllllclIl< Dlld ScUiIl~,\I'DS ^"chom~c - M/'LIDc,klo >ITnm,,,,il_ Ori~illDl.doc e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 r3l0~ RE: MWD Formation Evaluation Logs 15-07C, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 15-07C: LAS Data & Digital Log Images: 50-029-21166-03 dD3-0C,1 1 CD Rom lf~ !ì/ ~I Ov '6 f~~~_ DATA SUBMITTAL COMPLIANCE REPORT 8/1/2005 Permit to Drill 2030970 Well Name/No. PRUDHOE BAY UNIT 15-07C MD 15250 -- TVD 8724 /' Completion Date 7/8/2003"-- -------------- --~-- REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES, ASI, CNL Well Log Information: Log/ Electr Data Digital Dataset ~! 12'~.T2'P __~~~':!'"t Number Name L1'Rpt D Asc Directional Survey ¥D Asc Directional Survey 4 11974 LIS Verification i D 11974 Induction/Resistivity D 11974 Density ED D 11974 Neutron ~ED D 11974 Rate of Penetration ,------ - -- - -- -- Well Cores/Samples Information: Name Interval Start Stop Operator BP EXPLORATION (ALASKA) INC SpfAJ. ~~J~ ~~j API No. 50-029-21166-03-00 Completion Status 1-01L Current Status 1-01L UIC N Samples No Directional surve~ (data taken from Logs Portion of Master Well Data Maint) - Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments final 11690 15250 Open 7/24/2003 MWD final 11690 15250 Open 7/24/2003 1,3,4,5 11723 15250 Open 9/16/2003 1,3,4,5 11723 15250 Open 9/16/2003 GR, EWR4, CNP, SLD, ROP 1,3,4,5 11723 15250 Open 9/16/2003 GR, EWR4, CNP, SLD, ROP 1,3,4,5 11723 15250 Open 9/16/2003 GR, EWR4, CNP, SLD, ROP 1 ,3,4,5 11723 15250 Open 9/16/2003 GR, EWR4, CNP. SLD, ROP -- Sample Set Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 8/1/2005 Permit to Drill 2030970 Well Name/No. PRUDHOE BAY UNIT 15-07C Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21166-03-00 MD 15250 TVD 8724 Completion Date 7/8/2003 Completion Status 1-01L Current Status 1-01L UIC N ADDITIONAL INFORMATION Well Cored? Y 0 Chips Received? -Y / N Daily History Received? <IN Q)N Formation Tops Analysis Received? ~ .- ---- --------- Comments: ~____c __________~ " \ Compliance Reviewed By: ~J Date: ~*~J - --------- - ) ) ¿) C\ -:2 .- /~--.,. C· ":::::I- CliO Lj 1 I -if\ \ Q'1 Ll WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 J\nchorage,Alaska September 9,2003 RE: MWD F offilation Evaluation Logs 15-07C, AK-MW-2523315 1 LDWG fOffilatted Disc with verification listing. API#: 50-029-21166-03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro- Teclmical Data Center LR2-1 900 E. Benson Blvd. J\nchorage, Alaska 99508 Date: ~--..... Signed:\<C \_-",~ - \/'-. ~ \--LC~.c::)v'~ t~ECEIVED c n- 1 t. vc¡-J I 0 2003 ,öJaska o;¡ 8. Gas Cons. Coífìmi!eioo Anchor'tt.ge . :--.,~. c-- ~.'\ \~ 'v':\ '\\(\. ~ ') STATE OF ALASKA ) ALASKM ÖIL AND GAS CONSERVATION COMhll.'SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: IBI Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ D WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1527' SNL, 1354' EWL, SEC. 22, T11N, R14E, UM Top of Productive Horizon: 2997' NSL, 1403' EWL, SEC. 14, T11 N, R14E, UM Total Depth: 5173' NSL, 2906' EWL, SEC. 14, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 677294 y. 5959986 Zone- ASP4 TPI: x- 682505 y- 5964636 Zone- ASP4 Total Depth: x- 683953 y- 5966848 Zone- ASP4 18. Directional Survey IBI Yes 0 No 21. Logs Run: MWD, DIR, GR, RES, ABI, CNL 22. CÄ~IN~~!' ' ~IZE"," 20" 13-3/8" 9-518" One Other 5. Date Camp., Susp., or Aband. 7/8/2003 . 6. Date Spudded 6128/2003 7. Date T. D. Reached 7/412003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 57.77' 9. Plug Back Depth (MD+TVD) 15159 + 8724 Ft 10. Total Depth (MD+TVD) 15250· + 8724 Ft 11. Depth where SSSV set (Nipple) 2186' MD 19. Water depth, if offshore N/A MSL ;,':, ",,'/1: I,': ":, I",',; I : I·I~,,';II,I'I'" ~',I:',·' '11,',"1 ,...,,'~~pç: H-40 L-80 L-80 NT -80 L-80 CASING, LINER AND CEMENTING RECORD ,,1,'1 'SE¡TING:r~,:DER~,hf"; "1,,;, ';;,":':I>r¡,:~ø:C,~::;:",I:;¡I,'~';:'¡; TOP':¡"i,: :":~;:Ba¡':ròM," ' ,,' :,I$'IZE1::' ',. ' Surface 80' 30" Surface 2395' 17-1/2" Surface 10193' 12-1/4" 10014' 11724' 8-1/2" 11570' 15244' 6-1/8" ,<::,:",': " ',:" :---:,:,,': ,:',Wt::' P. .'1:. ~'é:T':' 1,'1 I' '" 91.5# 72# 47# 26# 12.6# 7" 4-1/2" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-1/2" Gun Diameter, 4 spf 2-1/2" Gun Diameter, 4 spf MD TVD MD TVD 12910' -13110' 8764' - 8764' 14260' -14310' 8745' - 8742' 13158' -13180' 8764' - 8763' 14360' -14382' 8741' - 8739' 13250' - 13290' 8761' - 8760' 14420' - 14560' 8737' - 8733' 13350' - 13372' 8757' - 8756' 14690' - 14760' 8730' - 8725' 13450' -13480' 8755' - 8754' 14780' -14960' 8724' - 8720' 13530' - 13650' 8754' - 8755' 15030' - 15120' 8722' - 8724' 13710' - 13970' 8754' - 8753' 15050' - 15070' 8722' - 8723' 26. Date First Production: July 16, 2003 Date of Test Hours Tested PRODUCTION FOR 8/1/2003 5.2 TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Press. 265 24-HoUR RATE 1 b. Well Class: IBI Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-097 13. API Number 50-029-21166-03 14. Well Number PBU 15-07C 15. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool 16. Lease Designation and Serial No. ADL 028307 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) ~A)~ /1" 7z.Ýt"Þ'JP '8, 0/10 t' 7Vr::> 1"',,I":,lil:';::'~\¡'::'~,'¡', '<I',~""I" ,1'1 ",' :1 ,:I':~ ::AM.oUNIT:R( ~t:EDI' ..:' '..,':,.!,~ 2000 sx Poleset 1850 sx PF 'EI 400 sx PF IC' 500 sx Class 'G', 300 sx PF 'C' 305 sx Class 'G' 449 sx Class 'G' II", I .... I I I :24;,"" /" ',' ,"\ SIZE 4-1/2", 12.6#, L-80 ::..... ·T~åING" RECORD' DEPTH SET (MD) 11569' PACKER SET (MD) 11512' , ~ ';,; " ',' ',' I, , :'; ," ' , ," ,,~ ".1>\. 'ê::~¡p;FRACTLJREi.ÇE~ENT··§Q. tI. EEZ.E,'..~TC..·· .. I" I I, " I , " : ' ' .,;' ,'I " , , I" ' ' " ~, , " , ' " I " ' ,; " ,'. I DEPTH INTERVAL (MD) 2200' PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-Bsl 2,445 Oll-Bsl 27. GAs-McF 4,525 GAs-McF W A TER-Bsl -0- W A TER-Bsl AMOUNT & KIND OF MATERIAL USED Freeze Protect with 155 Bbls of Diesel CHOKE SIZE 840 GAS-Oil RATIO 1,851 Oil GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach sèpårate §heet,it necessary). Submit core chip$.; j[none, state "none". . None j :---:-.~~::}~~l 7· ?_~_ / 1 .~.. Form 10-407 Revised 2/2003 nPtG1t\fAl_ CONTINUED ON REVERSE SIDE RBDMS BFl AUG 1 1 ïon') (, jC 28. GEOLOGIC MARKE~, ) 29. )FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 21TS 12028' 8633' None Zone 1 B 12230' 8712' TDF 12383' 8747' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed TerrieHubble ~~ .«U~ Title Technical Assistant Date 08-0 S-Q3 PBU 15-07C 203-097 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Phil Smith, 564-4897 Permit No.1 Approval No. 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. 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). 0 R \ G \ N A L ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 Legal Name: Common Name: Test Date 6/27/2003 LOT 15-07 15-07C Test Type Test Depth (TMD) 11,720.0 (ft) TêstDepth(TVQ) 8,500.0 (ft) AMW 8.50 (ppg) SÚrfãceEPrê$sLlrê Léak.."OffPréSSl,Ire(ßHp) 675 (psi) 4,428 (psi) EMW 10.03 (ppg) .~ -'-- Printed: 7/2212003 8:48:35 AM ) BP EXPLORATION Operations Summary R.eport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-07 15-07C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/24/2003 Rig Release: 7/8/2003 Rig Number: Spud Date: 8/16/1984 End: 7/8/2003 Date From- To Hours Task Codë NPT Phase Descri ptionof Operations 6/23/2003 10:00 - 12:00 2.00 MOB P PRE Held PJSM - Rig Down Rig Floor And Can-Rig Top Drive- Load Up Camp Shop And Mud Pit Pump Room Complex 12:00 - 13:30 1.50 MOB P PRE Held PJSM - Bridle Up Traveling Blocks - Lower Cattle Shoot 13:30 - 14:30 1.00 MOB P PRE Held PJSM - Remove Pins From A-Legs And Lower Mast 14:30 - 15:30 1.00 MOB P PRE Held PJSM - Move Sub Base Off DS 18-03B And Stage At End Of Pad 15:30 - 18:30 3.00 MOB P PRE Held PJSM With Security And Peak - Take Camp, Shop, And Mud Pit Complex To DS-18 Road Sub Base To DS-15 18:30 - 21 :00 2.50 RIGU P PRE Held PJSM - Lay Matting Boards And Herculite Around Well Cellar - Attempt To Position Rig Had To Remove Needle Valve Connections, And Flange - Reposition BOP Stack - Spot Sub Base Over Well 21 :00 - 22:00 1.00 RIGU P PRE Held PJSM - Raise Mast And Pin - Raise Cattle Shoot 22:00 - 23:00 1.00 RIGU P PRE Held PJSM - Lay Herculite - Position Mud Pit Pump Room Complex 23:00 - 00:00 1.00 RIGU P PRE Held PJSM - Position Camp Unit - Connect Service Lines 6/24/2003 00:00 - 01 :00 1.00 RIGU P PRE Held PJSM - Lay Herculite For Cuttings Tank - Position Tank And Berm - Remove Bridal Lines From Traveling Blocks And Secure In Mast - Hook Up Utilities Between Pit Complex And Sub Base - Rig Up FloorArea And Can-Rig Top Drive - Spot Mud Lab And Geologist Unit 01 :00 - 01 :30 0.50 WHSUR P DECaMP Hold Pre-Spud Meeting With All Personal Regarding Operations For Well Work Rig Accepted For Well Work On OS 15-07C At 01 :00 Hours On 06/24/2003 01 :30 - 02:00 0.50 WHSUR P DECaMP Held PJSM - Take On Sea Water In Pit System - Install Secondary Annulus Valve On Well Head - Record Tubing Pressure At 15 Psi. And Annulus Pressure At 0 Psi. 02:00 - 03:30 1.50 WHSUR P DECaMP Held PJSM - Rig Up DSM Lubricator And Pull BPV - Rig Up To Tree And Well Head To Circulate Out Freeze Protection. 03:30 - 08:30 5.00 WHSUR P DECaMP Held PJSM - Test Surface Lines To 3,500 Psi. (Test Good) - Circulate Out Freeze Protection Thru Choke Taking Returns To Cuttings Tank - Fluids Out Of Balance - Circulate To Balance Out Fluid. CBU at 5 bpm and 650 psi. 0 psi on tubing and annulus. 08:30 - 11 :00 2.50 WHSUR P DECaMP Dry rod TWC. Test from below to 1,000 psi. Blow down surface equipment. RID circulation lines. N/D tree and adapter flange. Verify 4 1/2" NSCT threads. Required 7 1/2 turns to M/U. No galling apparent. 11 :00 - 14:30 3.50 BOPSUR P DECaMP N/U BOPE. Install flow riser, turnbuckles, and mousehole. 14:30 - 17:30 3.00 BOPSURP DECaMP Test BOPE to 250 psi low and 3,500 psi high. Test witnessed by Lou Grimaldi of the AOGCC. 17:30 - 18:30 1.00 WHSUR P DECaMP R/U DSM and pull TWC with lubricator. 18:30 - 20:30 2.00 WHSUR P DECaMP M/U landing joint and screw into tubing hanger. BOLDS. Pull tubing hanger to floor with 125K up weight. 20:30 - 21 :30 1.00 PULL P DECaMP RlU casing equipment. UD tubing hanger. RlU control line spooler. 21 :30 - 23:00 1.50 PULL P DECaMP UD 41/2", 12.6#, L-80, NSCT tubing to the SCSSV (52 joints). 23:00 - 23:30 0.50 PULL P DECaMP UD SCSSV, RID control line spooler. Recovered 51 SS control line bands. 23:30 - 00:00 0.50 PULL P DECaMP Continue UD 4 1/2" tubing. 6/25/2003 00:00 - 01 :00 1.00 PULL P DECaMP POOH, UD 41/2" tubing from 9,623' to 7,730'. Printed: 7/22/2003 8:48:44 AM ) ') BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-07 15-07C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/24/2003 Rig Release: 7/8/2003 Rig Number: Spud Date: 8/16/1984 End: 7/8/2003 Date From -To Hours Task Code NPT Phase Description·of Operations 6/25/2003 01 :00 - 09:00 8.00 PULL P DECOMP CIO handling equipment. LID 31/2",9.2#, L-80, NSCT tubing from 7,730'. RID 3 1/2" handling equipment. Clear and clean rig floor. Install wear bushing. 09:00 - 11 :00 2.00 STWHIP P WEXIT PJSM. P/U and M/U BHA #1 to 1,049'. 11 :00 - 13:00 2.00 STWHIP P WEXIT Service top drive. Cut and slip 107' drilling line. 13:00 - 20:00 7.00 STWHIP P WEXIT P/U 4" drill pipe from 1,049' to 11,742', (344 joints). Break circulation every 4,000'. 20:00 - 21 :30 1.50 STWHIP P WEXIT Circulate. Pressure test the 9 5/8" x 7" to 3,500 psi for 30 minutes. Record test. 21 :30 - 23:00 1.50 STWHIP P WEXIT Displace well to 8.5 ppg QuickDrilN fluid at 13 bpm and 2,350 psi. Clean out under shakers. 23:00 - 00:00 1.00 STWHIP P WEXIT Pump dry job. POOH with drill pipe from 11,742' to 10,484'. P/U weight 190K, SIO weight 145K, Rot weight 165K Torque 6K 6/26/2003 00:00 - 04:30 4.50 STWHIP P WEXIT POH wi drill pipe from 10,484' to 1,049'. Stand back assembly from 1,049' to 35'. Caliper and LID mills. Clear and clean rig floor. 04:30 - 06:00 1.50 STWHIP P WEXIT PJSM. M/U Whip Stock assembly (BHA #2) to 110'. 06:00 - 06:30 0.50 STWHIP P WEXIT Upload MWD. 06:30 - 07:00 0.50 STWHIP P WEXIT RIH from 110' to 1,133'. Shallow test MWD tools at 486' at 250 gpm and 350 psi. C/O elevators. 07:00 - 13:00 6.00 STWHIP P WEXIT RIH with drill pipe from 1,133' to 11,742'. Running speed 1 1/2 minutes per stand. Fill pipe at 4,400' and 7,671'. 13:00 - 13:30 0.50 STWHIP P WEXIT Orient whip stock at 20 degrees RHS and set. 13:30 - 00:00 10.50 STWHIP P WEXIT Mill window in 7", 26# casing from 11,724' to 11,743'. P/U weight 190K, S/O weight 145K, Torque 6 -7K. TOW at 11,724', BOW at 11,736'. Recovered approximately 50 Ibs metal cuttings. 6/27/2003 00:00 - 07:30 7.50 STWHIP P WEXIT Mill window / formation from 11,743' to 11,748'. 07:30 - 08:00 0.50 STWHIP P WEXIT Work window. Clean. 08:00 - 09:00 1.00 STWHIP P WEXIT Drop dart and open circ sub. Pump sweep and circulate hole at 12 bpm and 2,100 psi. 09:00 - 09:30 0.50 STWHIP P WEXIT Perform FIT with 8.5 ppg mud to 675 psi surface pressure at 11,720', (8,500' tvd). EMW 10.0 ppg. 09:30 - 13:30 4.00 STWHIP P WEXIT Observe well and pump dry job. POOH from 11,748' to 1,115'. 13:30 - 15:30 2.00 STWHIP P WEXIT LID BHA from 1,115'. Caliper mills and LID same. Clear rig floor. 15:30 -16:30 1.00 DRILL P PROD1 Flush stack and surface equipment. Service wear bushing. 16:30 - 19:00 2.50 DRILL P PROD1 PJSM. M/U BHA #3 to 107'. Upload MWD tools. Shallow test MWD. O.K. Load nuclear sources. Continue M/U BHA to 236'. 19:00 - 20:30 1.50 DRILL P PROD1 P/U drill pipe from 236' to 1,823'. RIH with drill pipe from 1,823' to 2,756'. 20:30 - 21 :30 1.00 DRILL P PROD1 Service top drive. 21 :30 - 23:00 1.50 DRILL P PROD1 RIH with drill pipe from 2,756' to 6,311'. Fill pipe every 3,000'. 23:00 - 00:00 1.00 DRILL P PROD1 Cut and slip drilling line. 6/28/2003 00:00 - 02:30 2.50 DRILL P PROD1 RIH from 6,311' to 11,675'. Break circulation at 9,110'. MWD functioning O.K. RIH to top of window. Break circulation. No response from MWD. Printed: 7/22/2003 8:48:44 AM ) ') BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-07 15-07C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/24/2003 Rig Release: 7/8/2003 Rig Number: Spud Date: 8/16/1984 End: 7/8/2003 Date From- To . Hours Task Code NPT Phase Description of Operations 6/28/2003 02:30 - 04:00 1.50 DRILL N DFAL PROD1 Work with MWD. Work pipe, rotate, pump 20 bbl water sweep, check and confirm all surface equipment functioning. No success reviving MWD. 04:00 - 05:00 1.00 DRILL N DFAL PROD1 POOH from 11,724' to 10,300'. Circulate and test MWD. No success. Drop dart to circ sub, pump dry job. 05:00 - 09:30 4.50 DRILL N DFAL PROD1 POOH with drill pipe from 10,300' to 237'. 09:30 - 11 :00 1.50 DRILL N DFAL PROD1 POH with BHA from 237' to 138'. Function test MWD. No response. Flush tools with water. Remove RAS, download MWD. 11 :00 - 12:00 1.00 DRILL N DFAL PROD1 LID MWD. P/U new MWD tools to 46' and orient. 