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203-137
tli 1C7C,1 V =Li STATE OF A • \LASKA OIL AND GAS CONSERVATION COMMI N JUL 2 $ 2015 WELL..OMPLETION OR RECOMPLETION REP(.-. AND LOG [^)�1�1,��'��. la. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 10 • Suspended 0 1b.Well OiSs�i° �P'v '°' 20AAC 25.105 20AAC 25.110 'Development II Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL ❑ No.of Completions: Zero • Service ❑ Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp,or Aband._ ) 14.Permit to Drill Number/Sundry BP Exploration(Alaska).Inc 7/6/2015 203-137 • 315-328 3. Address: 7. Date Spudded: 15' API Number P.O.Box 196612 Anchorage,AK 99519-6612 8/29/2003 50-029-20651-01-00' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number 9/2/2003 PBU F-15A • Surface: 3284 FNL,2201'FEL,Sec.02,T11N,R13E,UM ' 17. Field/Pool(s): 9. KB(ft above MSL): 71.31' • Top of Productive Interval: 4857'FNL,3911'FEL,Sec.02,T11N,R13E,UM GL(ft above MSL): 35.96' • PRUDHOE BAY,PRUDHOE OIL • Total Depth: 4979'FNL,5237'FEL,Sec.02,T11N,R13E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 9064'/8622' ADL 028280 • 4b. 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 652650• y- 5973529 • Zone - ASP 4 • 11226'/ 9050' • TPI: x- 650973 y- 5971922 Zone - ASP 4 12. SSSV Depth(MD/TVD): PO Thickness of Permafrost MD/TVD: Total Depth:x- 649651 y- 5971774 Zone - ASP 4 None 1900'(Approx.) 5. Directional Survey: Yes 0 (attached) No ll 13. Water Depth.if Offshore: 21. Re-drill/Lateral Top VNndow MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) • 9370'/8912' • 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 GR,EWR,MGR,CCL,CNL 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20"x 30" Insulated Conductor 37' 117' 37' 117' 36" 8 cu yds Concrete 13-3/8" 72# L-80 36' 2710' 36' 2710' 17-1/2" 3720 cu ft Permafrost II 9-5/8" 47# L-80 34' 8956' 34' 8515' 12-1/4" 1202 cu ft Class'G',130 cu ft PF'C' 7" 26# L-80 8463' 9370' 8047' 8912' 8-1/2" 360 cu ft Class'G' 3-3/16"x 2-7/8" 6.2#/6.16# L-80 9145' 11226' 8026' 9050' 3-3/4" 124 cu ft Class'G' 704' 24. Open to production or injection? Yes 0 No Il' 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): 5-1/2",17#x 4-1/2",12.6#,L-80 8550' 8405'/7992' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. S /� �)L O I� Was hydraulic fracturing used during completion? Yes ❑ No HE© SEP 1 V Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 9145' Cut&Pull Liner 9064' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period —* Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate �'♦ Form 10-407 Revised 5/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only V7L q/2//5--41V2 . li6Z71015 ,0./sem' 16 28 CORE DATA Conventional Core(s) Yes 0 No 0 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 separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. 