12:00 - 12:30 0.50 DRILL N DFAL PROD1 M/U BHA from 46' to 107'. 12:30 - 14:00 1.50 DRILL N DFAL PROD1 Upload MWD. Shallow test MWD tools. M/U BHA to 138'. PJSM. Load RAS in MWD tool. M/U BHA to 237'. 14:00 - 16:00 2.00 DRILL N DFAL PROD1 RIH with drill pipe from 237' to 6,778'. Fill pipe every 3,000'. 16:00-17:00 1.00 DRILL P PROD1 Service top drive. 17:00 - 18:30 1.50 DRILL N DFAL PROD1 RIH with drill pipe from 6,778' to 11,539'. 18:30 - 19:00 0.50 DRILL N DFAL PROD1 Install blower hose. Orient to 20 degrees RHS. 19:00 - 19:30 0.50 DRILL P PROD1 RIH from 11,539'. Slide through window, no problems. Ream undergauge hole from 11,738' to 11,748'. Obtain SPR. 19:30 - 00:00 4.50 DRILL P PROD1 Directional drill from 11,748' to 11,910'. ART = 0.59 hrs, AST = 2.05 hrs, ADT = 2.64 hrs P/U weight 180K, S/O weight 140K, Rot weight 160K. Slide I Rotate 162' (11,748' - 11,910') Slide at TF 20 to initiate build / RH turn Flow rate 267 gpm, on btm 2,100 psi, off btm 2,000 psi. WOB 5 - 15 K, ROP 40-60 fph Rotate at 30 RPM Flow rate 267 gpm, on btm 2,100 psi, off btm 2,000 psi. Torque on btm 7,000; Torque off btm 4,000 WOB 5 -15K, ROP 40 - 60 fph 6/29/2003 00:00 - 12:00 12.00 DRILL P PROD1 Directional drill from 11,910' to 12,375'. ART = 3.08 hrs, AST = 5.73 hrs, ADT = 8.81 hrs P/U weight 185K, S/O weight 140K, Rot weight 160K. Slide I Rotate 465' (11,910' - 12,375') Slide at TF 0 to 20 RHS to continue build I RH turn Flow rate 267 gpm, on btm 2,100 psi, off btm 2,000 psi. WOB 15 - 20 K, ROP 50-60 fph Rotate at 60 RPM Flow rate 267 gpm, on btm 2,100 psi, off btm 2,000 psi. Torque on btm 7,000; Torque off btm 5,000 WOB 15 -20K, ROP 70 - 100 fph 12:00 - 15:00 3.00 DRILL P PROD1 Directional drill from 12,375' to 12,562'. ART = 1.0 hrs, AST = 1.14 hrs, ADT = 2.14 hrs Printed: 7/22/2003 8:48:44 AM ) ) BP EXPLORATION Operation$ Sum.rtlary RèpOrt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-07 15-07C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/24/2003 Rig Release: 7/8/2003 Rig Number: Spud Date: 8/16/1984 End: 7/8/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/29/2003 12:00 - 15:00 3.00 DRILL P PROD1 P/U weight 185K, SIO weight 140K, Rot weight 162K. Slide I Rotate 187' (12,375' - 12,562') Slide at TF 60 to 90 LHS to initiate LH turn Flow rate 267 gpm, on btm 2,100 psi, off btm 2,000 psi. WOB 15 - 20 K, Rap 50-80 fph Rotate at 60 - 80 RPM Flow rate 267 gpm, on btm 2,100 psi, off btm 2,000 psi. Torque on btm 8,000; Torque off btm 5,000 WOB 15 -20K, Rap 70 - 100 fph 15:00 - 16:00 1.00 DRILL P PROD1 Circulate at 12,562' at 268 gpm and 1,950 psi. Monitor well. 16:00 - 16:30 0.50 DRILL P PROD1 POOH from 12,562' to 11,445'. Overpull of 40K at 11,880'. 16:30 - 17:30 1.00 DRILL P PROD1 P/U drill pipe from 11,445' to 12,562'. No fill on bottom. 17:30 - 00:00 6.50 DRILL P PROD1 Directional drill from 12,562' to 12,835'. ART = 3.94 hrs, AST = 0.83 hrs, ADT = 4.77 hrs P/U weight 185K, S/O weight 140K, Rot weight 162K. Slide I Rotate 273' (12,562' - 12,835') Slide at TF 160 to 180 RHS to offset LH walk while rotating. Flow rate 267 gpm, on btm 2,100 psi, off btm 2,000 psi. WOB 15 - 20 K, Rap 50 fph Rotate at 80 RPM Flow rate 267 gpm, on btm 2,100 psi, off btm 2,000 psi. Torque on btm 8,000; Torque off btm 5,000 WOB 15 -20K, Rap 70 - 90 fph 6/30/2003 00:00 - 07:30 7.50 DRILL P PROD1 Directional drill from 12,835' to 13,096'. ART = 3.47 hrs, AST = 1.17 hrs, ADT = 4.64 hrs P/U weight 185K, SIO weight 140K, Rot weight 165K. Slide / Rotate 261' (12,835' - 13,096') Trend downward, following geologists instructions, to land at 8,765' tvd (-13,000' md). Will continue at 90 - 90.5 degrees. Slide at TF 160 to 180 RHS, as needed, to reach requested tvd. Flow rate 267 gpm, on btm 2,100 psi, off btm 2,000 psi. WOB 15 - 20 K, Rap 50 fph Rotate at 80 RPM Flow rate 267 gpm, on btm 2,100 psi, off btm 2,000 psi. Torque on btm 8,000; Torque off btm 5,000 WOB 15 -20K, Rap 70 - 90 fph 07:30 - 09:30 2.00 DRILL P PROD1 Circulate a HiVis sweep around at 110 spm and 2,075 psi. 09:30 - 10:30 1.00 DRILL P PROD1 POOH from 13,096' to 11,633'. Overpull of 15K from 12,730' to 12,700'. 10:30 - 11 :00 0.50 DRILL P PROD1 Open circ sub, pump dry job. 11:00-11:30 0.50 DRILL P PROD1 MAD pass with MWD from 11,620' to 11,460' at 300 fUhr. Printed: 7/22/2003 8:48:44 AM ) ) BP EXPLORATION QperationsSummary Røport Rotate at 80 RPM Flow rate 320 gpm, on btm 2,200 psi, off btm 1,950 psi. Torque on btm 7,000 - 8,000; Torque off btm 6,000 WOB 5 - 10K, ROP 80 - 120 fph PROD1 Directional drill from 13,530' to 13,577'. ART = 0.00 hrs, AST = 0.79 hrs, ADT = 0.79 hrs Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-07 15-07C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To Hours Task Code NPT Phase 6/30/2003 11 : 30 - 15: 30 15:30 - 16:00 PROD1 PROD1 4.00 DRILL P 0.50 DRILL P 16:00 - 17:00 17:00 - 18:00 18:00 - 18:30 18:30 - 21 :30 1.00 DRILL P 1.00 DRILL P 0.50 BOPSUR P 3.00 BOPSURP PROD1 PROD1 PROD1 PROD1 21 :30 - 22:00 22:00 - 00:00 PROD1 PROD1 0.50 BOPSUR P 2.00 DRILL P 7/1/2003 00:00 - 04:30 4.50 DRILL P 04:30 - 05:30 1.00 DRILL P 05:30 - 06:30 1.00 DRILL P 06:30 - 00:00 17.50 DRILL P PROD1 PROD1 PROD1 PROD1 7/2/2003 2.00 DRILL P 00:00 - 02:00 Start: 6/24/2003 Rig Release: 7/8/2003 Rig Number: Spud Date: 8/16/1984 End: 7/8/2003 Dëscription of Operations POOH from 11,460' to 237'. PJSM. Stand back BHA #4 from 237' to 138'. Flush MWD tools with fresh water. Remove LWD RAS. Down load MWD data. LID BHA from 138'. Pull wear bushing. M/U test joint. Test BOPE and all related valves to 250 psi low and 3,500 psi high. Witness of test waived by Chuck Scheve, of the AOGCC. Pull test plug. RID test joint. Set wear bushing. PJSM. M/U BHA #5 to 82'. Upload MWD tools. Continue M/U BHA to 212'. Shallow test MWD at 275 gpm and 750 psi. O.K. RIH with drill pipe from 212' to 3,669'. Fill pipe. P/U singles from 3,669' to 5,358'. RIH with drillpipe from 5,358' to 11,615'. Fill pipe at 6,759' and 9,932'. Service top drive. Inspect brakes. RIH with drill pipe from 11,615' to 13,096'. Directional drill from 13,096' to 13,530'. ART = 3.22 hrs, AST = 3.48 hrs, ADT = 6.70 hrs P/U weight 190K, S/O weight 140K, Rot weight 160K. Slide I Rotate 434' (13,096' - 13,530') following geologists instructions. Slide at TF 90 to 180 LHS, as needed, to crest at requested tvd and begin LH turn. Flow rate 320 gpm, on btm 2,100 psi, off btm 1,900 psi. WOB 5 - 10 K, ROP 10 - 50 fph Sliding difficult. Slip I stick making it difficult to maintain consistent weight and differential. P/U weight 190K, S/O weight 140K, Rot weight 160K. Slide / Rotate 47' (13,530' - 13,577') following geologists instructions. Slide at TF 120 LHS, as needed, to maximize LH turn and maintain inclination at -90 degrees. Flow rate 320 gpm, on btm 2,150 psi, off btm 1,900 psi. WOB 5 - 10 K, Rap 10 - 20 fph Rotate at 80 RPM Flow rate 320 gpm, on btm 2,300 psi, off btm 1,950 psi. Torque on btm 7,000 - 8,000; Torque off btm 6,000 waB 5 K, Rap 80 - 120 fph Printed: 7/22/2003 8:48:44 AM ) ) BP EXPLORATION Operations Summary Report Flow rate 320 gpm, on btm 2,150 psi, off btm 1,900 psi. WOB 10 - 15 K, ROP 10 - 20 fph PROD1 Decided to POOH for bit / BHA change due to inadequate dogleg output. Circ,. HiVis sweep at 133 spm and 2,100 psi. Rotate and reciprocate pipe. POOH from 13,671' to 11,709'. Open circ sub, pump dry job, blow down top drive. POOH from 11,709' to 3,856'. Service top drive. Cut and slip drilling line. POOH from 3,856' to 212'. PJSM. Stand back BHA from 212' to 81'. Flush MWD with water. Download MWD tools. LID BHA from 81'. C/O motor. M/U BHA to 81'. Upload MWD tool. M/U BHA to 211 '. Shallow test MWD tool at 250 gpm and 1,000 psi. RIH with drill pipe from 211' to 13,390'. Fill pipe every 3,000 feet. Orient TF to 20 degrees RHS at 11,627' to slide through window. No problems. PROD1 RIH from 13,390' to 13,590', fill pipe, wash down from 13,590' to 13,671'. PROD1 Directional drill from 13,671' to 14,307'.' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-07 15-07C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To Hours Task Code NPT Phase 7/2/2003 02:00 - 02:30 0.50 DRILL P PROD1 02:30 - 08:00 5.50 DRILL P PROD1 08:00 - 10:00 2.00 DRILL P 10:00 - 11 :00 1.00 DRILL P PROD1 11 :00 - 11 :30 0.50 DRILL P PROD1 11 :30 - 14:30 3.00 DRILL P PROD1 14:30 - 16:00 1.50 DRILL P PROD1 16:00 - 17:30 1.50 DRILL P PROD1 17:30 - 18:30 1.00 DRILL P PROD1 18:30 - 19:30 1.00 DRILL P PROD1 19:30 - 20:00 0.50 DRILL P PROD1 20:00 - 00:00 4.00 DRILL P PROD1 7/3/2003 00:00 - 00:30 0.50 DRILL P 00:30 - 00:00 23.50 DRILL P Start: 6/24/2003 Rig Release: 7/8/2003 Rig Number: Spud Date: 8/16/1984 End: 7/8/2003 Description of Operations Circulate a HiVis sweep at 133 spm and 2,100 psi. Rotate and reciprocate pipe to facilitate hole cleaning. Good return of cuttings. Directional drill from 13,577' to 13,671'. ART = 0.00 hrs, AST = 2.27 hrs, ADT = 2.27 hrs P/U weight 190K, S/O weight 140K, Rot weight 160K. Slide 94' (13,577' - 13,671 ') following geologists instructions. Slide at TF 90 -130 LHS, as needed, to maximize LH turn and maintain inclination at -90 degrees. Difficult to obtain required turn rate of 8/100'. BHA yielding dogleg of -4/100'. ART = 4.54 hrs, AST = 10.96 hrs, ADT = 15.50 hrs P/U weight 190K, S/O weight 130K, Rot weight 160K. Slide I Rotate 508' (13,671' - 14,179') following geologists instructions. Slide at TF 90 - 120 LHS, as needed, to maximize LH turn and maintain inclination at -90 degrees. Flow rate 270 gpm, on btm 2,200 psi, off btm 1,900 psi. WOB 15 - 25 K, ROP 20 - 50 fph Good response from bitlBHA. Dogleg (turn rate) of up to -14/100'. Able to nearly complete turn to final azimuth. Printed: 7/22/2003 8:48:44 AM ') ') BP EXPLORATION Operations Summary. Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-07 15-07C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/24/2003 Rig Release: 7/8/2003 Rig Number: Spud Date: 8/16/1984 End: 7/8/2003 Date From ~ To Hours Task Code NPT Phase Description of Operations 7/3/2003 00:30 - 00:00 23.50 DRILL P PROD1 Rotate at 80 RPM Flow rate 270 gpm, on btm 2,200 psi, off btm 1,900 psi. Torque on btm 8,000 - 9,000; Torque off btm 7,000 - 8,000 WOB 15 K, ROP 80 -100 fph Slide I Rotate 128' (14,179' - 14,307') following geologists instructions. Slide at TF 75 - 0 LHS to complete LH turn and begin climb to 8,730' tvd, per geologists instructions. Flow rate 270 gpm, on btm 2,200 psi, off btm 1,900 psi. WOB 15 - 25 K, ROP 20 - 50 fph 7/4/2003 00:00 - 22:00 22.00 DRILL P PROD1 Directional drill from 14,307' to 15,250'. ART = 9.97 hrs, AST = 4.60 hrs, ADT = 14.57 hrs P/U weight 190K, S/O weight 130K, Rot weight 160K. Slide I Rotate 173' (14,307' - 14,480') following geologists instructions. Slide at TF 75 - 0 LHS to complete LH turn and begin climb to 8,730' tvd, per geologists instructions. Flow rate 270 gpm, on btm 2,200 psi, off btm 1,900 psi. WOB 15 - 25 K, ROP 20 - 50 fph Rotate at 80 RPM Flow rate 270 gpm, on btm 2,200 psi, off btm 1,900 psi. Torque on btm 8,000 - 9,000; Torque off btm 7,000 - 8,000 WOB 15 - 20 K, ROP 80 -100 fph Slide I Rotate 770' (14,480' - 15,250') following geologists instructions. Slide at TF 30 RHS to continue climb to crest of 8,718' tvd, per geologists instructions, then slide at TF 180 to toe well bore down toward TD. Flow rate 270 gpm, on btm 2,1500 psi, off btm 1,950 psi. WOB 35 K, ROP 25 - 75 fph Rotate at 1 00 RPM Flow rate 270 gpm, on btm 2,200 psi, off btm 2,000 psi. Torque on btm 8,000 - 9,000; Torque off btm 7,000 - 8,000 WOB 18 - 22 K, ROP 80 -120 fph 22:00 - 00:00 2.00 DRILL P PROD1 Rotate and reciprocate drill pipe. CBU at 112 spm, 275 gpm, and 2,300 psi. 7/5/2003 00:00 - 01 :30 1.50 DRILL P PROD1 Finish CBU. UD 6 drill pipe singles, SfT 18 stands. 35K overpull at 14,515'. Work through twice. RIH, no problems. 01 :30 - 05:00 3.50 DRILL P PROD1 Pump Hi Vis sweep at 112 spm, 275 gpm, and 2,300 psi. Circulate well clean. Spot liner running pill. 05:00 - 08:00 3.00 DRILL P PROD1 POH with drill pipe, 1 x 1, from 15,250' to 11,707' (117 jts). Drop dart, shear circ sub at 1,520 psi, pump dry job. 08:00 - 12:30 4.50 DRILL P PROD1 POOH from 11,701' to 212'. C/O handling equipment. Loss of Printed: 7/22/2003 8:48:44 AM ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 15-07 15-07C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES 7/5/2003 From - To Hours Task Code NPT Pha$e 08:00 - 12:30 4.50 DRILL P PROD1 12:30 - 15:00 2.50 DRILL P PROD1 15:00 - 15:30 0.50 CASE P CaMP 15:30 - 16:00 0.50 CASE P CaMP 16:00 - 19:00 3.00 CASE P CaMP 19:00 - 19:30 0.50 CASE P CaMP 19:30 - 20:00 0.50 CASE P CaMP 20:00 - 00:00 4.00 CASE P CaMP 00:00 - 00:30 0.50 CASE P CaMP 00:30 - 02:00 1.50 CASE P CaMP 02:00 - 02:30 0.50 CASE P CaMP 02:30 - 05:00 2.50 CASE P CaMP 05:00 - 06:00 1.00 CEMT P CaMP 7/6/2003 06:00 - 07:30 1.50 CEMT P CaMP 07:30 - 08:00 0.50 CEMT P CaMP 08:00 - 09:30 1.50 CEMT P CaMP 09:30 - 14:00 4.50 CEMT P CaMP 14:00 - 15:30 1.50 PERF P CaMP 15:30 - 16:30 1.00 PERF P CaMP 16:30 - 19:00 2.50 PERF P CaMP 19:00 - 20:30 1.50 PERF P CaMP 20:30 - 00:00 3.50 PERF P CaMP 7/7/2003 00:00 - 02:00 2.00 PERF P CaMP 02:00 - 02:30 0.50 PERF P CaMP Page Bof 9 Start: 6/24/2003 Rig Release: 7/8/2003 Rig Number: Spud Date: 8/16/1984 End: 7/8/2003 Description of Operations 13 bbls during trip out. LID BHA from 212' to 82'. Download MWD, flush BHA with water, LID BHA, straighten motor. Clear rig floor. PJSM. R/U 4 1/2" casing equipment. MIU and RIH with 4 1/2" float equipment. Check floats. M/U 41/2", 12.6#, L-80, IBT-M liner to 3,649'. Average M/U torque 3,800 ft-Ibs. M/U HMC hanger / ZXP packer. P/U and M/U drill pipe pups and 1 stand of drill pipe to 3,795'. Circulate liner volume at 7 bpm and 230 psi. Clear rig floor. RIH with liner on drill pipe, from 3,795' to 11,651 '. Circulate at 100 spm, 243 gpm, and 550 psi. P/U weight 170K, SIO weight 130K. RIH from 11,651' to 15,229' with liner. No problems. MIU cement head. Tag bottom at 15,250'. Break circulation at 50 spm, 120 gpm, and 615 psi. Circulate at maximum rate of 110 spm, 275 gpm, and 790 psi. P/U weight 190K, SIO 130K. PJSM with Dowell and crew. Mix and pump 5 bbls CW-100 and pressure test lines to 4,500 psi. Pump additional 15 bbl 8.3 ppg CW-100, 20 bbl 9.5 ppg MudPUSH, followed by 96 bb115.8 ppg slurry. Reciprocate pipe, full returns. Displace with perf pill at 6 bpm. Encountered increase of pressure from -600 psi to -1,100 psi at 70 bbls displacement. At 97 bbls away, pressure spiked to 2,600 psi. Hanger set with pipe 5 feet off bottom. Continued displacement. Observed dart latch on calculated displacement of 116 bbl. Bumped plug on calculated displacement, to 2,600 psi. CIP at 05:55. Release from hanger with 20 RH rotations. Sting out and circulate bottoms up at 215 spm, 530 gpm, and 3,000 psi. TaL at 11,570'. Displace well bore