25N 9424' 8964' 25P 9450' 8988' 21N 9598' 9085' 21P 9614' 9089' Formation at total depth: 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Wellbore 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: Boltz,Travis Email: Travis.Boltz@bp.com Printed Name: Joe Lastufk AI Title: Drilling Technologist /\ Signature: Phone: +1 9075644091 Date J,.WIS INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item lb.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only F-15A, Well History (Pre-Rig Sidetrack) DAT ,�,. ... _. . ....,, �,. .,... ., SUMMARY INITIAL T/I/O = 0/100/500. MIRU. PT. RIH WITH 2.5"POWER CUTTER. CUT TUBING" "'9145. (CORRELATED TO HES CBL LOG DATED 10-APR-15). GOOD VOLTAGE/CURRENT 6/9/2015 INDICATION. POOH. SHOT CONFIRMED AT SURFACE. RDMO. FINIAL T/I/O = 0/100/500 CTU#3 w/ 1.75" CT Job Objective: Pull & Release Liner- previously cut by Eline. Arrive on location. 6/28/2015 Standby for Wells Support to RU. CTU#3 w/ 1.75" CT Job Objective: Pull & Release Liner- previously cut by Eline. MIRU. Perform chain/injector inspection and changed packoffs. Perform weekly BOP Test. Rih w/Baker 4"GS- Spear. Latch liner at 8430'ctm. Pull 5k over pick up weight& pick up cut liner no problem. Pull cut liner up to 8303' & run back down to 8430'. Pump off& pooh. Lay in 50/50 meth FP from 2500'. 6/29/2015 RDMO. T/I/O = 25/50/500. Installed TS#06 . Torqued and PT'd to API specs. (PASSED). PT'd bottom side 7/1/2015 of SV(PASSED). RDMO. Final WHP = 25/50/500. T/I/O= SSV/460/60. Temp=SI. Bleed IAP & OAP to 0 psi (Pre CTD). WH is removed and the well is demobed. IA FL @ surface. OA FL near surface. Bled OAP to BT from 460 psi to 0 psi in 4 hrs (Gas). IAP decreased 30 psi during bleed. OAP increased 10 psi during 30 min monitor. Final 7/3/2015 WHPs= SSV/30/10. SV, WV, SSV= C. MV= O. IA, OA= OTG. NOVP. 15:30. North America-ALASKA-BP Page 1 ofLi.4— Operation Summary Report Common Well Name:F-15 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/4/2015 End Date: X3-0174D-C:(4,410,433.00) —I Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:NORDIC 2 I Spud Date/Time:12/28/1981 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA j UWI:500292065100 Active datum:ORKB 071.31 usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth , Phase Description of Operations (hr) (usft)_- 7/4/2015 7/4/2015 00:00 - 03:00 3.00 MOB P PRE PJSM REGARDING MOVING OFF F-12. MOVE RIG OFF WELL. MOVE RIG TO BACKISDE OF F PAD. 03:00 - 03:15 0.25 j MOBP PRE PJSM REGARDING SPOTTING OVER WELL. 03:15 - 04:00 0.75 I MOB P j PRE MOVE OVER WELL. I SET RIG DOWN. I "ACCEPT RIG AT 04:00 7/4/15. • 04:00 - 04:35 0.58 RIGU P PRE RU IA/OA&WING VALVE GAUGES.RU SLB PANEL&OPEN SSV. 04:35 - 06:00 1.42 RIGU P PRE RU TEST HOSE.LEAK TITE TEST TREE. BLEED OFF.RD TEST HOSE. 06:00 - 10:00 4.00 RIGU P j PRE SET MOUSEHOLE IN. NIPPLE DOWN TREE CAP. j • I NIPPLE UP BOP'S AND CENTER. GET RKB DISTANCES. 