to clean seawater at 12.5 bpm and 2,740 psi. Trace of cement throughout 80 bbl at BU. Set 80K down on packer, verify set. LID cement head. Clean out under shakers. Cut and slip drilling line. Service top drive. POOH from 11,527'. Service break and LID running tool. Clear rig floor. PJSM. RIU handling equipment for TCP perf guns. Pressure test casing to 3,500 psi for 30 minutes and record. Good test. MIU perf guns to 2,215', cIa handling equipment, M/U firing head and XIO to 2,225'. P/U 2 7/8" drill pipe from 2,225' to 3,674'. cIa handling equipment. RIH from 3,674' to 11,904'. RIH from 11,904' to 15,159'. Tag landing collar plug. P/U weight 195K, SIO weight 135K. P/U and S/O twice to confirm bottom tag. Pick up to take weight, then pull up hole to place bottom shot on depth at 15,120' and top shot at 12,910'. Increase pressure to 3,100 psi per HES tcp hand. Hold pressure one minute. Bleed pressure. After -5 minutes, good surface indication of guns firing. POOH. Printed: 7/22/2003 8:48:44 AM ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ·Oate 7/7/2003 7/8/2003 15-07 15-07C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES From.;. To Hours Task Code NPT Phase 02:30 - 03:30 1.00 PERF P COMP 03:30 - 07:00 3.50 PERF P COMP 07:00 - 07:30 0.50 PERF P COMP 07:30 - 09:00 1.50 PERF P COMP 09:00 - 10:00 1.00 PERF P COMP 10:00 - 11 :00 1.00 PERF P COMP 11 :00 - 13:30 2.50 PERF P COMP 13:30 - 17:30 4.00 RUNCOIVP COMP 17:30 - 19:00 1.50 RUNCOIVP COMP 19:00 - 00:00 5.00 RUNCOIVP COMP 00:00 - 06:00 6.00 RUNCOIVP COMP 06:00 - 09:00 3.00 RUNCOIVP COMP 09:00 - 09:30 0.50 RUNCOIVP COMP 09:30 - 11 :00 1.50 RUNCOIVP COMP 11 :00 -12:30 1.50 BOPSUR P COMP 12:30 - 14:30 2.00 WHSUR P COMP 14:30 - 15:30 1.00 WHSUR P COMP 15:30 - 18:00 2.50 WHSUR P COMP 18:00 - 20:00 2.00 RIGD P COMP Start: 6/24/2003 Rig Release: 7/8/2003 Rig Number: Spud Date: 8/16/1984 End: 7/8/2003 Description of Operations Pull 25 stands, from 15,120' to 12,898', until BHA above perforation interval. Monitor hole. Static loss rate 10 bph. LID drill pipe, 1 X 1, from 12,898' to 8,153'. RIH from 8,153' to 10,478', with excess drill pipe from derrick. POOH, 1 X 1, from 10,478' to 8,153'. POOH from 8,153' to 3,674'. (48 stands of inspected drill pipe - 4,480') R/U casing equipment.. LID 2 7/8" drill pipe from 3,674' to 2,225'. PJSM. LID perf guns from 2,225'. All shots fired. Clear rig floor. Pull wear bushing. R/U casing equipment. PJSM regarding running 4 1/2" completion. M/U 41/2",12.6#, L-80, IBT-M tubing to 6,024'. Average MIU torque 3,800 ft-Ibs. M/U 41/2", 12.6#, L-80, IBT-M tubing from 6,024' to 11,576'. Tag up. P/U weight 145K, S/O weight 107K. Work pipe and rotate, 5 attempts. Bottomed out at same point each time at 11574'. Space out wI 3.65' pup joint. M/U tubing hanger and land. RILDS. WLEG at 11,570' Tubing Measurement. Top of TBS 11,570' DPM. Displaced annulus with corrosion inhibited SWat 3 bpm with 210 psi. Dropped 1 7/8" rodlball assy wI 1.375" fishing neck on RHC-M plug installed in XN nipple at 11556' while RID landing jt and x-o's. Set S-3 packer at 11512' with 3500 psi. Hold and record pressure for 30 minutes. Good test. Bled down tubing pressure to 1500 psi, switch over to 9 5/8" X 7" casing inner annulus, test to 3500 psi for 30 minutes, Good test. Bled down tubing sheared DCR valve in GLM at 3097', bled off equalized pressure on well. OK Install TWC, Test to 1000 psi, N/D BOP's N/U tree, test to 5000 psi. R/U lubricator, Pull TWC, RID R/U circ. lines, test, Pumped 155 bbls of diesel down annulus, u-tube to tubing. Freeze protected annulus and tubing to 2200' Install BPV, test to 1000 psi, blow down surface lines, RID secondary annulus valve, secured well. Released rig at 20:00 hrs on 7/08/2003 Printed 7/22/2003 8:48:44 AM ) ) 19-Jul-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-07C Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11,690.04' MD Window / Kickoff Survey: 11,724.00' MD (if applicable) Projected Survey: 15,250.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, ~-b-oql RECEIVED William T. Allen Survey Manager JUL 24 2003 AlasKa Ofi & s'áá ~fb ~~n <~ct1" - 0 Attachment(s) JEF NTIVE Sperry-Sun Drilling Services -- North Slope Alaska BPXA PBU_EOA DS 15 15-07C ~' Job No. AKZZ0002523315, Surveyed: 4 July, 2003 Survey Report 17 July, 2003 Your Ref: APIS00292116603 Surface Coordinates: 5959985.55 N, 677294.45 E (70017' 46.2957" N, 148033' 51.3608" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 -' Surface Coordinates relative to Project H Reference: 959985.55 N, 177294.45 E (Grid) Surface Coordinates relative to Structure Reference: 1124.25 N, 1023.29 E (True) Kelly Bushing: 57. 77ft above Mean Sea Level Elevation relative to Project V Reference: 57. 77ft Elevation relative to Structure Reference : 57. 77ft SpI!!I''-'Y-!5UJ'1 DRILLING SeAVlces A Halliburton Company Survey Ref: 5vy4070 Sperry-Sun Drilling Services JEF NITIVE Survey Report for PBU_EOA DS 16· 16-07C Your Ref: API 500292116603 Job No. AKZZOO02523315, Surveyed: 4 July, 2003 BPXA North Slope Alaska Measured 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) (0/100ft) 11690.04 50.170 58.490 8410.50 8468.27 4309.58 N 4896.03 E 5964409.43 N 682087.45 E 6432.81 Tie On Point AK-6 BP _IFR-AK 11724.00 50.400 58.100 8432.20 8489.97 4323.31 N 4918.25 E 5964423.68 N 682109.35 E 1.113 6457.48 Window Point 11744.65 52.960 58.850 8445.00 8502.77 4331.78 N 4932.06 E 5964432.47 N 682122.96 E 12.720 6472.77 11773.40 56.060 59.910 8461.69 8519.46 4343.70 N 4952.21 E 5964444.86 N 682142.81 E 11.192 6494.72 '-- 11806.81 58.630 61.130 8479.72 8537.49 4357.53 N 4976.69 E 5964459.27 N 682166.97 E 8.284 6520.91 - 11837.30 60.760 62.240 8495.10 8552.87 4370.02 N 4999.87 E 5964472.29 N 682189.84 E 7.660 6545.22 11865.96 63.220 64.810 8508.56 8566.33 4381.29 N 5022.51 E 5964484.10 N 682212.21 E 11.676 6568.25 11899.24 66.920 67.320 8522.59 8580.36 4393.52 N 5050.09 E 5964496.98 N 682239.50 E 13.052 6595.15 11930.85 66.510 65.810 8535.08 8592.85 4405.07 N 5076.73 E 5964509.15 N 682265.86 E 4.576 6620.92 11959.12 66.320 64.620 8546.40 8604.17 4415.93 N 5100.25 E 5964520.56 N 682289.12 E 3.916 6644.18 11993.15 66.170 63.070 8560.10 8617.87 4429.66 N 5128.21 E 5964534.94 N 682316.74 E 4.192 6672.48 12051.61 66.210 63.400 8583.71 8641 .48 4453.74 N 5175.97 E 5964560.15 N 682363.91 E 0.521 6721.30 12144.10 67.050 64.490 8620.39 8678.16 4491.03 N 5252.24 E 5964599.23 N 682439.29 E 1.412 6798.36 12177.76 66.850 64.440 8633.57 8691.34 4504.38 N 5280.19 E 5964613.23 N 682466.91 E 0.610 6826.35 12209.21 68.100 64.860 8645.62 8703.39 4516.82 N 5306.44 E 5964626.29 N 682492.86 E 4.162 6852.57 12236.89 70.550 65.810 8655.39 8713.16 4527.62 N 5329.97 E 5964637.64 N 682516.13 E 9.415 6875.80 12270.63 73.930 66.050 8665.68 8723.45 4540.73 N 5359.31 E 5964651.44 N 682545.15 E 10.041 6904.48 12300.89 76.600 66.210 8673.38 8731.15 4552.57 N 5386.06 E 5964663.90 N 682571.62 E 8.838 6930.55 12329.80 78.440 68.010 8679.63 8737.40 4563.54 N 5412.07 E 5964675.49 N 682597.36 E 8.801 6955.4 7 12363.65 81.700 68.4 70 8685.46 8743.23 4575.90 N 5443.03 E 5964688.58 N 682628.02 E 9.723 6984.60 12395.10 85.360 66.970 8689.01 8746.78 4587.75 N 5471.94 E 5964701.10 N 682656.65 E 12.565 7012.03 12423.68 86.720 63.810 8690.98 8748.75 4599.62 N 5497.86 E 5964713.58 N 682682.28E 12.013 7037.60 12457.83 88.090 62.640 8692.53 8750.30 4614.99 N 5528.31 E 5964729.66 N 682712.36 E 5.273 7068.74 ~ 12488.71 88.640 60.030 8693.41 8751.18 4629.79 N 5555.40 E 5964745.10 N 682739.09 E 8.634 7097.32 12517.32 89.440 60.430 8693.89 8751.66 4644.00 N 5580.23 E 5964759.89 N 682763.57 E 3.126 7124.00 12615.05 87.770 62.160 8696.27 8754.04 4690.92 N 5665.91 E 5964808.82 N 682848.13 E 2.460 7214.48 12708.46 88.700 61.070 8699.14 8756.91 4735.31 N 5748.05 E 5964855.13 N 682929.20 E 1.533 7300.75 12800.58 88.210 61.150 8701.63 8759.40 4779.79 N 5828.68 E 5964901.51 N 683008.75 E 0.539 7386.14 12894.13 88.330 60.270 8704.45 8762.22 4825.54 N 5910.23 E 5964949.17 N 683089.20 E 0.949 7473.09 12987.59 89.320 61.410 8706.37 8764.14 4871.07 N 5991.83 E 5964996.61 N 683169.70 E 1.615 7559.90 17 July, 2003 - 17:12 Page 20f5 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU....EOA DS 15 - 15-07C Your Ref: API 500292116603 Job No. AKZZOO02523315, Surveyed: 4 July, 2003 BPXA North Slope Alaska Measured 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) (0/100ft) 13032.67 90.060 61.380 8706.61 8764.38 4892.65 N 6031.40 E 5965019.12 N 683208.76 E 1.643 7601.62 13064.64 91.240 61.770 8706.25 8764.02 4907.87 N 6059.52 E 5965034.99 N 683236.51 E 3.887 7631.16 13109.42 90.990 62.180 8705.38 8763.15 4928.90 N 6099.04 E 5965056.95 N 683275.52 E 1.072 7672.42 13158.14 90.930 62.220 8704.56 8762.33 4951.62 N 6142.13 E 5965080.68 N 683318.06 E 0.148 7717.24 13206.03 91.050 61.780 8703.73 8761.50 4974.10 N 6184.41 E 5965104.15 N 683359.80 E 0.952 7761.36 13251.42 92.720 62.600 8702.24 8760.01 4995.27 N 6224.53 E 5965126.26 N 683399.41 E 4.098 7803.10 13304.47 92.100 60.120 8700.01 8757.78 5020.67 N 6271.04 E 5965152.75 N 683445.31 E 4.815 7852.16 13345.53 93.150 62.320 8698.13 8755.90 5040.42 N 6306.99 E 5965173.34 N 683480.79 E 5.932 7890.16 13379.74 90.800 60.850 8696.95 8754.72 5056.68 N 6337.06 E 5965190.31 N 683510.46 E 8.101 7921.76 13410.62 91.230 61.550 8696.40 8754.17 5071.56 N 6364.12 E 5965205.82 N 683537.16 E 2.660 7950.37 13438.71 90.990 61.530 8695.86 8753.63 5084.94 N 6388.81 E 5965219,78 N 683561.53 E 0.857 7976.33 13472.62 90.560 61.370 8695.40 8753.17 5101.15N 6418.59 E 5965236.69 N 683590.92 E 1.353 8007.70 13503.81 90.250 61.290 8695.18 8752.95 5116.11 N 6445.96 E 5965252.29 N 683617.93 E 1.026 8036.57 13532.36 90.930 61.290 8694.89 8752.66 5129.82 N 6470.99 E 5965266.59 N 683642.63 E 2.382 8063.01 13566.42 90.250 61.590 8694.54 8752.31 5146.11 N 6500.91 E 5965283.58 N 683672.15 E 2.182 8094.52 13593.69 89.440 60.800 8694.61 8752.38 5159.25 N 6524.80 E 5965297.28 N 683695.73 E 4.149 8119.80 13625.32 88.830 59.1 00 8695.09 8752.86 5175.08 N 6552.18 E 5965313.75 N 683722.73 E 5.710 8149.36 13658.71 89.570 56.780 8695.55 8753.32 5192.80 N 6580.47 E . 5965332.14 N 683750.59 E 7.292 8180.96 13689.46 91.480 52.450 8695.27 8753.04 5210.60 N 6605.53 E 5965350.52 N 683775.23 E 15.389 8210.58 13717.19 91.610 49.370 8694.52 8752.29 5228.08 N 6627.04 E 5965368.50 N 683796.32 E 11.113 8237.71 13750.73 90.560 44.430 8693.89 8751.66 5250.98 N 6651.52 E 5965391.98 N 683820.25 E 15.055 8270.93 13780.95 90.370 40.750 8693.64 8751.41 5273.23 N 6671.97 E 5965414.70 N 683840.17 E 12.193 8301.09 13809.12 90.490 36.950 8693.43 8751.20 5295.16 N 6689.64 E 5965437.04 N 683857.31 E 13.496 8329.25 13843.28 91.170 33.860 8692.94 8750.71 5323.00 N 6709.42 E 5965465.34 N 683876.44 E 9.261 8363.33 - 13874.29 89.260 30.990 8692.82 8750.59 5349.17 N 6726.05 E 5965491.90 N 683892.44 E 11.117 8394.12 13902.74 89.510 29.450 8693.13 8750.90 5373.75 N 6740.36 E 5965516.81 N 683906.17 E 5.484 8422.23 13936.92 89.630 27.120 8693.38 8751.15 5403.85 N 6756.56 E 5965547.28 N 683921.66 E 6.826 8455.79 13968.19 90.060 25.110 8693.47 8751.24 5431.92 N 6770.32 E 5965575.67 N 683934.75 E 6.573 8486.26 13997.67 90.430 22.040 8693.34 8751.11 5458.94 N 6782.11 E 5965602.96 N 688945.90 E 10.489 8514.66 14031.83 90.990 19.620 8692.92 8750.69 5490.86 N 6794.26 E 5965635.16 N 683957.29 E 7.271 8547.08 14063.36 92.900 18.710 8691.85 8749.62 5520.63 N 6804.60 E 5965665.16 N 683966.93 E 6.709 8576.70 14090.94 91.970 15.460 8690.68 8748.45 5546.96 N 6812.70 E 5965691.68 N 683974.40 E 12.247 8602.24 14125.81 92.650 14.150 8689.27 8747.04 5580.64 N 6821.60 E 5965725.56 N 683982.51 E 4.230 8633.98 14157.13 91.730 12.100 8688.07 8745.84 5611.12 N 6828.70 E 5965756.20 N 683988.89 E 7.170 8662.11 14184.99 90.180 9.050 8687.61 8745.38 5638.50 N 6833.82 E 5965783.69 N 683993.36 E 12.279 8686.57 17 July, 2003 - 17:12 Page 3 of5 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 - 15-07C Your Ref: AP/500292116603 Job No. AKZZ0002523315, Surveyed: 4 July, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth I net. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 14218.87 91.480 6.010 8687.12 8744.89 5672.08 N 6838.25 E 5965817.36 N 683997.00 E 9.758 8715.42 14249.99 92.590 6.120 8686.01 8743.78 5703.01 N 6841.54 E 5965848.36 N 683999.56 E 3.584 8741.49 14278.43 92.840 5.440 8684.67 8742.44 5731.27 N 6844.40 E 5965876.68 N 684001.75 E 2.545 8765.22 14312.47 92.100 1.800 8683.20 8740.97 5765.21 N 6846.55 E 5965910.66 N 684003.09 E 10.902 8792.90 14343.85 91.540 0.510 8682.20 8739.97 5796.56 N 6847.18 E 5965942.02 N 684002.99 E 4.480 8817.62 14372.74 93.580 359.290 8680.91 8738.68 5825.42 N 6847.13 E 5965970.87 N 684002.26 E 8.225 8839.97 - 14406.49 93.210 358.650 8678.91 8736.68 5859.11 N 6846.52 E 5966004.53 N 684000.86 E 2.188 8865.72 14437.50 93.890 358.570 8676.99 8734.76 5890.05 N 6845.77 E 5966035.45 N 683999.38 E 2.208 8889.25 14464.54 94.130 358.190 8675.10 8732.87 5917.01 N 6845.01 E 5966062.38 N 683997.98 E 1.659 8909.68 14498.79 90.760 358.100 8673.64 8731.41 5951.21 N 6843.90 E 5966096.54 N 683996.06 E 9.843 8935.51 14529.86 89.260 357.440 8673.63 8731.40 5982.25 N 6842.69 E 5966127.55 N 683994.12 E 5.274 8958.83 14558.50 90.490 358.690 8673.70 8731.47 6010.87 N 6841.73 E 5966156.14 N 683992.48 E 6.123 8980.42 14592.53 89.880 358.360 8673.59 8731.36 6044.89 N 6840.85 E 5966190.13 N 683990.80 E 2.038 9006.26 14623.16 89.810 358.050 8673.67 8731 .44 6075.51 N 6839.89 E 5966220.72 N 683989.12 E 1.038 9029.40 14651.55 91 .790 358.310 8673.27 8731.04 6103.88 N 6838.99 E 5966249.06 N 683987.55 E 7.034 9050.84 14685.39 94.320 359.510 8671.47 8729.24 6137.66 N 6838.35 E 5966282.82 N 683986.11 E 8.272 9076.64 14716.04 95.200 359.390 8668.93 8726.70 6168.20 N 6838.05 E 5966313.34 N 683985.10 E 2.898 9100.15 14743.27 93.330 359.180 8666.90 8724.67 6195.36 N 6837.72 E 5966340.48 N 683984.12 E 6.910 9121.00 14777.21 93.210 358.700 8664.97 8722.74 6229.23 N 6837.09 E 5966374.33 N 683982.69 E 1 .456 9146.88 14808.63 93.890 358.740 8663.02 8720.79 6260.59 N 6836.39 E 5966405.66 N 683981.25 E 2.168 9170.76 14836.77 92.350 358.790 8661.49 8719.26 6288.68 N 6835.78 E 5966433.73 N 683979.98 E 5.4 76 9192.17 14870.76 90.180 0.030 8660.74 8718.51 6322.65 N 6835.43 E 5966467.69 N 683978.83 E 7.352 9218.30 14901.09 89.440 359.060 8660.84 8718.61 6352.98 N 6835.19 E 5966498.00 N 683977.88 E 4.023 9241.68 14928.23 89.510 359.660 8661.09 8718.86 6380.12 N 6834.89 E 5966525.12 N 683976.93 E 2.226 9262.54 .~. 14962.54 89.690 358.980 8661.33 8719.10 6414.43 N 6834.48 E 5966559.41 N 683975.72 E 2.050 9288.89 14993.97 88.270 359.400 8661.89 8719.66 6445.85 N 6834.04 E 5966590.81 N 683974.53 E 4.711 9312.99 15021.53 88.760 359.500 8662.60 8720.37 6473.40 N 6833.77 E 5966618.35 N 683973.62 E 1.815 9334.19 15055.20 88.520 359.250 8663.40 8721.17 6507.05 N 6833.41 E 5966651.99 N 683972.46 E 1.029 9360.07 1 5086.56 88.640 358.750 8664.18 8721.95 6538.40 N 6832.86 E 5966683.31 N 683971.17 E 1.639 9384.04 15114.56 89.260 358.470 8664.69 8722.46 6566.39 N 6832.18 E 5966711.28 N 683969.83 E 2.430 9405.32 15149.50 89.320 358.150 8665.12 8722.89 6601.31 N 6831.15 E 5966746.16 N 683967.98 E 0.932 9431.76 15180.10 89.810 357.690 8665.36 8723.13 6631.89 N 6830.04 E 5966776.71 N 683966.15 E 2.196 9454.78 15205.04 90.310 356.860 8665.33 8723.10 6656.80 N 6828.85 E 5966801.59 N 683964.37 E 3.885 9473.35 15250.00 90.310 356.860 8665.09 8722.86 6701.69 N 6826.39 E 5966846.41 N 683960.85 E 0.000 9506.62 Projected Survey 17 July, 2003 - 17:12 Page 4 0'5 DrillQuest 3.03.02.005 .- Sperry-Sun Drilling~Services Survey Report for PBU_EOADS 15· 15-07C Your Ref: API 500292116603 Job No. AKZZOO02523315, Surveyed: 4 July, 2003 BPXA North Slope Alaska 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 39.130° (True). ~~. Magnetic Declination at Surface is 25.878°(25-Jun-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 15250.00ft., The Bottom Hole Displacement is 9566.20ft., in the Direction of 45.528° (True). .- Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~ ~ Comment 11690.04 11724.00 15250.00 8468.27 8489.97 8722.86 4309.58 N 4323.31 N 6701.69 N 4896.03 E 4918.25 E 6826.39 E Tie On Point Window Point Projected Survey Survey tool program for 15-07C From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) -. 0.00 10195.52 11690.04 0.00 7553.35 8468.27 10195.52 11690.04 15250.00 7553.35 8468.27 8722.86 BP High Accuracy Gyro (15-07) MWD Magnetic (15-07A) AK-6 BP _IFR-AK (15-07C) 17 July, 2003 - 17:12 Page 5 0'5 DrillQuest 3.03.02.005 ) ) 19-Jul-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-07C MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11,690.04' MD Window / Kickoff Survey: 11,724.00' MD (if applicable) Projected Survey: 15,250.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, ~3-097 RECEIVED William T. Allen Survey Manager Attachment(s) Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 15 15-07C MWD -"" Job No. AKMW0002523315, Surveyed: 4 July, 2003 Survey Report 17 July, 2003 Your Ref: APlS00292116603 Surface Coordinates: 5959985.55 N, 677294.45 E (70017' 46.2957" N, 148033'51.3608" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 .- Surface Coordinates relative to Project H Reference: 959985.55 N, 177294.45 E (Grid) Surface Coordinates relative to Structure Reference: 1124.25 N, 1023.29 E (True) Kelly Bushing: 57. 77ft above Mean Sea Level Elevation relative to Project V Reference: 57. 77ft Elevation relative to Structure Reference: 57. 77ft 5p~""Y-!!iUl'1 DRILLING SSAVIc:es A Halliburton Company Survey Ref: svy4071 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 16· 15-07C MWD Your Ref: API 500292116603 Job No. AKMWOO02523315, Surveyed: 4 July, 2003 BPXA North Slope Alaska Measured 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) (0/100ft) 11690.04 50.170 58.490 8410.50 8468.27 4309.58 N 4896.03 E 5964409.43 N 682087.45 E 6432.81 Tie On Point - 11724.00 50.400 58.100 8432.20 8489.97 - 4323.31 N 4918.25 E 5964423.68 N 682109.35 E 1.113 6457.48 Window Point 11744.65 52.960 58.850 8445.00 8502.77 4331.78 N 4932.06 E 5964432.47 N 682122.96 E 12.720 6472.77 11773.40 56.060 59.910 8461.69 8519.46 4343.70 N 4952.21 E 5964444.86 N 682142.81 E 11 . 1 92 6494.72 11806.81 58.630 64.680 8479.72 8537.49 4356.75 N 4977.10 E 5964458.50 N 682167.40 E 14.268 6520.56 11837.30 60.760 65.050 8495.11 8552.88 4367.93 N 5000.93 E 5964470.24 N 682190.96 E 7.064 6544.27 '-' 11865.96 63.220 65.300 8508.57 8566.34 4378.55 N 5023.90 E 5964481.40 N 682213.66 E 8.618 6567.01 11899.24 66.920 67.950 8522.59 8580.36 4390.51 N 5051.60 E 5964494.01 N 682241.07 E 13.256 6593.76 11930.85 66.510 66.310 8535.09 8592.86 4401.80 N 5078.35 E 5964505.92 N 682267.55 E 4.939 6619.40 11959.12 66.320 64.620 8546.40 8604.17 4412.55 N 5101.92 E 5964517.23 N 682290.86 E 5.520 6642.62 11993.15 66.170 63.510 8560.11 8617.88 4426.18 N 5129.93 E 5964531.51 N 682318.54 E 3.018 6670.86 12051.61 66.210 64.900 8583.71 8641 .48 4449.45 N 5178.08 E 5964555.91 N 682366.13 E 2.176 6719.30 12144.10 67.050 65.150 8620.40 8678.17 4485.30 N 5255.04 E 5964593.56 N 682442.22 E 0.941 6795.68 12177.76 66.850 64.770 8633.58 8691.35 4498.41 N 5283.10 E 5964607.33 N 682469.97 E 1.197 6823.56 12209.21 68.100 65.030 8645.63 8703.40 4510.73 N 5309.41 E 5964620.27 N 682495.98 E 4.047 6849.72 12236.89 70.550 65.350 8655.40 8713.17 4521.59 N 5332.92 E 5964631.69 N 682519.22 E 8.917 6872.98 12270.63 73.930 65.460 8665.69 8723.46 4534.96 N 5362.13 E 5964645.74 N 682548.11 E 10.023 6901.79 12300.89 76.600 65.080 8673.38 8731 .15 4547.21 N 5388.71 E 5964658.61 N 682574.39 E 8.907 6928.06 12329.80 78.440 67.470 8679.63 8737.40 4558.56 N 5414.55 E 5964670.57 N 682599.95 E 10.279 6953.17 12363.65 81.700 66.720 8685.47 8743.24 4571.54 N 5445.25 E 5964684.27 N 682630.35 E 9.875 6982.62 12395.10 85.360 65.160 8689.01 8746.78 4584.28 N 5473.78 E 5964697.67 N 682658.57 E 12.638 7010.50 12423.68 86.720 62.710 8690.99 8748.76 4596.80 N 5499.39 E 5964710.80 N 682683.88 E 9.787 7036.38 12457.83 88.090 62.800 8692.53 8750.30 4612.42 N 5529.72 E 5964727.13 N 682713.83 E 4.020 7067.64 12488.71 88.640 60.690 8693.41 8751.18 4627.03 N 5556.91 E 5964742.38 N 682740.66 E 7.059 7096.13 '~ 12517.32 89.440 59.900 8693.89 8751.66 4641.21 N 5581.76 E 5964757.14 N 682765.17 E 3.930 7122.81 12615.05 87.770 63.090 8696.27 8754.04 4687.83 N 5667.60 E 5964805.77 N 682849.89 E 3.683 7213.14 12708.46 88.700 61.900 8699.15 8756.92 4730.94 N 5750.41 E 5964850.83 N 682931.66 E 1.616 7298.85 12800.58 88.210 61 .1 50 8701.63 8759.40 4774.85 N 5831.35 E 5964896.63 N 683011.55 E 0.972 7383.99 12894.13 88.330 60.660 8704.46 8762.23 4820.32 N 5913.06 E 5964944.01 N 683092.16 E 0.539 7470.82 12987.59 89.320 60.91 0 8706.37 8764.14 4865.92 N 5994.62 E 5964991.53 N 683172.61 E 1.093 7557.67 13032.67 90.060 61 .400 8706.62 8764.39 4887.67 N 6034.10 E 5965014.20 N 683211.57 E 1.969 7599.46 13064.64 91.240 61.080 8706.26 8764.03 4903.05 N 6062.13 E 5965030.24 N 683239.23 E 3.824 7629.07 13109.42 90.990 61.830 8705.38 8763.15 4924.45 N 6101.45 E 5965052.56 N 683278.04 E 1.765 7670.49 13158.14 90.930 61.650 8704.57 8762.34 4947.51 N 6144.36 E 5965076.63 N 683320.39 E 0.389 7715.46 13206.03 91 .050 61 .120 8703.74 8761.51 4970.44 N 6186.39 E 5965100.54 N 683361.87 E 1.135 7759.78 17 July, 2003 - 17:17 Page 20f5 DrillQlIest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOADS 15 - 15-07C MWD Your Ref: API 500292116603 Job No. AKMW0002523315, Surveyed: 4 July, 2003 BPXA North Slope Alaska Measured 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) (0/100ft) 13251.42 92.720 61.530 8702.25 8760.02 4992.21 N 6226.20 E 5965123.24 N 683401.15 E 3.788 7801.78 13304.47 92.100 59.550 8700.02 8757.79 5018.28 N 6272.34 E 5965150.39 N 683446.67 E 3.908 7851.12 13345.53 93.150 62.060 8698.14 8755.91 5038.28 N 6308.14 E 5965171.24 N 683481.99 E 6.620 7889.23 13379.74 90.800 60.780 8696.96 8754.73 5054.64 N 6338.17 E 5965188.29 N 683511.62 E 7.821 7920.87 13410.62 91.230 61.780 8696.41 8754.18 5069.47 N 6365.24 E 5965203.77 N 683538.33 E 3.525 7949.46 13438.71 90.990 62.100 8695.87 8753.64 5082.68 N 6390.03 E 5965217.56 N 683562.80 E 1.424 7975.35 -.-I 13472.62 90.560 61.640 8695.41 8753.18 5098.67 N 6419.93 E 5965234.24 N 683592.32 E 1.857 8006.62 13503.81 90.250 61.600 8695.19 8752.96 5113.50 N 6447.37 E 5965249.71 N 683619.40 E 1.002 8035.44 13532.36 90.930 61.310 8694.89 8752.66 5127.14 N 6472.45 E 5965263.94 N 683644.15 E 2.589 8061.85 13566.42 90.250 61.830 8694.54 8752.31 5143.35 N 6502.40 E 5965280.86 N 683673.71 E 2.513 8093.33 13593.69 89.440 60.310 8694.62 8752.39 5156.54 N 6526.26 E 5965294.61 N 683697.26 E 6.316 8118.62 13625.32 88.830 58.830 8695.09 8752.86 5172.56 N 6553.53 E 5965311.26 N 683724.14 E 5.060 8148.25 13658.71 89.570 57.240 8695.56 8753.33 5190.23 N 6581.85 E 5965329.60 N 683752.04 E 5.252 8179.84 13689.46 91.480 52.560 8695.28 8753.05 5207.91 N 6607.00 E 5965347.87 N 683776.76 E 16.437 8209.42 13717.19 91.610 49.620 8694.53 8752.30 5225.32 N 6628.57 E 5965365.78 N 683797.91 E 10.609 8236.54 13750.73 90.560 44.860 8693.89 8751.66 5248.08 N 6653.18 E 5965389.11 N 683821.98 E 14.531 8269.72 13780.95 90.370 40.480 8693.65 8751.42 5270.29 N 6673.66 E 5965411.80 N 683841.93 E 14.507 8299.88 13809.12 90.490 36.740 8693.44 8751.21 5292.30 N 6691.24 E 5965434.22 N 683858.98 E 13.283 8328.04 13843.28 91.170 33.920 8692.94 8750.71 5320.16 N 6710.99 E 5965462.54 N 683878.07 E 8.491 8362.12 13874.29 89.260 31.310 8692.83 8750.60 5346.28 N 6727.70 E 5965489.04 N 683894.16 E 10.429 8392.92 13902.74 89.510 29.180 8693.13 8750.90 5370.85 N 6742.03 E 5965513.95 N 683907.90 E 7.538 8421.03 13936.92 89.630 26.690 8693.39 8751.16 5401.05 N 6758.04 E 5965544.51 N 683923.20 E 7.293 8454.56 13968.19 90.060 24.800 8693.47 8751.24 5429.21 N 6771.62 E 5965572.99 N 683936.11 E 6.199 8484.97 13997.67 90.430 22.180 8693.35 8751.12 5456.25 N 6783.37 E 5965600.29 N 683947.22 E 8.975 8513.36 - 14031.83 90.990 19.230 8692.92 8750.69 5488.19 N 6795.44 E 5965632.52 N 683958.54 E 8.789 8545.76 14063.36 92.900 18.500 8691.85 8749.62 5518.01 N 6805.63 E 5965662.57 N 683968.02 E 6.485 8575.32 14090.94 91.970 15.790 8690.68 8748.45 5544.34 N 6813.75 E 5965689.08 N 683975.52 E 10.380 8600.87 14125.81 92.650 14.290 8689.28 8747.05 5577.99 N 6822.79 E 5965722.93 N 683983.76 E 4.720 8632.68 14157.13 91.730 12.320 8688.08 8745.85 5608.44 N 6830.00 E 5965753.55 N 683990.25 E 6.938 8660.85 14184.99 90.180 10.140 8687.61 8745.38 5635.76 N 6835.42 E 5965780.99 N 683995.02 E 9.600 8685.46 14218.87 91.480 6.710 8687.12 8744.89 5669.27 N 6840.38 E 5965814.60 N 683999.20 E 10.826 8714.59 14249.99 92.590 7.090 8686.02 8743.79 5700.14 N 6844.12 E 5965845.56 N 684002.20 E 3.770 8740.89 14278.43 92.840 6.390 8684.67 8742.44 5728.35 N 6847.45 E 5965873.84 N 684004.87 E 2.611 8764.88 14312.4 7 92.100 3.600 8683.20 8740.97 5762.23 N 6850.41 E 5965907.77 N 684007.03 E 8.4 72 8793.03 14343.85 91.540 1.200 8682.21 8739.98 5793.56 N 6851.73 E 5965939.13 N 684007.60 E 7.850 8818.16 ----~- 17 July, 2003 - 17:17 Page 30'5 DriflQuest 3.03.02.005 Sperry-Sun Drilli"gServices Survey Report for PBU_EOADS16 . 16-07C MWD Your Ref: API 500292116603 Job No. AKMW0002523315, Surveyed: 4 July, 2003 BPXA North Slope Alaska Measured 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) (0/100ft) 14372.74 93.580 359.800 8680.92 8738.69 5822.42 N 6851.98 E 5965967.99 N 684007.18 E 8.561 8840.71 14406.49 93.210 359.290 8678.92 8736.69 5856.11 N 6851.71 E 5966001.66 N 684006.11 E 1.865 8866.67 14437.50 93.890 358.560 8677.00 8734.77 5887.06 N 6851.13 E 5966032.58 N 684004.80 E 3.214 8890.31 14464.54 94.130 358.130 8675.11 8732.88 5914.02 N 6850.35 E 5966059.52 N 684003.39 E 1.818 8910.73 14498.79 90.760 358.270 8673.65 8731.42 5948.22 N 6849.28 E 5966093.68 N 684001.51 E 9.848 8936.58 14529.86 89.260 358.140 8673.64 8731.41 5979.27 N 6848.30 E 5966124.70 N 683999.80 E 4.846 8960.06 .~ 14558.50 90.490 358.740 8673.70 8731.47 6007.90 N 6847.53 E 5966153.31 N 683998.35 E 4.778 8981.77 14592.53 89.880 358.580 8673.59 8731.36 6041.92 N 6846.73 E 5966187.30 N 683996.75 E 1.853 9007.66 14623.16 89.810 358.250 8673.68 8731.45 6072.54 N 6845.88 E 5966217.89 N 683995.18 E 1.101 9030.88 14651.55 91 .790 358.500 8673.28 8731.05 6100.91 N 6845.08 E 5966246.23 N 683993.71 E 7.030 9052.38 14685.39 94.320 359.830 8671.48 8729.25 6134.70 N 6844.58 E 5966280.00 N 683992.42 E 8.444 9078.28 14716.04 95.200 359.530 8668.93 8726.70 6165.24 N 6844.41 E 5966310.53 N 683991.52 E 3.032 9101.86 14743.27 93.330 359.800 8666.91 8724.68 6192.39 N 6844.26 E 5966337.67 N 683990.73 E 6.938 9122.82 14777.21 93.210 359.030 8664.97 8722.74 6226.27 N 6843.91 E 5966371.54 N 683989.58 E 2.292 9148.89 14808.63 93.890 358.130 8663.03 8720.80 6257.62 N 6843.13 E 5966402.86 N 683988.06 E 3.586 9172.72 14836.77 92.350 358.800 8661.49 8719.26 6285.71 N 6842.38 E 5966430.92 N 683986.65 E 5.967 9194.03 14870.76 90.180 359.600 8660.74 8718.51 6319.69 N 6841.91 E 5966464.88 N 683985.37 E 6.804 9220.09 14901.09 89.440 359.050 8660.84 8718.61 6350.01 N 6841.55 E . 5966495.19 N 683984.30 E 3.040 9243.39 14928.23 89.510 358.460 8661.09 8718.86 6377.15 N 6840.96 E 5966522.30 N 683983.07 E 2.189 9264.06 14962.54 89.690 358.620 8661.33 8719.10 6411.45 N 6840.08 E 5966556.56 N 683981.39 E 0.702 9290.12 14993.97 88.270 359.160 8661.89 8719.66 6442.86 N 6839.48 E 5966587.96 N 683980.04 E 4.834 9314.10 15021.53 88.760 359.110 8662.61 8720.38 6470.41 N 6839.06 E 5966615.49 N 683978.97 E 1.787 9335.21 15055.20 88.520 359.450 8663.41 8721.18 6504.07 N 6838.64 E 5966649.13 N 683977.76 E 1.236 9361.05 15086.56 88.640 359.040 8664.18 8721.95 6535.42 N 6838.22 E 5966680.46 N 683976.60 E 1.362 9385.11 .-' 1 5114.56 89.260 358.660 8664.70 8722.4 7 6563.41 N 6837.66 E 5966708.43 N 683975.38 E 2.597 9406.46 15149.50 89.320 358.490 8665.13 8722.90 6598.33 N 6836.79 E 5966743.32 N 683973.69 E 0.516 9433.01 15180.10 89.810 358.230 8665.36 8723.13 6628.92 N 6835.92 E 5966773.88 N 683972.09 E 1.813 9456.18 15205.04 90.310 357.690 8665.34 8723.11 6653.84 N 6835.03 E 5966798.78 N 683970.62 E 2.951 9474.96 15250.00 90.310 357.690 8665.09 8722.86 6698.77 N 6833.22 E 5966843.64 N 683967.75 E 0.000 9508.66 Projected Survey 17 July, 2003 - 17:17 Page 40(5 DríllQlJest 3.03.02.005 Sperry-Sun Drilling-Services Survey Report for PBU_EOA OS 15 ~1s.o7C MWD Your Ref: API 500292116603 Job No. AKMWOOO2523315,. Surveyed: 4 July, 2003 BPXA North Slope Alaska 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 39.130° (True). Magnetic Declination at Surface is 25.878°(25-Jun-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 15250.00ft., The Bottom Hole Displacement is 9569.03f1., in the Direction of 45.569° (True). -- Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11690.04 11724.00 15250.00 8468.27 8489.97 8722.86 4309.58 N 4323.31 N 6698.77 N 4896.03 E 4918.25 E 6833.22 E Tie On Point Window Point Projected Survey Survey tool program for 15-07C MWD ,-- Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) ~' 0.00 10195.52 0.00 10195.52 7553.35 15250.00 7553.35 BP High Accuracy Gyro (15-07) 8722.86 MWD Magnetic (15-07A) 17 July, 2003 - 17:17 Page 50f5 DrillQuest 3.03.02.005 ) r~ñ'ì rrl~ ® 11 ®@íV(® ~) r U~~ ls Lr\\ l~) ü\.\ l~, ) / / / l FRANK H. MURKOWSKI, GOVERNOR AI¡llSHA. OIL AND GAS CONSERVATION COMMISSION 333 w. rrn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 15-07C BP Exploration (Alaska), Inc. Permit No: 203-097 Surface Location: 1527' SNL, 1354' EWL, Sec. 22, TIIN, RI4E, UM Bottomhole Location: 1883' NSL, 2989' EWL, Sec. 11, TI1N, RI4E, UM Dear Mr. Isaacson: 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 the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~ f?