10:00 - 12:00 2.00 1 RIGU P PRE ,MAKE UP INJECTOR AND GOOSENECK PICK UP INJECTOR AND SET BACK INTO BUNGHOLE. CHANGE OUT INJECTOR PULLBACK CABLE •ON_WINCH. 12:00 - 13:00 1 1.00 RIGU P PRE •SPOT COIL UNDER REEL HOUSE TO PICK UP COIL. •PJSM FOR PICKING UP COIL. PICK UP COIL FROM TRAILER AND SECURE IN REEL HOUSE. I 13:00 - 14:00 1.00 BOPSUR P. PRE GREASE CHOKE MANIFOLD VALVES. FLOOD BOP STACK. CHECK FOR VISUAL LEAKS. I j "SIMOPS:HOOK UP HARDLINE IN I REELHOUSE TO REEL 14:00 - 00:00 10.00 BOPSUR P PRE i SHELL TEST BOP STACK. INSTALL TEST PLUG IN SARBER SPOOL DUE TO SHELL TEST SUSPECT LEAKING AT SWAB VALVE. • RESHELL TEST BOP STACK j GOOD SHELL TEST. I PRESSURE TEST BOPS. TEST ANNULAR,UPPER AND LOWER 2 3/8"X I i i 3 1/2"VBRS,2 3/8"PIPE/SLIP RAMS,BLIND/• • SHEAR RAMS,KILL LINE AND CHOKE VALVES. j .AOGCC WITNESS WAIVED BY INSPECTOR JEFF JONES. 7.5/2015 0000 - 01:30 1.50 RIGU I P PRE PJSM FOR PULL COIL ACROSS.PU INJECTOR.PULL TEST GRAPPLE.REMOVE COIL CLAMPS.PULL COIL ACROSS&STAB 1 INTO INJECTOR.RD STABBING CABLE.RU PULL BACK CABLE.CUT OFF GRAPPLE. I _ _ !CLOSE GOOSENECK ROLLER DOOR. 01:30 - 02:30 1.00 RIGU j P PRE PLACE INJECTOR OVER BUNGHOLE.FILL COIL WITH 1%KCL.PT REEL IRON/REEL FILTER,250PSI/4000PSI. 02:30 - 02:40 0.17 RIGU P PRE PUMP OUT 370FT OF E-LINE CABLE. 02:40 - 03:05 J 0.42 j RIGU P i 1 PRE I BOOT E-LINE CABLE.STAB ONTO WELL. 03:05 - 03:40 I 0.58 . BOPSUR P ' 1PRE j TEST INNER REEL&PACKOFFS 250PSI/3500PSI.BLEED OFF.POP OFF. Printed 7/14/2015 11:44.19AM • North America-ALASKA-BP Page 2 004' , , Operation 0 4- Operation Summary Report Common Well Name:F-15 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/4/2015 End Date X3-0174D-C:(4,410,433.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:NORDIC 2 Spud Date/Time:12/28/1981 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292065100 Active datum:ORKB©71.31usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:40 - 04:40 1.00 BOPSUR P PRE SUCK DOWN STACK.PULL SPOOL PLUG. INSTALL NITE CAP.TEST QTS 250PSI/3500PSI.PUMP 3/4"DRIFT BALL. 04:40 - 04:45 0.08 BOPSUR P PRE PJSM REGARDING TORQUE TREE. 04:45 - 06:00 1.25 BOPSUR P PRE INSTALL SSV CAP. TORQUE TREE. 06:00 - 07:00 1.00 BOPSUR P PRE OPEN WELL TO CLOSED HAND CHOKE.9 PSI ON WELL WHEN WE OPENED IT. BLEED DOWN RESIDUAL PRESSURE OFF OF WELL. MONITOR PRESSURE ON WELL-BUILD TO 4 PSI AND STABILIZED. BLEED OFF PRESSURE