-~~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this-'-- day of June, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ~ G jf- (, /-S/2.OO'~ 12. Distance to nearest property line 13. Distance to nearest well / ADL 028307, 1883' MD L2-25 is 915' away at 14250' MD 16. To be completed for deviated wells Kick Off Depth 11735' MD Maximum Hole Angle 18. Casing ~rogram Specifications Size Casing Weiç ht Grade CouolinQ 4-1/2" 12.6# L-80 IBT Hole 6-1/8" I ... STATE OF ALASKA \ ALASKA C.) AND GAS CONSERVATION COMMk.J10N PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 181 Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool ~ Plan KBE = 57.8' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028302 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / 15-07C 9. Approximate spud dat~ 06/20/03 /' Amount $200,000.00 14. Number of acres in property 15. Pr~sed depth (MD and TVD) 2560 15250' MD / 87431 TVD o 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 92 Maximum surface 2450 psig, At total depth (TVD) 85001 / 3300 psig Setting Depth Top Bottom Quantity of Cement LenQth MD TVD MD TVD (jnclud;;taae data) 36651 115851 8404' 15250' 8743' 437 sx Class IG' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work 0 Drill 181 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 677294, Y = 5959986 1527' SNL, 13541 EWL, SEC. 22, T11 N, R14E, UM At top of productive interval x = 682694, Y = 5964720 30761 NSL, 1593' EWL, SEC. 14, T11 N, R14E, UM At total depth x = 683985, Y = 5968839 18831 NSL, 2989' EWL, SEC. 11, T11 N, R14E, UM Number 2S 100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 13875 feet Plugs (measured) true vertical 8729 feet Effective depth: measured 13838 feet Junk (measured) true vertical 8730 feet Casing Length Size Cemented Structural Conductor Surface Intermediate Production Liner Liner 80' 20" 2395' 13-3/8" 9-5/8" 21001 7" 2021' 2-3/8" 2000 sx Poleset 1850 sx PF IE', 400 sx PF ICI 500 sx Class 'G', 300 sx PF ICI MD TVD 801 801 2395' 23951 10193' 75561 305 sx Class 'G I 66 sx LARC (Approx.) 1 <IDe t~ a ~ \l&m:f\~7081 1 ~~ tsã~ ~ 8~'5L,~J87291 JUN 0 2 2003 Perforation depth: measured Open: 13158' - 13360', 134001 - 135581, 136401 - 13835' Sqzd: 12950' - 13100', 13156' - 131581 true vertical Open: 87351 - 8727', 8726' - 8730', 87321 - 87301 Sqzd: 8735' - 87351, 87351 - 8735' 181 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 181 Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 181 20 AAC 25.050 Requirements Alaska Oil & Gas Cons. ComiTtission Anchorage 20. Attachments Contact Engineer Name/Number: Phil Smith, 564-4897 21. I hereby certify that t~e f~regoing is -rue and correct to the best of my. ~noWI~. ~ge . Signed Billlsaacson µL.. \. ...u~ -. Title Senior Drilling Engineer Com.mission Use.Onl\, Prepared By Name/Number: Terrie Hubble, 564-4628 Date J vreE z , Z OO~ Permit Number API Number .2...0 ....~. ~ 0 /' 7 50- 029-21166-03 Conditions of Approval: Samples Required 0 Yes ~ No Hydrogen Sulfide Measures ~ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: Teçt g (J r" E ~ ~ S"OC tJ~,". tp vL... - L() /.. by order of :~:o~~~~~ Rev. 1~-~ / IT - -~ ~ åFfiGeí N AT commission oo~ya~{)a~ See cover letter (; { ~( ( ..J for other requirements Mud Log Required 0 Yes fiíI No Directional Survey Required ~Yes 0 No o 4K D5K D10K D15K 0 3.5K psi for CTU Date ~~i%cate ) ) I Well Name: I DS 15-07C Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: Estimated Target Location: Ivishak Zone 2A Bottom Hole Location: x = 677,294.46 Y = 5,959,985.55 1521' FNL, 1355' FWL Sec. 22, T11N, R14E Umiat X = 682,694 Y = 5,964,720 TVDss 8690' ~. 2203' FNL, 1593' FWL Sec. 14, T11N, R14E Umiat X = 683,985 Y = 5,968,839 TVDss 8685' 3391' FNL, 2989' FWL Sec. 11, T11 N, R14E Umiat /. /' I RiQ: I Nabors 2ES ./ I AFE Number: I PBD4P2093 I I Estimated Start Date: 106/20/03 /" I I OperatinQ days to complete: 119.0 / I MD: 115,250' I I TVD: 18,743' I I BF/MS: 129.3' 1 KB: 128.5' I I KBE: 157.8' I Well DesiQn (conventional, slim hole, etc.): I Horizontal Sidetrack I Objective: I Zone 1 A / 1 B CasinQlTubinQ Pro~ ram Hole Size Csgl WtlFt Gra,. conn/ Length Top Btm Tbg O.D. MDITVD MDITVD 61/8" 4 Y2" 12.6# L-80 IBT -3,665' 11 ,585 / 8404' 15,250'/8,743' Tubing 4 Y2" 12.6# L-80 IBT -11,555' GL 11,585/8404' Directional KOP: 111,735' MO Maximum Hole Angle: Close Approach Well(s): Survey Program: OS15-07C Sidetrack -620 at 7900' MO (above window) -500 at the whipstock setting depth -920 in 6 1/8" horizontal section Three close approach wells have been identified: / L2-25 with ctr-ctr distance of 915' at 14,250' MO, and OS18-10 with ctr-ctr distance of 985' at 14,540' MO OS18-09B with ctr-ctr distance of 1124' at 13,600' MO All wells pass minor risk criteria of 1/200 with allowable deviations in excess of 800'. All areas of interest are well within the reservoir section; both collision probability and potential impact are minimal. MWO IFR/Cassandra. Page 1 ') ') Logging Program 6 1/8" Production: Sample Catchers - over entire interval, samples described and discarded. Drilling: MWD Dir/GR/Res + ABI- Real time GR/Res throughout entire interval. Open Hole: None Cased Hole: Post Rig memory CNL Formation Markers Formation Tops (wp03) MD TVDss TVDbkb Comments CM3/K10rrop COLVillE MOSTN -6300 CM2 -6754 CM1 -7446 THRZ -7778 BHRZ -7969 lCU -8001 TJAfTOP KINGAK A -8069 SAG RIVER SS -8164 SHUBLIK -8207 TOP SADlEROCHITrrZ4B -8268 ~,<;: TZ2/ KOP 11 ,735 -8439 8497 3300 psi (7.5 ppg EMW) ~ TZ1B 12,201 -8642 8700 ±10' uncertainty TZ1A 12,310 -8676 8734 ±10' uncertainty BSAD -8702 8760 Not Penetrated TO 15,250 -8685 8743 TD Criteria: Reach planned TD to drain target area unless drilling conditions deteriorate. Mud Program Section Milling Mud Properties: QUIKDRll-n Density (ppg) Viscosity PV 8.4 - 8.5 45 - 55 4 - 7 I Whip Stock Window 7" 26# YP MBT pH 25 - 30 <3 8.5 - 9.0 API FI N/C Production Mud Properties: QUIKDRll-n Density (ppg) Viscosity PV 8.4 - 8.5 45 - 55 4 - 7 I 6 1/8" hole section YP MBT pH 20 - 28 <3 8.5 - 9.0 API FI N/C Cement Program Casing Size í 4 ¥2" 12.6#, L-80 Solid Liner Basis: lead: None Tail: Based on 3515' of 4 Y2" x 6 1/8" open hole annulus with 40% excess + 85' shoe + 150 liner lap + 200' DP x 7" liner annulus .. Tail TOC: 11,585' MD I 8404' TVD-bkb (Top of Liner) / Fluid Sequence & Volumes: Pre 15bbls CW100 Flush Spacer lead Tail 20 bbls MudPUSH Xl at 9.5 ppg None 6-- ~). Is, 512 ft3 4~sacks Class G wI Gas-Block@15.8ppg, (;Y.. ft3/sack OS 15-07C Sidetrack Page 2 , ) ) Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9·5/8" Casingn" Liner Test Planned completion fluids 13-5/8", 5M, 3 MPL Gates with Annular (Hydril- 13-5/8" GK) 3300 psi (7.5 ppg @ 8500' TVD) 2450 psi (.10 psi/ft gas gradient to surface) Infinite___,,--; Rams test t(Xf,5Q(}15si/250 psi. Annular tes~50b psi/250 psi 3500 psi surface pressure / 8.6 ppg Seawater / 7.2 ppg Oiesel Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Sidetrack and Complete Procedure SUmmary Pre-riQ Operations: In preparation for the sidetrack the following pre-work has been performed: -/ Tested the OA to 2000 psi - passed 4/16/03 -/ Changed the uppermost two GLMs to dummy valves 5/02/03 -/ Loaded the IA with 386 bbls dead crude 5/02/03 and tested the IA to 3000 psi. -/ Tested the FMC Gen III 9-5/8" mandrel pack-off and tubing hanger seals - passed 5/11/03 -/ Cycled tubing hanger and inner casing LOS 5/11/03. Remaining Work: 1. Lock open the SSSV, drift & tag top of 2 3/8" liner. 2. RIH with a 3 Y2" Weatherford FH cement retainer on coiled tubing. Set retainer at 11,825' and squeeze 10-bbls cement (full liner volume + 3 bbls) to abandon the perforations and the 2 3/8" liner. 3. Pressure test the tubing to 3500 psi against the cement retainer. Test the IA to 3500 psi. 4. Chemical cut the 3 Y2" tubing at 11,745' (13' up from the bottom of the 6th full joint above the packer, ref tally 2/24/94). This depth accounts for the tally being 6' deep to the 5/30/2003 corrected tie-in log in which the KOP is based. The depth of the cut ±5' is critical to ensure proper whipstock setting location. 5. Circulate the well to seawater and freeze protect to 2100' with diesel. Bleed well pressures to zero. Set a BPV. 6. Remove the well house. If necessary, level the pad. OS15-07C Sidetrack Page 3 ) ) RiCl Operations: 1. MIRU Nabors 2ES. 2. Pull BPV, circulate out freeze protection with seawater and reverse circulate the well with seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. /' 4. Pull 4 %" x 3 %" tubing from the cut at 11,750'. ,.- 5. MU window milling BHA and drift the the casing to the top of fish. Test casing to 3500 psi. Change the well over to 8.4 ppg drill-in mud, POH. 6. RIH with 7" Baker bottom-trip anchor whipstock assembly. Orient whipstock and set on tubing stub. Mill window in 7" casing at ±11 ,735' MD plus 20' minimum open hole below the window top. Perform FIT to 10.0 ppg EMW. ;r 7. RIH with 6 1/8" directional assembly. Drill the 6 1/8" production section as per directional plan to an estimated TD of 15,250' MD. CBU, POH. /' 8. Run a 4 %", 12.6# L-80 solid production liner. Cement the liner in place, and displace well to clean seawater above liner top. POH LD DP. ..,.".... 9. R/U and RIH with Halliburton 2 Y2" dpc perforating guns. Perforate per Halliburton recommendation. POOH. 10. Run 4-1/2", 12.6# L-80 completion tying into the 4-1/2" liner top. ~ 11. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 12. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 13. Freeze protect the well to -2200' and secure the well. /"'.' 14. Rig down and move off. Post-RiQ Work: 1. Install wellhouse and flow lines. 2. MIRU slickline. Pull the ball and rod 1 RHC plug from landing nipple below the production packer. Install gas lift valves. Run slickline-conveyed CNL to determine GOC. Job 1: MIRU Hazards and Contingencies ~ No wells will require shut-in for the rig move onto DS15-07C. The well is located on the northern end of the pad on 120' cey.ers between wells 15-20A and 15-088. ~ DS15 is not an H2S site. Recent H2S data from the pad is as follows: Closest SHL Wells: Closest BHL Wells: /" 15-08B 9 ppm on 3/8/01 L2-25 None Recorded 15-20A 11 ppm on 3/6/01 15-30 18 ppm on 4/8/01 The maximum level recorded of H2S on the pad in recent history was 33 ppm on 15-44 and in 1996. » Post Permit to Drill in camp prior to spud. Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP I~." '. ,";-¡';'- ~ - .;. ... _.-....,;...- I--"",~' ....-.'" ,_ _ _. T--"- _ " . --;--.-._,i,. .. "'~'. .";I"-""'-.-Þ(.;.,--'-¡ DS15-07C Sidetrack Page 4 ) ) Job 2: De-complete Well Hazards and Contingencies )0> NORM test all retrieved well head and completion equipment. )0> The existing wellhead is an FMC Gen 3 (13-5/8" 5K) and has 5 %" LH Acme running threads on the tubing hanger. Inspect the tubing hanger after ND the tree to verify the thread type and ensure the threads are in good condition. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP "';,-.-m.w,-!,...-m.w.a,¡mm;mm¡.-¡;,"'-¡,:m:mmmm¡; J¡mm~';':;:~AAa,IJmJ¡m, Mþ'Im.I,~WJ¡,rÅI,:mm.:>~I,:m;ml,.mmm,-,-J~,,:m;Jmß,:m:¡.mmmm,:,I,:,:¡;,-m,l;¡,-,,-m.:;¡mtfim;¡,-,rm:.I!,-;,:,-,:',;;,~ijAAI AAI.I.I.!~'-,-mm,l,-;m;,4,I,I¡,:.w;m.l>m",:H¡,l;m.-¡!¡;:.:,r;,I)¡mmm,Im,¡;¡¡;;;m:mIM,I,I,I,:mmmm;,immm.IJ.},I!,\,I;K-!!.I,:UI,-.-,::.I.-,r"K,-,-,!;!ß;.I",,-K-¡'¡,I!D.I.-AAI,:,:,w,-,-m;;-mm,1,.I!!,r,;,lm,:,m.lmm,:,I!o.-,'!;!~;.:¡¡¡',I,I. Job 4: Window Mill Hazards and Contingencies )0> Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. )0> The 7" liner was cemented with 66 bbls class G cement and full returns during the 1994 sidetrack. No cement or spacer was detected while circulating off the top of liner however. The annular volume of gauge 8.5" hole and 7" casing from the shoe to the planned KOP (717') is 16.2 bbls. Two turbolators per joint are positioned on the bottom 13 joints. The KOP at 17 joints from bottom is not centralized or turbolated. Reference RP .:. "Whipstock Sidetracks" RP Illa-'llilll-:I; 1111111:m:IIIIHlln:mmllllll;:a:mllllll1111111; - -111- - ;;1- ,11111I11I11111I: _ nmlrmmm. _111. ~~mI11ml:n~lm.llmm.I',I. .~II.lmI1mllll'1111..1.1Im.lmll.II1.lm. .1. .1_11.-1I~:ln;:: ln. -m~:I:I·:lm:1111Im-:I'I··~-- :11::I:~11:11·1·1111~11:·IIII~IIIII:I-llm::~11I:1mmmnm1l:·1·· .'I1II",:m:lI1lmrl.l. .'11111.111:111:.11 .111. .11..I1IIIIIIII:m::111:111·11111111·11~la:lln:n~m:111111:1~111:11 Job 7: Drill 6 1/8" Production Hole Hazards and Contingencies )0> Two fault crossings are anticipated in this well: one at 13,250' and the second at 14,050' MD (±100'). Each fault has 10-20' of throw down to the southwest and not expected to cause lost circulation problems. )0> The Zone 1 A target is bounded by the Kavik below and the GOC above. Every effort should be made to avoid drilling too low into the Kavik for wellbore instability concerns or too high into the gas. The BHA will include ABI to improve directional control in the horizontal section. )0> Three close approach wells have been identified (see the "Directional" section for details). Though these wells are roughly 1000' from the planned sidetrack, measurement error possibilities could place the wells significantly closer under extreme worst-case scenarios. Accepting a 1/200 chance of an intersection allows ample room for drilling the wellplan. Watch for indications of magnetic interference. Cease drilling and contact the drilling manager if wellbore interference is detected. ~ KICK TOLERANCE: In the worst-case scenario of 8.8 ppg pore pressure in the Ivishak, a fracture gradient of 9.6 ppg at the 7" casing window, and 8.6 ppg mud in the hole, the kick tolerance is Infinite. Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP DS15-07C Sidetrack Page 5 ) ) Job 9: Install 4 Y2" Solid Production Liner Hazards and Contingencies » The completion design includes a 4 Y2", 12.6#, L-80 solid liner throughout the production interval. The option exists for a solid x slotted liner (Bonzai) if no faults are detected, the well is drilled without significant undulation or toeing up toward the gas cap, and consistent zone 1A reservoir properties are indicated on the logs. » Differential sticking is a concern. The 8.6ppg mud will be -700psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. » A Gas-lock type slurry is requested to ensure the best chance for zonal isolation. Reference RPs .:. "Production Liner/Casing and Cementing Guidelines" 171~ .1. .1~nl:I-_I_ -:-,,"~11111111~111tOI:!IIn:IIIQ1Im:m:Q::11~lm:mllO::l:mll- ,1:1:.111111 Job 10: DPC Perforate Production Liner Hazards and Contingencies » Observe Halliburton's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. Reference RPs .:. Follow Halliburton perforating practices and recommendations. .:. "DPC Perforating" RP IlaOOl,nUIUllllla,LII:mnllllltloammIIUllanllllmlllllmIOlllalralllllll111111Iallll'lJlllmUlllmllu:m:llln:mlll.III_.II.:tl:.