AGAIN. MONITOR PRESSURE ON WELL-BUILD TO 2 PSI. BLEED OFF PRESSURE AND PERFORM FLOWCHECK FOR 10 MINUTES-WELL STATIC. MONITOR PRESSURE ON WELL FOR 10 MINUTES-0 PSI. 07:00 - 08:00 1.00 FISH P DECOMP PJSM ON PICKING UP FISHING BHA. CHECK FOR PRESSURE UNDER CAP-0 PSI. REMOVE NIGHT CAP FROM LUBRICATOR. SOME BUBBLING IN WELL. INSTALLED NIGHT CAP AND PUT GAUGE ON TO MONITOR WHILE DISCUSSING WITH OPS SUPT. DECIDED TO PROCEED WITH PLAN FORWARD.15 MINUTES ON GAUGE-0 PSI. HELD DISCUSSION WITH RIG CREW ON SITUATION AND EXPECTATIONS CONCERNING THE WELL. "SIMOPS:TEST GAS AND H2S ALARMS. 08:00 - 08:45 0.75 FISH P DECOMP PICK UP FISHING BHA CONSISTING OF: GS SPEAR WITH SEALED STINGER,3/4" DISCONNECT,G-FORCE JARS,WEIGHT BAR, ACCELERATOR,DBPV,2 JTS PI-16,AND SWIVEL. RUN IN HOLE WITH BHA. MAKE UP CTC TO SWIVEL. STAB AND MAKE UP INJECTOR ON LUBRICATOR. TEST QTS. 08:45 - 10:20 1.58 FISH P DECOMP RUN IN HOLE WITH FISHING BHA. PUMP AT.75 BPM,TAKING RETURNS OUTSIDE TO FLOWBACK TANK. MM IN/OUT.72/1.23 BPM,CIRCULATING PRESSURE 256 PSI,MW IN/OUT 8.39/7.35 PPG(AT 900') Printed 7/14/2015 11:44:19AM • North America-ALASKA-BP Page 3 ov441 Operation Summary Report Common Well Name:F-15 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/4/2015 End Date: X3-0174D-C:(4,410,433.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:NORDIC 2 Spud Date/Time:12/28/1981 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292065100 Active datum:ORKB @71.31 usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:20 - 13:15 2.92 FISH P DECOMP ESTABLISH PARAMETERS AT 8,389'.SHUT DOWN PUMPS.PUW=40K,SOW=24K. TURN PUMPS ON AND PUMP AT 1 BPM TO ENGAGE FISH. SLACK OFF AND ENGAGE FISH.TAG FISH AT 8,458'.STACK 10K ON TOP OF FISH TO ENGAGE FISH. PICK UP WITH PUW BREAKING OVER AT 44.5K. PICK UP TO 8,447'WITH NO OVERPULL. CIRCULATE 2 X BOTTOMS UP.(170 BBLS I CALCULATED BOTTOMS UP). CIRCULATE 190 BBLS AT 2.5 BPM @ 2618 PSI. AT 180 BBLS,THE IN AND OUT MICROMOTION AND DENSITIES WERE CONSISTENT AND EVEN. SHUT DOWN AT 190 BBLS,PERFORM FLOWCHECK AND LINE UP TO BRING FLUID INTO THE RIG. PUMP 15 BBLS INTO THE CUTTINGS BOX TO 'CHECK QUALITY OF FLUID-QUALITY WAS GOOD. LINE UP AND CIRCULATE FLUID TO PITS. MM IN/OUT 2.69/2.70,MW IN/OUT 8.44/ 8.36,CIRC PRESSURE 2772 PSI. PUMP A TOTAL OF 340 BBLS. SHUT DOWN PUMPS AND PERFORM FLOWCHECK FOR 10 MINUTES-WELL STATIC. BRING PUMPS BACK ONLINE. SLACK OFF AND TAG WITH 10K TO VERIFY FISH ENGAGEMENT. PJSM ON PULLING OUT OF HOLE WITH LINER. 13:15 - 15:30 2.25 FISH P DECOMP PULL OUT OF HOLE WITH LINER. APPLY 200 PSI TO WELLHEAD. PUMP AT.45 BPM DOWN COIL AND PUMP 1.09 BPM DOWN KILL LINE DOWN BACKSIDE. POOH AT 80 FPM WITH 212 PSI ON WELLHEAD. FLOWCHECK WITH BHA BELOW BOP STACK-WELL STATIC. 15:30 - 16:30 1.00 FISH P DECOMP BREAK OUT BHA. BREAK OUT AND LAY DOWN FISHING TOOLS. BREAK OUT AND LAY DOWN DEPLOYMENT SLEEVE WITH GS SPEAR. 16:30 - 20:00 3.50 FISH P DECOMP RIG UP FARR TONGS FOR LAYING DOWN LINER. POOH WITH LINER AND LAY DOWN TO PIPE SHED. WELL CONTROL DRILL.SIMULATED FAILED ANNULAR.CLOSE VBR'S.AAR W/CREW. RECOVER 22-1/2JTS OF 3-3/16"TCII LINER. CUT JOINT FLARED END WAS 3.80"OD.1/16" CEMENT SHEATH AROUND LINER FROM 8518' TO CUT.708.98FT RECOVERED.RD ELEVATORS.RD TONGS.CLEAN RF. Printed 7/14/2015 11:44:19AM North America-ALASKA-BP Page 4 cl124 >a Operation Summary Report 1 Common Well Name:F-15 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/4/2015 End Date. X3-0174D-C:(4,410,433.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:NORDIC 2 Spud Date/Time:12/28/1981 12:00:00AM 1 Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292065100 Active datum:ORKB©71.31 usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ' (usft) 20:00 - 00:00 4.00 I FISH P ' DECOMP PU INJECTOR.CLOSE MASTER&SWAB.RU ' NITE CAP.GET HWP.BOOT END OF E-LINE. STAB ONTO WELL.PUMP SLACK INTO REEL. POP OFF.RU COIL CUTTER.PJSM REGARDING CUTTING COIL.CUT 270FT OF COIL.DRESS END OF COIL.MU CTC.PULL I TEST TO 43K.PRESSURE TEST 250PSI/3800PSI.MU 5'STINGER.PUMP . FORWARD.RD NOZZLE.REHEAD UQC. PRESSURE TEST UQC 250PSI/4000PSI.OPEN WELL TO CLOSED HAND CHOKE OPSI. 7/6/2015 00:00 - 00:10 0.17 FISH PDECOMP PJSM REGARDING MU CALIPER BHA. 00:10 - 01:15 1.08 FISH P DECOMP MU CALIPER BHA.GOOD SURFACE TEST ON CALIPER.PU&MU TO INJECTOR.STAB ONTO WELL.TEST QTS 250PSI/4000PSI.SET COUNTERS.POWER UP TOOLS. 01:15 - 02:35 1.33 FISH P DECOMP RIH,CIRC 0.57BPM/161PSI. • 02:35 - 03:10 0.58 FISH P DECOMP LOG DOWN FOR TIE-IN FROM 9000FT.MINUS 21 FT CORRECTION. 03:10 - 03:20 0.17 FISHP DECOMP RIH AND TAG STUB AT 9158FT.CIRC 1.4BPM/700PSI. 03:20 - 04 20 1.00 FISH P i DECOMP CCL UP TO 8300FT.CIRC 1.4BPM/700PSI. 04:20 - 04 40 0.33 FISH P DECOMP 'RIH TO 9152FT.CIRC AT 1.4BPM/702PSI. 04:40 - 05 35 0.92 FISH P DECOMP WAIT FOR CALIPER ARMS TO OPEN.CIRC AT 1.4BPM/707PSI. 05:35 - 07:15 1.67 FISH -. P 1 DECOMP LOG UP AT 50FT/MIN.CIRC 1.6BPM/894PSI. LOGGED FROM 9152'TO 7750'. POOH WITH LOGGING BHA. 07 15 - 07:40 0.42 FISH P DECOMP FLOWCHECK BEFORE BRINGING BHA 'ACROSS BOP STACK-WELL STATIC. l � PICK UP AND LAY DOWN LOGGING BHA. GOOD DATA FROM LOG. 107:40 - 08:40 1.00 WHIP P WEXIT !PICK UP WHIPSTOCK BHA AND RUN IN HOLE. 08:40 - 11:00 2.33 WHIP P WEXIT 'RUN IN HOLE WITH WHIPSTOCK. PDS FILES BEING INTERPOLATED AND SENT TO TOWN. TIE INTO PDC LOG WITH-21'CORRECTION. RIH TO 9118'(TOP OF WHIPSTOCK AT 9100'). ORIENT WHIPSTOCK TO 30 DEGREE LOHS. 11:00 - 15:45 4.75 WHIP N WAIT WEXIT WAIT ON PDS