-¡I.l ; II - -I - - - - U),oC I"'" ;; -II;; I ;;; - ; I;;;;;;~" 04;;1;;; ÞO.;; Job 12: Run Completion Hazards and Contingencies » Diesel will be used to freeze protect the well. The diesel flash point is 1 000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP .-JIII.IIII__IIII.III.J!I!II.I__II.',mlnlllll!III!II:1I111I11IIm:'.111111111111I11111111111111111.1111__'-1111__1. ."__1__11,11. .1.1 I lUlL .I...LlIU..1. -I . !: -IIIIIII;I:I'T -alrT'I"'· ".. Tnu--,- "11--1' mml'lIIlnlmllntIllUIIII!!II.III.II'--ILllliIIIIUUUlL.UllunIlL.UI..I. ··\--llIlrO-I:IIII".L _!mlll,... .111'·'" Job 13: ND/NU/Release RiQ Hazards and Contingencies » There are no identified hazards particular to this phase of the operation. Reference RP .:. "Freeze Protecting an Inner Annulus" RP DS15-07C Sidetrack Page 6 . TREE =. WELLHEAD = ACTuÄTÒR;'; KB. ELEV = äF~8..EV ;; KOP= . ~~~~~~IE3~. Datum MD = Datum ìVD = FMC GEN 3 CrN BA KER 67' 2796' 98 @ 12619' ........... "".""..."",,,,,. 12317' 8800'SS ) 15-07 B 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2395' ~ Minimum 10 = 1.995" @ 11854' TOP OF 2-3/8" LNR 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 1-1 I TOP OF 3-1/2" TBG 1-1 I TOP OF 7" LNR 1-1 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 I TOP OF 2-3/8" LNR, 4.6# 1-1 4020' 4020' 10014' 10193' 11854' 3-1/2" TBG, 9.2#, L-80, 0.0076 bpf, ID = 2.992" 1-1 12002' " I r 1 ~ ~ 1 ... . I) /' ) SAFETY NOTES: 70° @ 12127' AND 90° @ 12230' 2106' 1-1 4-1/2" CAMCO TRDP SSSV NIP, ID = 3.812" ~ GAS LIFT MANDRELS ST MD ìVD DEV TYÆ VLV LATCH PORT DATE 1 3048 3040 15 TGPD TG L 2 6637 5756 51 TGPDX TG 3 10386 7667 52 TGPDX TG 4 11581 8402 49 TGPDX TG / 1m ~ I I ----1 I I I I 4018' 1-1 4-1/2" X 3-1/2" XO 1 11854' 11894' 11946' 11968' 11989' 1-1 BAKER DEPLOYMENT SLEEVE 1 1-13-1/2" OTIS X NIP, ID = 2.813" (BEH. LNR) 1-1 7" x 4-1/2" BAKER SABL-3 PKR 1 1-1 3-1/2" OTIS X NIP, ID = 2.813" 1 1- 3-1/2" PARKER SWN NIP, ID = 2.76" (BEH. LNR) - MILLED OUT 1-1 3-1/2" TUBING TAIL WLEG 1 1-1 ELMD TT LOGGED 04/10/94 1 12002' 12013' 7" LNR, 26#, NT-80 1-1 12452' 1 ÆRFORATION SUMMARY REF LOG: MWD-RESISTIVITY ON 02/20/94 ANGLE AT TOP ÆRF: 84 @ 12950' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 12950-13100 S 08/14/00 1-11/16" 4 13156-13158 S 08/14/00 1-11116" 4 13158-13160 0 08/14/00 1-11116" 4 13400-13558 0 08/14/00 1-11/16" 4 13640-13835 0 08/14/00 DATE 1984 09/25/00 01/23/01 08/15/00 02/10/02 REV BY COMMENTS ORIGINAL COMA..ETION 51S-lsl CONVERTED TO CANVAS SIS-MD FINAL B SIDETRA CK RNlTP CORRECTIONS DATE 05/29/03 7" WINDOW 12114 '- 12118' I PBTD 1-1 13838' ~ 12-3/8" LNR, 4.6#, L-80, FL4S, .0039 bpf, ID = 1.995" 1-1 13875' REV BY COMMENTS PGS Corrections (pre-rig) PRUDHOE BA Y UNrr WELL: 15-07B ÆRMrr No: 200-0980 API No: 50-029-21166-02 SEC 22, T11N, R14E BP Exploration (Alaska) )S-07C Propost..ì:I ~ J . TREE ~ FMC GEN 3 WELLHEAD = CrN 'A·CTiJÄTÔR;--'·~-"-BÃKËR· ....",....·.'."'.'."w,"~........................",·...·...",....'."";...",·.'.,',..................... .... ..,.w...........'....",..........'.· KB. ELEV = 67' 'BF~-ECB7";;^-'-,····_'W_._WN._.M".W."'.M..^'..'_w.,.^ ^RÕ^p··;w".w_'''.''''_w_.w''''·-''·····27'9S;· §~:~~~~.::_".".,.,.,_...,..,.,...."...'..M...'.^.. Datum MD = w..",..,"",.",.,.,...,·........"'.w.".,"'",.,"'"..,'.',,,.,,.w." ·,·,·,"",·,·,·....·,w,'"",.,w...w,.,.,.,·,..,.."".,... Datum "TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 1--1 2395' r-.JI Minimum ID = 3.725" @ XN Nipple TUBING TAIL 1 TOP OF 7" LNR 1-1 10014' 1 "m 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 10193' ~ Ii ~ 11500' 1-1 4-1/2" x NIP, ID = 3.813" I 11530' 1-1 7" x 4-1/2" BAKER SABL-3 PKR 1 11560' 1-1 4-1/2" x NIP, ID = 3.813" I 11580' 1-1 4-1/2" XN NIP, ID = 3.725" I ~ 11590' 1-1 4-1/2" TUBING TAIL WLEG 1 11735' 1-1 7" Window I Whipstock ~ /' 14 1/2" 12.6# L-80 Liner PBTD 1-1 15,160' 14 1/2" LinerlSection TO 1-1 15,250' / L 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 1-1 11590' I.,/' 1 TOP OF 41/2" LNR, 12.6#1-1 11585' 1 ~ I Top of "B" Sidetrack Fish 1-1 11755' I 7" LNR, 26#, NT-80 1-1 12452' I PERFORA TION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE DATE 1984 08/15/00 04/23/03 REV BY COMMENTS ORlGINA L COMA-ErION SIS-lsl B SIDETRACK PGS Proposed C Sidetrack DATE REV BY COMMENTS SAFETY NOTES: 2100' 1-1 4-1/2" Landing Nipple, ID = 3.813" ~ GAS LIFT MANDRELS ST MD "TVD DEV TYÆ VLV LATCH PORT DATE 3 TBD 1 1/2" 2 TBD 1 1/2" 1 TBD 1 1/2" I "B" Sidetrack TD (2 3/8" LNR) -I 13875' I PRUDHOE BAY UNIT WELL: 15-07C PERMIT No: 200-0980 API No: 50-029-21166-03 SEC 22, T11N, R14E BP Exploration (Alaska) Plan: 15-07C wp03 (l5·07/Plan I5·07C) Created By: Ken Allen Date: 4121/2003 Checked: Date: Reviewed: Dale: SURVEY PROGRAM Depth Fro J:>eptb To SuryeyiPlan Tool 11735.00 15250.1)4 PIanœd: 15-07C wp03 V' MWD-cIFR~MS REFERENCE INFORMATION Co-ordinate (NtE) Rerereoce: Well Centre: 15-07. True North Vertical (TVD) Refcrenœ: 57.7T 57.77 Sc<tioo (VS) Reference: SloI· (O.OON,O.OOE) M"",,-un.x1 Depth Refefl.'nce: 57.77' 57.77 Cakulalion Method: Minimtnn Curvature (,()~1I'ANY DETAILS ('aku13lioll McthnJ: MínímumC"løvatun: (:nor Sysh:m: IS("\VSA &-311 MClhtJd; Trav CylillLkr N.)rth Em,r Swfacc: Elliplical ' Casing. Wamins:, Method: Rul...-s Ibs~.:d bp r~.·; ~ WELL DETAILS Nan;, -Nt·S ·EJ·W NOI1hing Ea.<1ing Latitude Longitudo Slot 15-07 112455 1024.20 5998555 677294.46 70"17'46.296N l4&o33·51.360W NtA TARGET DETAILS Nan;, TVD .Nt·S ·EJ·W NO<thing Ea.sting Shape 15-07C T3 8122.77 6101.80 6856.91 5966253.00 684005.00 Point 15-01C T2 8139.77 5511.56 6815.89 5965656.00 683918.00 Point 15-07C T4 8142.11 6694.15 6850.79 5966839.00 683985.00 Point I5-07C landing 8141.77 4606.06 5510.08 5964720.00 682694.00 Point 15-07C ntI tip 8741.77 6083.28 615135 5966226.00 683900.00 Point SECTION DETAILS +£1- W DLeg TFace VSec Targe 4925.46 0.00 0.00 6547.48 5061.61 ".1-0.00 22.69 6695.3 7 5310.19 0.00 0.00 6952.60 5510.08 10.00 -1.12 7160.10 15-07C landing 5545.82 8.00 -85.74 7198.17 6481.21 0.00 0.00 8217.57 6815.89 8.00 -89.52 8726.91 15-07C T2 6859.17 8.00 -85.65 8932.51 .~ 6857.24 0.00 0.00 9149.91 6856.97 6.00 -172.89 9172.99 15-07C T3 6856.43 4.00 -179.91 9208.28 6850.79 0.00 0.00 9578.36 15-07C T4 FORMATION TOP DETAILS No. TVDPath MDPath Formation I 8496.77 11734.68 1Z2 2 8699.77 12201.43 TZIB 3 8733.77 12310.93 1Z1A CASING DETAILS Size 4.500 No. TVD MD Name 8742.77 5250.03 4 1/2' +N/-S 4327.79 4400.06 4513.72 4606.06 4623.95 5125.28 5511.56 5761.45 6074.50 6107.80 6158.84 6694.15 TVD 8496.97 8590.02 8703.78 8747.77 8747.69 8743.29 8739.77 8734.19 8723.35 8722.77 8723.68 8742.77 All TVD depths are ssTVD plus 57.77'101" RKBE. Azi 57.98 65.43 65.43 65.00 61.81 61.81 20.00 359.65 359.65 359.40 359.40 359.40 Inc 50.47 67.40 67.40 90.00 90.24 90.24 90.50 91.98 91.98 90.00 87.96 87.96 MD 11735.00 11915.80 12211.86 12437.86 12477.84 13539.11 14061.74 14316.76 14630.00 4663.31 4714.37 5250.04 Sec I 2 3 4 5 6 7 8 9 10 II 12 #.sf' #'§' #, 4'# 1 riP I I ¡P I I -I ,I ,I ,I 8000- ~ I I 0000 5-07C wp03 1/2' ~'õjTf 4 8742m'T\lI); .. ·r 9600 "'/<bo End Dir Start Dir4/100' : Start Dir 6íl 00' : 14630' MD, 14316.76' MD, 8734.19' TVD 8400 Section at 45.66° [400ft/in] 7600 Slart Dir 101100': 11735' MD. 8496.97'TVD 1915.8' MD, 8590.02' TVD 00': I St: f 7200 6400 8800 (15-07/Plan 15-07C) Plan: 15-07C wp03 Crealed By: Ken AJlen Checked: SURYEY PROGRAM Depth Fm Depth To Sur.-e)'lptan Tool Iï35.00 15250.Q.I Plann<d: ¡5-07C wp03 Y MW~IFR~MS REFERENCE INFORMATION WeD Centre: 15-07. True North 57.77" 57.77 5101- (O.OON,O.OOE) 57.77' 57.77 Minimum ClD'\<J.ture Co-on.Jina~ tNl£) Refcn-."tKc: Yert;';.1 (lVD) Refe",,,,,,: Sec'ioo (VS) Refe",,,,,,: MC3:!>W\..xI Depth Rcfen..'I1Cc: C.kubtion Melhod: bp §~~~ ~-...'~ --,t'-- Dale: Dale: WELL DETAILS Na~ "N'-S ~E!-W Northing Easting '-"'ilud.: Longitlrle 510' Size 15·07 1124.55 102420 595998555 677294.46 70017"462961'1 148"H51360W WA 4.500 SECTION DETAILS See MD ne Azi TVD +N/-S +EI-W DLeg TFaee VSee Targe I ] 1735.00 50.47 57.98 8496.97 4327.79 4925.46 0.00 0.00 6547.48 2 ] 19]5.80 67.40 65.43 8590.02 4400.06 5061.61 ]0.00 22.69 6695.37 3 12211.86 67.40 65.43 8703.78 4513.72 5310.19· 0.00 0.00 6952.60 4 12437.86 90.00 65.00 8747.77 4606.06 5510.08 ]0.00 -1.12 7160.]0 ] 5-07C landing 5 12477.84 90.24 61.81 8747.69 4623.95 5545.82 8.00 -85.74 7198.]7 6 13539.] I 90.24 61.81 8743.29 5]25.28 6481.2 ] 0.00 0.00 8217.57 7 ]4061.74 90.50 20.00 8739.77 5511.56 6815.89 8.00 -89.52 8726.91 15-07C T2 8 14316.76 91.98 359.65 8734.19 5761.45 6859.17 8.00 -85.65 8932.51 9 ]4630.00 91.98 359.65 8723.35 6074.50 6857.24 0.00 0.00 9]49.91 10 ]4663.31 90.00 359.40 8722.77 6]07.80 6856.97 6.00 -] 72.89 9] 72.99 ] 5-07C T3 II ]4714.37 87.96 359.40 8723.68 6] 58.84 6856.43 4.00 -179.91 9208.28 12 ] 5250.04 87.96 359.40 8742.77 6694.15 6850.79 0.00 0.00 9578.36 ] 5-07C T4 TARGET DETAILS Narœ l'ID ~NI-S ~E/-W Northing Easting Shape .~ 15-07C T3 8722. 6107.80 6856.97 5966253.00 684005.00 Point 15-07C T2 8739. 5511.56 6815.89 5%5656.00 683978.00 Point 15-07C T4 8742. 6694.15 6850.79 5966839.00 683985.00 Point 15-07C landing 8747. 4606.06 5510.08 5964720.00 682694.00 Point 15-07C fln tip 8747. 608328 6751.35 5966226.00 683900.00 Point CASING DETAILS Name FORMATIONTOPDETA~S Fonnation TZ2 TZIB TZIA 112' MDPath 11734.68 ]2201.43 12310.93 4 5250.03 No. TVDPath 8496.77 8699_77 8733.77 MD TVD 8742.77 No. RKBE. Calt."1Jlar¡no MdhnJ: Mmlßum Cw\'alW\' ~: t(~~~~~ ~~~~~·~T NnnJt Em'f Surfac!.:': Elliplk.-al . Casing WJmi~ MdD....J: Ru~s IbSl..'\Í All TVD depths are ssTVD plus 57. 77'for 5250.04'MDr8742.7f'TVP Depth Tota --/ "v_ 15-07C wp03 --r¡r--4 ]/2' 1-~ i : ]47]4.37' MD, 8723.68' TVD 4/100': 14663.3]' MD, 8722.77'TVD 6/100' : ]4630' MD, 8723.35'TVD 4316.76' MD, 8734.19' TVD MD, 8743.29'TVD I I I I I 7200 7800 5-}7CT4 . 1 , 15-07C n ~End Dir lip t==H-.mi' T::~tart D.il , t · ¡- ':~tart DII rnn, i I ¡ EndDir 1m .:/m I i . 1;,/ t5~07C T2 , .B . . .~·'/II ./ . \ ! . . ¡ (m rm SI tl:Óit 8/100' :i3539.]]' i··,·, ..Ið'm.n 1m. 15c07C landin~/,"/. f t··· /k>l::j] ,"'77~"MO. 87'7~9'TVOI' /' Start Dir all 00' : 12437,86' MD, 8747.77TVr ~,///-......... Start Dír 10/100';122.·11.8 S'Mb.8 70 3. 7&'TVP .... ~"" . , , EndDir : 859Q.02'TV) . 1m Shirt Dir 10/10 I . I I I I I I I I I 6600 West( - )/East( +) [600ft/in] 8496.97'TVJ 6000 915.&' MDj 735' MD, 5400 4800 6600 6000 5400 4800 4200 ª .::: o o :£. ~ 1: o ~ Õ C/J ) BP KW A Planning Report MAP COl11pany: Field: Site: Well: WeUpath: BP Amoco Prudhoe Bay PBDS 15 15-07 Plan 15-07C Date: 4/21/2003 Time: 16:00:16 Page: Co-ordinate(NE) Reference: Well: .15~07, . True North Verticàl(TVD) Reference: 57.77' 57.8 Section (VS) Reference: Well (0.00N,O.00E,45.66Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft 676296.98 ft Latitude: Longitude: North Reference: Grid Convergence: 15-07 15-07 Well Position: Well: Slot Name: +N/-S 1124.55 ft +E/-W 1024.20 ft Position Uncertainty: 0.00 ft 5959985.55 ft 677294.46 ft Northing: Easting : Latitude: Longitude: Wellpath: Plan 15-07C Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: 57.77' 4/7/2003 57548 nT Depth From (TVD) ft 0.00 +N/-S ft 0.00 Height 57.77 ft Plan: 15-07C wp03 Date Composed: Version: Tied-to: Principal: Yes Casing Points ) Alaska, Zone 4 Well Centre BGGM2002 70 17 35.236 N 148 34 21.213W True 1.34 deg 70 17 46.296 N 148 33 51.360 W 15-07B 11735.00 ft Mean Sea Level 25.95 deg 80.84 deg Direction deg 45.66 4/7/2003 8 From: Definitive Path 15250.03 8742.77 4.500 6.125 41/2" Formations TVD Litþology Dip Angle Dip Direction ft deg deg 11734.68 8496.77 TZ2 0.00 0.00 12201.43 8699.77 TZ1B 0.00 0.00 12310.93 8733.77 TZ1A 0.00 0.00 Targets Map Map <-- Latitude --> <- Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 15-07C T3 8722.77 6107.80 6856.97 5966253.00 684005.00 70 18 46.335 N 148 30 31.334 W 15-07C T2 8739.77 5511.56 6815.89 5965656.00 683978.00 70 18 40.471 N 148 30 32.548 W 15-07C T4 8742.77 6694.15 6850.79 5966839.00 683985.00 70 18 52.101 N 148 30 31.499 W 15-07C landing 8747.77 4606.06 5510.08 5964720.00 682694.00 70 1831.576N 148 31 10.657 W 15-07C flt1 tip 8747.77 6083.28 6751.35 5966226.00 683900.00 70 18 46.094 N 148 30 34.416 W ) BP ) KW A Planning Report MAP Company: BP Amoco Date: 4/21/2003 Time: 16:00:16 Page: 2 Field: Prudhoe Bay Co-ordinate(NE).Reference: Well: .15-07, True North Site: PB DS 15 Vertical (TVD) Reference: 57.77' 57.8 Well: 15-07 SeCtion (VS) Reference: Well (0.00N;0.00E;45.66Azi) Wellpath: Plan 15-07C Survey Calculatioö Method: Minimum Curvature Db: Oracle 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 11735.00 50.47 57.98 8496.97 4327.79 4925.46 0.00 0.00 0.00 0.00 11915.80 67.40 65.43 8590.02 4400.06 5061.61 10.00 9.37 4.12 22.69 12211.86 67.40 65.43 8703.78 4513.72 5310.19 0.00 0.00 0.00 0.00 12437.86 90.00 65.00 8747.77 4606.06 5510.08 10.00 10.00 -0.19 -1.12 15-07C landing 12477.84 90.24 61.81 8747.69 4623.95 5545.82 8.00 0.59 -7.98 -85.74 13539.11 90.24 61.81 8743.29 5125.28 6481.21 0.00 0.00 0.00 0.00 14061.74 90.50 20.00 8739.77 5511.56 6815.89 8.00 0.05 -8.00 -89.52 15-07C T2 14316.76 91.98 359.65 8734.19 5761.45 6859.17 8.00 0.58 -7.98 -85.65 14630.00 91.98 359.65 8723.35 6074.50 6857.24 0.00 0.00 0.00 0.00 14663.31 90.00 359.40 8722.77 6107.80 6856.97 6.00 -5.95 -0.74 -172.89 15-07C T3 14714.37 87.96 359.40 8723.68 6158.84 6856.43 4.00 -4.00 -0.01 -179.91 15250.04 87.96 359.40 8742.77 6694.15 6850.79 0.00 0.00 0.00 0.00 15-07C T4 -- .._."-_...~"'-----'---' - -,.-. -~- Survey MD Inel Azim TVD Sys TVD MapN MapE VS DLS TFO Tool/Comment ft deg deg ft ft ft ft ft deg/100ft deg 11734.68 50.47 57.98 8496.77 8439.00 5964427.90 682115.94 6547.24 0.00 0.00 TZ2 11735.00 50.47 57.98 8496.97 8439.20 5964428.04 682116.14 6547.48 1.10 307.42 MWD+IFR+MS 11750.00 51.86 58.71 8506.38 8448.61 5964434.40 682125.94 6558.88 10.00 22.69 MWD+IFR+MS 11800.00 56.51 60.98 8535.64 8477.87 5964455.56 682160.51 6598.17 10.00 22.23 MWD+IFR+MS 11850.00 61.19 63.01 8561 .50 8503.73 5964476.51 682197.80 6639.21 10.00 20.90 MWD+IFR+MS 11900.00 65.91 64.87 8583.76 8525.99 5964497.09 682237.53 6681.70 10.00 19.85 MWD+IFR+MS 11915.80 67.40 65.43 8590.02 8532.25 5964503.50 682250.54 6695.37 10.00 19.02 MWD+IFR+MS 12000.00 67.40 65.43 8622.37 8564.60 5964537.48 682320.45 6768.53 0.00 0.00 MWD+IFR+MS 12100.00 67.40 65.43 8660.80 8603.03 5964577.84 682403.48 6855.41 0.00 0.00 MWD+IFR+MS 12200.00 67.40 65.43 8699.22 8641 .45 5964618.19 682486.51 6942.30 0.00 0.00 MWD+IFR+MS 12201.43 67.40 65.43 8699.77 8642.00 5964618.77 682487.70 6943.54 0.00 0.00 TZ1B 12211.86 67.40 65.43 8703.78 8646.01 5964622.98 682496.36 6952.60 0.00 0.00 MWD+IFR+MS 12250.00 71.22 65.35 8717.25 8659.48 5964638.60 682528.43 6986.18 10.00 358.88 MWD+IFR+MS 12300.00 76.22 65.25 8731.27 8673.50 5964659.67 682571.53 7031.37 10.00 358.91 MWD+IFR+MS 12310.93 77.31 65.23 8733.77 8676.00 5964664.35 682581.09 7041.39 10.00 358.94 TZ1A 12350.00 81.21 65.16 8741.05 8683.28 5964681.26 682615.53 7077.56 10.00 358.94 MWD+IFR+MS 12400.00 86.21 65.07 8746.52 8688.75 5964703.23 682660.09 7124.41 10.00 358.96 MWD+IFR+MS 12437.86 90.00 65.00 8747.77 8690.00 5964720.00 682694.00 7160.10 10.00 358.97 15-07C landing 12450.00 90.07 64.03 8747.76 8689.99 5964725.48 682704.83 7171.59 8.00 274.26 MWD+IFR+MS 12477.84 90.24 61.81 8747.69 8689.92 5964738.73 682729.31 7198.17 8.00 274.26 MWD+IFR+MS 12500.00 90.24 61.81 8747.60 8689.83 5964749.66 682748.59 7219.46 0.00 0.00 MWD+IFR+MS 12600.00 90.24 61.81 8747.18 8689.41 5964798.96 682835.58 7315.51 0.00 0.00 MWD+IFR+MS 12700.00 90.24 61.81 8746.77 8689.00 5964848.26 682922.58 7411.57 0.00 0.00 MWD+IFR+MS 12800.00 90.24 61.81 8746.35 8688.58 5964897.56 683009.57 7507.62 0.00 0.00 MWD+IFR+MS 12900.00 90.24 61.81 8745.94 8688.17 5964946.86 683096.57 7603.68 0.00 0.00 MWD+IFR+MS 13000.00 90.24 61.81 8745.52 8687.75 5964996.17 683183.56 7699.73 0.00 0.00 MWD+IFR+MS 13100.00 90.24 61.81 8745.11 8687.34 5965045.47 683270.55 7795.78 0.00 0.00 MWD+IFR+MS 13200.00 90.24 61.81 8744.70 8686.93 5965094.77 683357.55 7891.84 0.00 0.00 MWD+IFR+MS 13300.00 90.24 61.81 8744.28 8686.51 5965144.07 683444.54 7987.89 0.00 0.00 MWD+IFR+MS 13400.00 90.24 61.81 8743.87 8686.10 5965193.37 683531.53 8083.94 0.00 0.00 MWD+IFR+MS 13500.00 90.24 61.81 8743.45 8685.68 5965242.67 683618.53 8180.00 0.00 0.00 MWD+IFR+MS 13539.11 90.24 61.81 8743.29 8685.52 5965261.96 683652.56 8217.57 0.00 0.00 MWD+IFR+MS 13550.00 90.24 60.94 8743.24 8685.47 5965267.39 683661.98 8228.05 8.00 270.48 MWD+IFR+MS 13600.00 90.28 56.94 8743.02 8685.25 5965294.19 683704.18 8276.70 8.00 270.48 MWD+IFR+MS 13650.00 90.31 52.94 8742.76 8684.99 5965323.86 683744.41 8326.04 8.00 270.46 MWD+IFR+MS 13700.00 90.34 48.94 8742.48 8684.71 5965356.26 683782.47 8375.81 8.00 270.44 MWD+IFR+MS 13750.00 90.37 44.94 8742.17 8684.40 5965391.24 683818.18 8425.79 8.00 270.42 MWD+IFR+MS 13800.00 90.39 40.94 8741.84 8684.07 5965428.63 683851.36 8475.72 8.00 270.39 MWD+IFR+MS 13850.00 90.42 36.94 8741.48 8683.71 5965468.24 683881.85 8525.37 8.00 270.37 MWD+IFR+MS ) BP ) KW A Planning Report MAP Company: BP Amoco Date: 4/21/2003 Time: 16:00:16 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-07, True. North. Site: PB DS 15 Vertical (TVD)Reference: 57.77' 57.8 Well: 15-07 Section (VS) Reference: Well (0.OON,O.00E,45.66Azi) Wellpath: Plan 15-07C Survey Calculation Method: Minimum CurVature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS D.LS TFO Tool/Comment ft deg deg ft ft ft ft ft deg/100ft deg 13900.00 90.44 32.94 8741.11 8683.34 5965509.88 683909.50 8574.48 8.00 270.34 MWD+IFR+MS 13950.00 90.46 28.94 8740.71 8682.94 5965553.35 683934.18 8622.83 8.00 270.31 MWD+IFR+MS 14000.00 90.48 24.94 8740.30 8682.53 5965598.43 683955.77 8670.17 8.00 270.28 MWD+IFR+MS 14050.00 90.50 20.94 8739.87 8682.10 5965644.91 683974.16 8716.28 8.00 270.25 MWD+IFR+MS 14061.74 90.50 20.00 8739.77 8682.00 5965656.00 683978.00 8726.91 8.00 270.21 15-07C T2 14100.00 90.73 16.95 8739.36 8681.59 5965692.55 683989.26 8760.93 8.00 274.35 MWD+IFR+MS 14150.00 91.03 12.96 8738.59 8680.82 5965741.13 684001.02 8803.90 8.00 274.31 MWD+IFR+MS 14200.00 91.32 8.97 8737.56 8679.79 5965790.41 684009.36 8845.00 8.00 274.25 MWD+IFR+MS 14250.00 91.61 4.98 8736.28 8678.51 5965840.14 684014.26 8884.00 8.00 274.17 MWD+IFR+MS 14300.00 91.89 0.99 8734.75 8676.98 5965890.08 684015.68 8920.73 8.00 274.07 MWD+IFR+MS 14316.76 91.98 359.65 8734.19 8676.42 5965906.83 684015.38 8932.51 8.00 273.95 MWD+IFR+MS 14400.00 91.98 359.65 8731.31 8673.54 5965989.97 684012.90 8990.28 0.00 0.00 MWD+IFR+MS 14500.00 91.98 359.65 8727.84 8670.07 5966089.86 684009.93 9059.68 0.00 0.00 MWD+IFR+MS 14600.00 91.98 359.65 8724.38 8666.61 5966189.75 684006.96 9129.09 0.00 0.00 MWD+IFR+MS 14630.00 91.98 359.65 8723.35 8665.58 5966219.72 684006.07 9149.91 0.00 0.00 MWD+IFR+MS 14650.00 90.79 359.50 8722.86 8665.09 5966239.70 684005.45 9163.78 6.00 187.11 MWD+IFR+MS 14663.31 90.00 359.40 8722.77 8665.00 5966253.00 684005.00 9172.99 6.00 187.11 15-07C T3 14700.00 88.53 359.40 8723.24 8665.47 5966289.67 684003.75 9198.35 4.00 180.09 MWD+IFR+MS 14714.37 87.96 359.40 8723.68 8665.91 5966304.02 684003.26 9208.28 4.00 180.09 MWD+IFR+MS 14800.00 87.96 359.40 8726.73 8668.96 5966389.54 684000.34 9267.44 0.00 0.00 MWD+IFR+MS 14900.00 87.96 359.40 8730.30 8672.53 5966489.41 683996.94 9336.53 0.00 0.00 MWD+IFR+MS 15000.00 87.96 359.40 8733.86 8676.09 5966589.28 683993.53 9405.61 0.00 0.00 MWD+IFR+MS 15100.00 87.96 359.40 8737.42 8679.65 5966689.16 683990.12 9474.70 0.00 0.00 MWD+IFR+MS 15200.00 87.96 359.40 8740.99 8683.22 5966789.03 683986.71 9543.79 0.00 0.00 MWD+IFR+MS 15250.04 87.96 359.40 8742.77 8685.00 5966839.00 683985.00 9578.36 0.00 0.00 15-07C T4 ~.~~~~~~~~~,~~=--~_._~ ~--~~-~~--~_.--..== ~~~-- I:~ 0 5 5 0 6 2 DATE CHEC!( í\lO. ---474720-0-3--- --U55UB2-- L-_..~·DïÎ :~~:.=~~.=~~~~NO!CE / CREDIT MEMO 4/4/2003 INV# CK040103L VENDOR I~SCRIPTION ~_-'_ - GROSS -~--- __.!?~~~~N-;~~~~·~·_~~~[~:~=~·.=~=~~.~:~~.~-···..·~··· ----1 PERMIT TO DRILL FEE _po, íFJ I r' .. , - ------~------~_._--------------- --. ~ ~~~~---=----- ---]--------=~~=~~~~ Ill!: I\TmCllEO CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. .._-----------~-~_._-- -- - ~~ -~---~~-- BP EXPLORATION, (ALASKA) INC. PI1UDHOE BAY UNIT PO BOX '/96612 ANCHOHAGE, AK 995'19~6612 NATIONAL CITY BANK Ashland, Ohio 56-389 412 NouP 055062 CONSOLIDATED COMMERCIAL ACCOUNT PAY: B P t:4~ 'T' .! . ..'.dJ., ::::)i TO THE ORDER OF: ALASKA OIL & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 DATE AMOUNT -~~I April 4, 2003 *******$100.00****J . NOT VALlF~:7~.~'~~~YS .... . ,_-~.J. '" .----- -----.---- - --_..~---~- -- ~.~~~~~ ---..~~~~--- II- 0 5 SOb 2 II- ~ : 0... L 2 0 :18 Eì 5 I: 0 ~ 2 7 8 9 b liD ) ) . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production. should continue to be reported as a function· of the original API number, stated above. BOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (SO 70/80) from records, data and logs acquired for well (name on permit). PäOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 1~~~ig@~à~~~~~):~1i Company _~~E~ELs)BAI1QtHALASJ~AH~~ Well Name: E.RllQtLOJ;J3.AY_U~lI_l5-:ØLÇ Program J1EV Well bore seg 0 PTD#: 2030970 Field & Pool __EB.UDJiQEJ3AY4-ERUDtlQE-OlL:_6AOJ..5_0 Initial Classrrype -DE..'lL1::..QLL_ GeoArea .890 Unit 116..~ On/Off Shore _00_ Annular Disposal 0 Administration 1 P~uoit fee attached. . _ . _ . _ . _ . _ _ _ _ _ _ _ . _ _ _ _ . . _ . _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ Y~$ _ _ _ _ _ _ . . . . _ . _ _ _ _ _ _ _ _ . _ . _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ . . _ . . . 2 .Leas~.n!Jmber .appropriate_ _. _ . . . _ . _ _ . . _ . . _ . . . . _ . _ . . . _ . . _ _. . Y~$ . _ . . . . . . . . . . _ _ . . . _ . . . . . . _ _ . _ _ . _ . . . . _ . _ _ . _ . 3 .U.nlq!Je well. n.arn~ .a[1d 1Jl!.n:!b.er . . . . . . . . . . . _ _ . . _ . _ _ . . _ . _ _ . _ . _ _ _ . . . . . _ . .Y~$ _ . . _ . . . . . . . . . . _ _ . _ . _ _ . . . . . . . . . _ . _ . . . . . . . . . . . . . _ _ . . _ . _ . . _ . . . . . . . _ . _ . _ . . . . . . . 4 _W~IIJQcat~d in_a_d.efil1ed_PPol_ . . _ _ . . . . . . . . . . . _ . . . . _ _ . . . . _ . . . . . _ _ _ . . _ Y~$. _ . . _ . . . . . _ . . _ . _ _ _ _ _ _ _ . _ . _ _ _ . _ _ _ . . _ _ _ . . . _ _ . _ _ _ _ . . _ _ _ . _ _ . . _ . . _ _ . _ _ _ _ _ _ . . . 5 .W~IIJQcated pr.oper .distanceJrom driJling unitb_oundafY. _ _ . . . _ . _ . . . . . . _ _ . _ . _ _ . . Y~$. . _ _ _ _ . . . . _ . . . _ . . . . . . . . . . _ . . _ _ _ _ _ . _ . _ _ _ _ . . . . _ . .. ...... _ . . . _ . . . . . _ _ . 6 _W~IIJQcat~d pr.oper _dlstançe. from Qtb~r w~l!s. _ . _ . _ _ . . . . _ . _ . . . _ . _ _ _ _ . . . _ . . . Y~$ . . . . . . . . . . . . . . . . . _ . _ _ _ . . . _ . . . . . _ . . _ _ . _ . . _ _ . _ . . _ . . . _ . . . _ . . _ . _ _ _ . . . . . _ . 7 .S.ufficiel1t .acr~age_aYailable in.d.rilJinQ un.it _ . . . . ._ _ . . . _ . . _ _ . . _ . . . . _ . . _ _ . _ . _ .Y~$. _ . . . _ . . . _ . . . . . . . _ . _ . . . _ . . _ . _ . . . _ _ . . . _ _ . . . . _ _ . . . . _ . _ _ . . _ . _ . . _ _ _ _ _ _ _ _ _ . . . 8 Jf.d~viated, .is. weJlbQre plaUl1cJuded . . _ _ _ _ . . . _ . . . . . . _ . _ _ . . . _ . . . . . _ _ . _ . _ Y~$ . _ _ . _ _ _ . . _ _ _ . _ _ _ _ _ _ . _ _ _ _ . _ . _ . _ _ . _ _ . _ _ _ _ _ _ . . _ . . . _ _ _ _ . _ . . _ . . _ . _ . . _ . . _ _ . 9 .Qper:ator only- affected party. _ _ _ _ . . . _ . . . _ . _ . . _ _ . _ . _ _ . . . . . . _ _ _ _ _ . _ _ . . Yes. . _ . _ . _ . . _ _ _ _ . _ _ . _ _ _ _ _ . _ . . . . _ _ _ _ . . _ _ _ . _ . _ . _ . . . _ _ _ . _ _ . _ . _ _ _ _ _ _ . _ _ _ _ . _ . . . . 10 _Oper:ator bas.8.Pprppriate. b.ond lnJorce. _ _ _ . . _ _ . . . . . . . . . _ _ _ . _ . _ _ _ _ _ . _ _ _ . _ _Y~$ . . . _ _ _ _ . _ . . _ . _ _ _ _ . _ _ _ _ _ . . _ _ . . _ _ _ _ . _ _ _ _ . _ _ . . . . . _ . . . _ _ _ . _ _ _ _ . . . _ _ _ . _ . _ _ _ . _ . _ _ 11 P~rmit c.a[l be issued witbQut co.nserva.tion order. _ . _ . _ . _ _ . _ _ _ _ _ . . . _ . _ _ _ . . . _ Y~$ _ _ _ . . _ . _ _ . . _ . . _ . . _ _ _ _ _ _ . . _ . . _ . . . . . . _ _ _ . . . . . . _ _ _ _ . . _ . . . . . _ _ _ _ _ . _ _ . . . _ . . Appr Date 12 P~rn:!it c.a[l be issued wjtbQut administrati\le.approvaJ . _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ . _ _ . . . _ . _ _ . _ . . _ _ . _ _ _ . . _ . . . _ _ _ . . _ . . _ . _ . _ _ . _ _ . _ . _ . . _ . _ _ . _ . _ _ . _ _ _ . _ . . 13 Can permit be approved before 15-day wait Yes #¿ 6'ß ftJ 14 .W~IIJQcated within area an.d.strata .authorized by.l[1jectipn Ord~r # (pullO# in_c.or:nm~[1tsUFor_ .NA . . - - . - . . . . - - - - . - - . - - - . . . . . - . . - - - . . . - _ . . . . . . _ _ . . . _ . . _ _ _ . _ _ _ _ . . _ _ . _ . . _ . . _ . _ . _ (i 15 _AJI wel]s. wit.hi.n .1[4_ mile _ar~a_of reyiew jd~lJtified (Fo( Siervjc~ .w.elJ ol1lY-L _ _ _ _ _ _ . _ _ _ _ _ . _ .NA _ _ _ _ _ _ _ _ _ . . _ . _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . . . _ . . . _ . . _ _ _ _ _ _ _ . . _ . 16 Pre.-produ.cedi[1jeçtor; duratiQn.ofpre-produGtionl~ss_than.3mol1ths_(For.ser:vi.ceweIlQnJy).. NA _. _ _ _ _. _. _.. _ _.. _. _ _ _ _ _. _ _ _ _ _ _ _ _ _.. _ _. _ _ _.. _ _ _ _ _ _.. _ _ _ _ _ _ _. _ _ _ _ _. _ _ _. _ _. _._ 17 ACMP_ Finding .of Con_s i.ste [1çy_ h_a$ bee.n .i$.sued. for.tbis pr_olect . _ _ _ _ . . _ _ . _ _ _ _ . . . _ . Y ~s _ .. _ . __ . _ _ . _ _ . _ . _ . _ _ _ _ _ _ . . _ . _ . _ _ _ _ . . _ _ . _ _ _ _ . _ _ __ . . _ _ _ _ . . _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ 18 _C.o[ldu.ctor $t(Îng_p.rQvided. _ _ . . . _ _ _ _ . _ _ _ _ _ _ . _ _ . _ . _ . . _ _ _ _ _ . _ . _ _ . . _ . . . NA _ _ . _ _ _ . . . . . . _ _ . _ _ _ _ _ . _ _ _ . . _ _ _ . _ . _ . _ _ _ . . . _ _ _ _ _ _ _ _ _ . _ . _ . _ . _ _ _ . . _ _ . _ _ . _ . _ _ _ _ . _ 19 _S.ud'ac~ .casing_ pJotec.t$. alLknown. USDWs _ _ . . _ _ _ _ _ _ . . _ . . _ _ _ _ _ _ _ . . . _ . _ _ _ . NA _ _ . _ . . _ _ . . _ . . _ _ _ _ _ . _ _ _ _ . _ . _ . . _ _ . _ _ _ _ _ _ . . _ . . . _ _ _ _ _ _ _ _ _ . _ . . . _ _ . _ _ _ _ _ . _ _ . _ _ . . _ 20 _CMT.voladequ.ate.to circ.ulate.o_n.cOl1d.uctor.& $u.rf.q;g _ . . _ _ . _ . _ _ _ _ _ _ _ _ . . . . _ _ . _ .NA _ . . _ _ _ . _ . . . . . _ . _ . . . . _ . . _ . . _ . _ _ _ _ _ . . _ _ _ _ _ _ . . _ . _ _ _ _ . . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ . . _ _ _ 21 .CMT. v.ol adequ.ate.to tie-inJQng .string to.surf C$.g. . . . . . . . . _ . . . _ . . . _ _ _ _ . _ . _ . . . _NA _ _ _ _ . _ . _ . _ . _ _ . _ _ . . . . _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ . . _ . _ . . _ . _ _ _ _ . _ _ _ . . . . . . _ . _ _ _ _ . _ . . . _ . . 22 _CMT.wiHçoYer.aJlkl1o.w.n.pro.duçtiYebQri~on_s.. _ _ _ _" _. _ _ _' _ _ _ _ _ _ _... _... _ _ Y~s_ _ _ _... _.... _ _. _. _ _ _ _ _.. _ _.. _. _ _ _ _... _ _...... _ _ _ _... _... _.. _ _ _ _ _ _ _.. _ _ _..._ 23 _C.asiog de_signs adequa.te. fo( Ç,.T, B .&_ permafr.ost . _ _ . . . . _ . . . _ .. . _ . . _ . _ . . _ . . . Y~s . . _ . _ . __ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . . . _ _ _ . _ _ . _ . _ _ . . . . . _ _ _ . _ _ _ _ _ _ . . _ . . . _ _ _ _ _ . . _ _ _ _ _ _ _ 24 Adequate.tan.kage_oJ re_seIYe pit. . . . . . . . _ _ _ . . . _ . . _ . _ . . _ _ _ _ _ _ . _ . . . . _ . . Yes _ _ . _ _ . . ~ab_ors.2_ES, . . _ _ _ _ . . _ _ . _ _ _ _ . _ _ _ _ . . _ _ . _ . _ . . . . _ _ _ _ _ _ . . . . _ . _ _ _ _ . _ _ _ . . . . . . _ . 25 Jf.a_re-drill~ bas.a. 1.0:-403 fQr abandon.ment be~1J ç¡PPJQved . _ _ . . . . . _ _ _ _ _ . _ . .. _ . . _ . Yes. . _ . _ _ _ TQ CQmm 91.3[03.. . _ _ . . . . . . _ _ _ . _ _ . _. _ . _ . _ . _ . . . _ . . . _ _ _ _ . . . . . . _ . _ _ _ _ _ . _ _ _ . _ . _ . 26 .Adequate.wellbor~ Sieparatjo.n.propOSiep. _ . . _ _ _ . _ _ . . _ _ _ _ . _ _ _ . _ _ _ . _ _ . . _ . . . Y~$ _ _ _ _ . _ . _ _ _ . . . _ . _ _ _ _ _ _ . . . . . _ . . _ _ _ . _ _ _ _ . _ _ _ _ _ . . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jf.djv~r:ter .req.ui.re.d. dQe~ jt JT1.e~t reguJatiOl1s. _ . _ _ . _ _ . _ . . . . . _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ .NA _ . _ . . _ . _ _ . . _ _ _ . _ _ _ _ _ _ . . . . _ . . . _ _ _ _ _ _ _ . . . . . . _ . . _ . _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ . . _ _ . . _ _ _ . 28 _DJillinQ flujd_prQgram sc.hematic.& eq_uipJistadequate. _ _ _ _ _ _ .. . _ _ _ _ _ _ _ . . _ . . . _ . . Y~s _ _ _ _ _ _ _ Max MW.8_.5. ppg~ _ _ _ . . . _ _ . . . _ _ _ _ _ _ _ . . . _ _ . _ _ . _ . _ _ _ _ _ _ _ . _ . _ . _ . _ _ _ _ _ _ _ _ . _ . . . . 29 _B_O.P.E$,_dO .they meet. regu.latiol1 . . . . _ . . _ ._ _ _ ._ _ _ _ . . . . . _ _ . _ _ _ . _ . . . . _ . _ Y~$ . _ _ _. _ _ . _ _ . . _ . . . . _ . _ . _ _ _ _ . _ _ _ _ _ __ _ _ _ _ _ _ . _ _ . _ . . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ . _ 30 _B_O.P.E.PJ~s$rati(lgap'propriate.;_testto.(pu.tp$igi.n_comlJ1eI1t$).. _. _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ Ye$_ _ _ _. _ .T~stlo_35QO_ps¡'_MS~24.50p$i._ _ _. _ _ _ _ _ _" _ _ _ _ _ _. _ _. _ _ _ _ _.. _ _ _. _ _ _ _ _ _ _ _ _ _ _ _.. __ 31 .C.hoke.manifold CQmpJie$. w/API. R~-53 (May 84)_ _ . _ _ _ _ _ _ . . _ _ _ . _ _ _ _ _ . _ _ _ _ . _ . yes _ _ _ _ _ . . . . ._ . . . _ . _ _ . _ _ _ _ . . . . . . . _ _ _ _ _ _ _ _ _ . _ _ _ _ . . _ _ . _ _ . _ _ _ . . _ _ _ _ _ _ _ _ _ . . _ _ _ . _ . . . 32 _WQrk will PÇC_U( withpyt.operatio.n _sbutdo_w.n_ _ _ .. _ _ _ . . _ _ . . . . _ _ .. _ . _ . _ _ _ _ _ Yes _ _ _ . _ _ . _ _ _ _ _ _ _ . _ _ _ _ . _ _ ._ . . _ . . . . _ . _ _ _ _ . _ _ _ .. _ . _ _ _ _ _ _ _ _ _ _ _ . _ . . _ . _ _ _ _ _ _ . . _ _ _ _ _ _ 33 J$. pre$.ence_ Qf H2S gas_ prQb_able. . _ _ . . _ . . . _ _ . _ _ _ . _ . . _ _ _ _ . _ _ _ _ _ _ _ _ . . _ _ No. _ . _ _ _ _ . . . . . _ . _ _ . _ _ _ . _ _ . . . _ _ . _ _ _ _ _ _ _ _ .. . . _ _ _ . . _ _ _ . _ . _ _ _ _ _ . _ . . _ _ _ _ _ _ . . _ _ _ . _ . . 