INTERPRETATION AND DIRECTION FROM TOWN. 15:45 - 16.00 0.25 WHIP P WEXIT DECISION TO SET WHIPSTOCK TOP AT 9,060' WITH BOTTOM AT 9,078'DUE TO RESULTS FROM CALIPER LOG. PULL UP HOLE TO SETTING DEPTH AND SET WHIPSTOCKAT 30 DEGREE LOHS. CLOSE EDC AND PRESSURE UP TO SET WHIPSTOCK.WHIPSTOCK SHEARED AT 2800 PSI. 16:00 - 18:45 2.75 WHIP P WEXIT j START MUD DOWN COIL TO LAY IN MUD ON WAY OUT. I POOH,LAYING IN MUD ON WAY OUT. PJSM REGARDING LD BHA WHILE POH. 18:45 - 19:30 , 0.75 WHIP P WEXIT BLOW DOWN TOOLS.LD WS SETTING BHA. -__ OFF LOAD SETTING BHA. 19:30 - 19:40 0.17 WHIP P WEXIT PJSM REGARDING MU MILLING BHA. Printed 7/14/2015 11 44 19AM North America-ALASKA-BP Page 5 GA-- Operation f VOperation Summary Report Common Well Name:F-15 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/4/2015 End Date: X3-0174D-C:(4,410,433.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:NORDIC 2 Spud Date/Time:12/28/1981 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292065100 Active datum:ORKB @71.31 usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:40 - 20:20 0.67 STWHIP P WEXIT MU WINDOW MILLING BHA.STAB ONTO WELL.TEST QTS 250PSI/4000PSI.POWER UP &TEST TOOLS.SET COUNTERS. 20:20 - 22:05 1.75 STWHIP P WEXIT RIH WITH WINDOW MILLING BHA.CIRC THRU EDC AT 0.55BPM/571 PSI.UNABLE TO TIE-IN DUE TO BHA LENGTH&DEEP TIE-IN POINT. ASSUME MINUS 21 FT CORRECTION.TAG AT 9068FT.PU TO 9060FT. 22:05 - 22:30 0.42 STWHIP P WEXIT CLOSE EDC.GET SPR'S.USING PUMP#1, PUMP AT 2.8BPM/2289PSI.STOP PUMPING, OPEN BAKER CHOKE,PERFORM FINGERPRINT TO PIT#4,5.2BBLS IN 8 MIN W/ NO FLOW. 22:30 - 00:00 1.50 STWHIP P WEXIT CIRC AT 2.87BPM/2311 PSI.WET TAG AT 3t 4. 9068FT. T TIME MILL WINDOW FROM 9068FT. tt'-15 b 2.88/2.89 BPM IN/OUT. 8.66/8.64 PPG. DWOB=0.16 KLBS,ECD=9.18 PPG,PVT= 327 BBLS. BLED DOWN IA FROM 940PSI TO 50PSI TO SLOP TRAILER,CRUDE,5 MIN. MILL TO MIDNIGHT DEPTH OF 9069.4FT. 7/7/2015 00:00 - 06:00 6.00 STWHIP P WEXIT CONTINUE TO TIME MILL WINDOW FROM 9069.4FT. 2.88/2.89 BPM IN/OUT. 8.66/8.64 PPG. DWOB=0.16-4 KLBS,ECD=9.18 PPG,PVT= 327 BBLS. MILL TO 9076' 06:00 - 10:45 4.75 STWHIP P WEXIT CONTINUE TO TIME MILL WINDOW FROM 9076 FT. 2.86/2.87 BPM IN/OUT. 8.65/8.60 PPG. DWOB=.2-2.8KLBS,ECD=9.12 PPG,PVT= 328 BBLS. MILL TO 9087' 10:45 - 11:30 0.75 STWHIP P WEXIT PULL OUT TO ABOVE WINDOW-CLEAN. REAM WINDOWN 3 TIMES WITH NO PROBLEMS. SHUT DOWN PUMPS AND DRY DRIFT WINDOW-ALL CLEAN. 11:30 - 12:15 0.75 STWHIP P WEXIT CIRCULATE SAMPLE FROM 9087'UP. SAMPLE SHOWED UPPER SHUBLIK. GOOD TO POOH. 12:15 - 13:50 1.58 STWHIP P WEXIT POOH WITH WINDOW MILLING BHA. FLOWCHECK BEFORE PULLING OUT OF HOLE-WELL STATIC. PULL OUT OF HOLE PUMPING AT 3.06 BPM WITH 2040 PSI. MM IN/OUT 3.06/2.64 BPM,MW IN/OUT 8.64 /8.60 ppg,PULLING OUT OF HOLE AT 81 FPM. CIRCULATING PRESSURE 2054 PSI,IA/OA/ PVT 264/57/322(AT 7772'). 