34 Meçba.nlcal.c!)Od.iti.o[1 of we.lI$ wlthin AOR yerified. (for.s_ervice w~U only-) _ _ _ _ _ _ _ _ _ _ . . . . NA _ _ . _ _ _ . _ . . . _ _ _ _ _ _ _ _ _ _ _ . . . . _ _ _ . _ . _ _ . _ _ . .. _ _ _ . _ . . . _ _ _ _ ._ _ _ _ . _ _ _ _ . _ _ _ . _ _ _ _ . . _ _ _ _ Engineering Appr Date WGA 6/3/2003 Geology Appr Date If¿ ø/~ Geologic Commissioner: j)Gf < 35 .P~rl1Jit c.a[1 be i.S$l!.eçl W!Q h.yçlr:.ogen. s.ulfide meaS!J(e$. _ _ . _ . _ . . . _ _ . _ _ _ _ _ . _ _ . . . . No_ . _ _ __ _ _ . _ . . . . _ . _ . _ _ _ _ _ _ . _ . _ . _ _ _ _ . _ _ _ _ _ . . _ _ . . . _ _ _ _ _ _ . _ . _ .. . _ _ . _ . _ _ _ _ _ _ _ . . . _ _ . . 36 _D_ata_p.re.seoted. on_ pote.ntial oveJRreS_sur~ .zone$. _ . _ _ _ . _ _ . _ . . _ _ _ _ _ _ _ _ . _ . _ . . _ NA _ _ _ _ _ . . _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ . _ . _ . _ _ . _ . . _ . . _ . _ _ .. . . . _ . . . _ _ _ _ _ _ . _ . . . . _ _ . . 37 .S~i.smic.aJ1alysjs_ Qf $ba.llow gas.zolJe.s_ . _ _ _ _ _ _ _ . _ . _ _ _ . . . _ _ _ . _ _ _ _ . _ _ _ _ . . . NA _ _ _ _ . . . _ . . . . . _ _ . _ _ _ _ _ . . _ _ _ . _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ . _ . .. _ _ _ . _ _ . _ _ _ . . _ . _ . _ _ . _ _ . . . . . _ . 38 _S~abe.d _cond_itipo survey _(if off.-s.hore) _ . . _ _ _ _ _ . . . . _ . _ . _ . _ _ _ _ _ _ _ _ . . _ . _ . _ . NA . _ _ . _ . _ _ . . . . _ . . . . _ . _ . _ . . _ _ . _ _ _ _ _ _ _ _ _ . _ . . . _ . _ _ _ . . . _ _ _ _ _ _ . . . . . . _ _ . . _ _ _ . . _ _ _ . . 39 _ CQnta.ct nam.e[p.honeJQr_weekly prpgreSis_repo.rt$ [exploratory _only]. _ _ _ . _ _ _ _ _ _ _ _ . . _ _ NA _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . . _ _ . _ . . . _ _ _ _ _ _ _ _ . . _ . _ _ . _ _ _ _ _ _ _ _ _ . _ . _ . . _ _ _ _ _ _ _ _ . . _ . _ . _ Date: O~J03 /OJ Engineering Commissioner: Public ~ Commissione'( vr-- ç ~ 6'0 Date Æ4æ 'It/18 ) ) Well History File APPENDIX Inforrnation of detailed nature that is not particularly germane to the Well Permitting Process bu1 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 APPEN.DIX. No special effort has been made to chronologically organize this category of information. ) ) 803 ·-c)Cf:-¡- ~. ) \9T~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Sep 03 08:55:13 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/09/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/09/03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 15-07C 500292116603 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 03-SEP-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW2523315 J. BOBBITT J. RALL MWD RUN 3 AK-MW2523315 J. BOBBITT J. RALL MWD RUN 4 AK-MW2523315 T. GALVIN J. RALL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 AK-MW2523315 J. BOBBITT R. BORDES / # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 22 11N 14E 1527 1354 57.77 29.27 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 11736.0 # REMARKS: RECEIVED 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. c: CiJ 1 6 "'003 vL¡ t. ). "\:(~~ \'\1\, ~.~ Alaska OU &. Gas Cons. CDmmis8ion ,l\nchor~ ) ) THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK AND MILL THE WINDOW, THE TOP OF WHICH WAS AT 11724'MD/8490'TVD AND THE BOTTOM WAS AT 11736'MD/8497'TVD. SROP DATA ARE PRESENTED. 4. MWD RUN 2 FAILED PULSE TEST - NO FOOTAGE MADE, NO DATA ACQUIRED. 5. MWD RUN 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS: ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); COMPENSATED THERMAL NEUTRON POROSITY (CTN); STABILIZED LITHO-DENSITY (SLD); AND AT-BIT-INCLINATION (ABI). 6. MWD RUNS 4 & 5 COMPRISED DIRECTIONAL WITH DGR; EWR4; AND ABI. 7. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 10' SHALLOWER PER E-MAIL FROM D. SCHNORR, BP EXPLORATION (ALASKA), INC., DATED 8/26/03. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 8. MWD RUNS 1, 3-5 REPRESENT WELL 15-07C WITH API#: 50-029-21166-03. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15250'MD/8723'TVD. 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. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.125" MUD WEIGHT: 8.4 PPG MUD SALINITY: 2200 PPM CHLORIDES FORMATION WATER SALINITY: 10994 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name. .... ...... ..STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 ') ') Date of Generation...... .03/09/03 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name..... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR NCNT NPHI FCNT PEF ROP DRHO RHOB RPX RPS RPM RPD FET $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 11390.5 11650.0 11650.5 11650.5 11663.5 11713.0 11713.5 11713.5 11720.5 11720.5 11720.5 11720.5 11720.5 STOP DEPTH 15177.0 12997.0 12997.0 12997.5 13010.5 15240.0 13010.5 13010.5 15184.0 15184.0 15184.0 15184.0 15184.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 11390.5 11400.5 15240.0 15250.0 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 11723.0 11748.0 MWD 3 11400.5 13096.0 MWD 4 13096.0 13671.0 MWD 5 13671.0 15250.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type............... ...0 Data Specification Block Type. ....0 Logging Direction......... ....... . Down Optical log depth units.......... .Feet Data Reference Point........... ...Undefined Frame Spacing................. ... .60 .1IN Max frames per record............ .Undefined Absent value........... ...... .... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD GR MWD RPX MWD RPS MWD RPM MWD RPD MWD FET MWD NPHI MWD FCNT MWD NCNT MWD RHOB MWD DRHO MWD PEF MWD Units FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 Nsam 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Code Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Rep 68 68 68 68 68 68 68 68 68 68 68 68 68 68 Offset o 4 8 12 16 20 24 28 32 36 40 44 48 52 ') ) First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11390.5 15240 13315.3 7700 11390.5 15240 ROP MWD FT/H 0.05 428.06 75.1511 7055 11713 15240 GR MWD API 12.55 387.2 58.6371 7342 11390.5 15177 RPX MWD OHMM 2.32 2000 135.93 6928 11720.5 15184 RPS MWD OHMM 3.54 2000 149.951 6928 11720.5 15184 RPM MWD OHMM 3.43 2000 166.959 6928 11720.5 15184 RPD MWD OHMM 3.77 2000 188.281 6928 11720.5 15184 FET MWD HOUR 0.45 55.06 2.66656 6928 11720.5 15184 NPHI MWD PU-S 7.11 32.7 20.5588 2694 11650.5 12997 FCNT MWD CNTS 400.2 1818.6 807.454 2695 11650.5 12997.5 NCNT MWD CNTS 24291.1 40016.9 30992 2695 11650 12997 RHOB MWD G/CM 1. 864 4.426 2.29283 2595 11713.5 13010.5 DRHO MWD G/CM -0.534 1.867 0.0453973 2595 11713.5 13010.5 PEF MWD BARN 1.5 17.81 2.66249 2695 11663.5 13010.5 First Reading For Entire File......... .11390.5 Last Reading For Entire File.......... .15240 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/09/03 Maximum Physical Record..65535 File Type.............. ..LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number....... .., .1.0.0 Date of Generation...... .03/09/03 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 11723.0 STOP DEPTH 11748.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 27-JUN-03 Insite 66.37 Memory 11748.0 11724.0 11748.0 50.4 50.4 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ TOOL NUMBER ') # 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 (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... ............0 Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing................ .... .60 .1IN Max frames per record............ .Undefined Absent value........... .......... .-999 Depth Units....................... Datum Specification Block sub-type. ..0 5.625 10014.0 QUIKDRIL-N 8.50 42.0 8.8 1500 8.0 .000 .000 .000 .000 Name Service Order DEPT ROP MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD010 FT/H Min 11723 0.05 Max 11748 6.15 First Reading For Entire File......... .11723 Last Reading For Entire File.......... .11748 File Trailer Service name..... ...... ..STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/09/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.... .... ...STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.... .... ...1.0.0 Date of Generation...... .03/09/03 Maximum Physical Record. .65535 Mean 11735.5 2.75647 Nsam 51 51 ) .0 118.0 .0 .0 First Reading 11723 11723 Last Reading 11748 11748 ) File Type.............. ..LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR NCNT FCNT NPHI PEF DRHO RHOB FET RPD RPM RPS RPX ROP $ 3 ) header data for each bit run in separate files. 3 .5000 START DEPTH 11400.5 11660.0 11660.5 11660.5 11673.5 11723.5 11723.5 11730.5 11730.5 11730.5 11730.5 11730.5 11748.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO 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 SLD CTN EWR4 $ STOP DEPTH 13032.5 13007.0 13007.5 13007.0 13020.5 13020.5 13020.5 13040.0 13040.0 13040.0 13040.0 13040.0 13096.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON 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 (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: 30-JUN-03 Insite 66.37 Memory 13096.0 11748.0 13096.0 53.0 90.1 TOOL NUMBER 184054 112439 100547 159436 6.125 11736.0 QUIKDRIL-N 8.50 46.0 9.4 2200 7.8 2.400 1.240 1. 900 2.100 67.0 136.0 67.0 67.0 ') ) $ # Data Format Specification Record Data Record Type..... ....... ......0 Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units......... ..Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record........... ..Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Service Order MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 Units FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 Code Offset o 4 8 12 16 20 24 28 32 36 40 44 48 52 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Nsam 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Rep 68 68 68 68 68 68 68 68 68 68 68 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11400.5 13096 12248.3 3392 11400.5 13096 ROP MWD030 FT/H 1. 06 428.06 74.7375 2696 11748.5 13096 GR MWD030 API 12.55 387.2 48.796 3033 11400.5 13032.5 RPX MWD030 OHMM 2.32 1678.64 156.485 2620 11730.5 13040 RPS MWD030 OHMM 3.54 1968.48 230.542 2620 11730.5 13040 RPM MWD030 OHMM 3.43 2000 245.301 2620 11730.5 13040 RPD MWD030 OHMM 3.77 2000 242.175 2620 11730.5 13040 FET MWD030 HOUR 0.56 55.06 2.21968 2620 11730.5 13040 NPHI MWD030 PU-S 7.11 32.7 20.5588 2694 11660.5 13007 FCNT MWD030 CNTS 400.2 1818.6 807.454 2695 11660.5 13007.5 NCNT MWD030 CNTS 24291.1 40016.9 30992 2695 11660 13007 RHOB MWD030 G/CM 1.864 4.426 2.29283 2595 11723.5 13020.5 DRHO MWD030 G/CM -0.534 1.867 0.0453973 2595 11723.5 13020.5 PEF MWD030 BARN 1.5 17.81 2.66249 2695 11673.5 13020.5 First Reading For Entire File...... ... .11400.5 Last Reading For Entire File.......... .13096 File Trailer Service name.. ......... ..STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.... ...03/09/03 Maximum Physical Record..65535 File Type..... ........ ...LO Next File Name......... ..STSLIB.004 Physical EOF File Header Service name. ....... .... .STSLIB.004 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .03/09/03 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name...... .STSLIB.003 ) Corcunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPS RPD FET RPX ROP $ 4 ) header data for each bit run in separate files. 4 .5000 START DEPTH 13033.0 13040.5 13040.5 13040.5 13040.5 13040.5 13096.5 STOP DEPTH 13608.0 13615.0 13615.0 13615.0 13615.0 13615.0 13671. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO 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 $ 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 (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ .... ......0 Data Specification Block Type.....O Logging Direction... ........ .... ..Down Optical log depth units. ..... .....Feet Data Reference Point............. .Undefined Frame Spacing...... ......... ......60 .1IN Max frames per record... ... .......Undefined Absent value. .......... .......... .-999 02-JUL-03 Insite 66.37 Memory 13671.0 13096.0 13671.0 88.8 93.2 TOOL NUMBER 184054 159436 6.125 11736.0 QUIKDRIL-N 8.50 40.0 6.0 2100 6.0 2.400 1. 060 1. 900 2.100 67.0 161. 0 67.0 67.0 ) ) Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 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 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13033 13 671 13352 1277 13033 13 671 ROP MWD040 FT/H 0.25 270.66 88.3617 1150 13096.5 13671 GR MWD040 API 44.07 102.75 64.8314 1151 13033 13608 RPX MWD040 OHMM 12.68 2000 72.5729 1150 13040.5 13615 RPS MWD040 OHMM 12.92 2000 82.5245 1150 13040.5 13615 RPM MWD040 OHMM 14 2000 121. 658 1150 13040.5 13615 RPD MWD040 OHMM 15.43 2000 139.618 1150 13040.5 13615 FET MWD040 HOUR 0.45 25.3 4.7639 1150 13040.5 13615 First Reading For Entire File......... .13033 Last Reading For Entire File... ....... .13671 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/09/03 Maximum Physical Record..65535 File Type.............. ..LO Next File Name....... ....STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/09/03 Maximum Physical Record..65535 File Type............. ...LO Previous File Name... ....STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 5 header data for each bit run in separate files. 5 .5000 START DEPTH 13608.5 13615.5 13615.5 13615.5 13615.5 13615.5 13671. 5 STOP DEPTH 15187.0 15194.0 15194.0 15194.0 15194.0 15194.0 15250.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 04-JUL-03 Insite ') DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO 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 $ 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 (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... ............0 Data Specification Block Type.....O Logging Direction.... ....... ..... . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 66.37 Memory 15250.0 13671.0 15250.0 88.3 94.1 TOOL NUMBER 184054 159436 6.125 11736.0 QUIKDRIL-N 8.40 38.0 9.3 1600 7.0 1. 250 .580 1. 200 3.000 70.0 158.0 70.0 70.0 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 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 13608.5 15250 14429.3 3284 13608.5 15250 ROP MWD050 FT/H 2.54 419.05 71.8626 3158 13671.5 15250 GR MWD050 API 28.31 155.99 65.8311 3158 13608.5 15187 RPX MWD050 OHMM 6.8 2000 141.948 3158 13615.5 15194 RPS MWD050 OHMM 6.65 2000 107.643 3158 13615.5 15194 RPM MWD050 OHMM 7.04 2000 118.46 3158 13615.5 15194 ) ) RPD MWD050 OHMM 8.84 2000 161. 289 3158 13615.5 15194 FET MWD050 HOUR 0.5 20.36 2.27356 3158 13615.5 15194 First Reading For Entire File......... .13608.5 Last Reading For Entire File..... ..... .15250 File Trailer Service name........... ..STSLIB.005 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..03/09/03 Maximum Physical Record..65535 File Type..... ......... ..LO Next File Name......... ..STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/09/03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number.. ....01 Next Tape Name........ ...UNKNOWN Comments.............. ...STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/09/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number.... ..01 Next Reel Name......... ..UNKNOWN Comments.............. ...STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