13:50 - 14:30 0.67 STWHIP P WEXIT FLOWCHECK BEFORE BRINGING BHA ACROSS BOP STACK-WELL STATIC. POOH AND LAY DOWN MILLING BHA. GAUGE MILL AND STRING MILL.MILL=3.79' GO/3.78"NO-GO,STRING MILL=3.8"GO/ 3.79"NO-GO. LAY DOWN BOT TOOLS TO GROUND. Printed 7/14/2015 11:44:19AM North America-ALASKA-BP Page 6 o Operation Summary Report Common Well Name:F-15 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/4/2015 End Date. X3-0174D-C:(4,410,433.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:NORDIC 2 Spud Date/Time:12/28/1981 12:00:OOAM Rig Release: Rig Contractor NORDIC CALISTA UWI:500292065100 Active datum:ORKB @71.31 usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 15:10 0.67 STWHIP P PROD1 PICK UP BUILD BHA. RUN IN HOLE WITH SAME. MAKE UP UQC AND LQC. STAB INJECTOR ONTO STUMP. TEST QTS. TEST MWD TOOLS. 15:10 - 15:50 0.67 STWHIP P PROD1 RUN IN HOLE TO 3050'. DD NOTICED THAT THE HOT WAS NOT RESPONDING TO COMMANDS. STOP RUNNING IN HOLE AND REBOOTED MWD. SEND COMMAND TO HOT,BUT NO RESPONSE FROM HOT. DECIDED TO POOH TO CHANGE OUT HOT. • 15:50 - 16:40 0.83 STWHIP N DFAL 3,050.00 PROD1 POOH TO CHANGE OUT HOT TOOL. 16:40 - 17:30 0.83 STWHIP N DFAL 3,050.00 PROD1 FLOWCHECK FOR 10 MINUTES BEFORE I BRINGING BHA ACROSS BOP STACK-WELL STATIC. TAG UP WITH BHA. UNSTAB INJECTOR AND DISCONNECT UQC AND LQC. PULL BHAAND CHANGE OUT HOT SUB. MAKE UP BHA AND RIH. MAKE UP UQC AND LQC. STAB INJECTOR ON STUMP. TEST QTS. MWD TEST TOOLS AT SURFACE. 17:30 - 18:15 0.75 STWHIP N DFAL 3,050.00 PROD1 RUN IN HOLE WITH BUILD BHA FROM SURFACE TO 3050'. 18:15 - 19:40 1.42 STWHIP P PROD1 RUN IN HOLE WITH BUILD BHA FROM 3050'. PUMP AT.83 BPM WITH 1.31 BPM OUT. 19:40 - 19:50 0.17 STWHIP P PROD1 PERFORM TIE INTO TOP OF SAG W/-21 CORRECTION PERFORM FINGERPRINT. PERFORM SPR'S 19:50 - 00:00 4.17 STWHIP P PROD1 DRILLING BUILD AT 9110' FREE SPIN=2360 PSI AT 2.76 BPM RATE IN=2.76 BPM RATE OUT=2.76 BPM MW IN=8.67 PPG MW OUT=8.61 PPG ECD =9.14 PPG WOB=1.4/2.5K CIRC PSI=2500 PSI IAP=247 PSI OAP=54 PSI PVT=328 BBLS LOTS OF STALLS. TIME DRILL TO GET PATTERN GOING 7/8/2015 00:00 - 02:00 2.00 DRILL P PROD1 DRILLING BUILD FREE SPIN=2360 PSI AT 2.76 BPM RATE IN=2.81 BPM RATE OUT=2.81 BPM MW IN=8.67 PPG MW OUT=8.61 PPG ECD =9.14 PPG WOB=1K CIRC PSI=2500 PSI IAP=250 PSI OAP=55 PSI PVT=328 BBLS MULTIPLE STALLS. SHALE LIMESTONE/ PYRITE 02:00 - 04:00 2.00 DRILL P PROD1 DRILLING BUILD FREE SPIN=2360 PSI AT 2.76 BPM RATE IN=2.84 BPM RATE OUT=2.83 BPM MW IN=8.67 PPG MW OUT=8.61 PPG ECD =9.14 PPG WOB=1K CIRC PSI=2500 PSI IAP=283 PSI OAP=55 PSI PVT=327 BBLS MULTIPLE STALLS. Printed 7/14/2015 11:44:19AM IEEE= 6-3/8'CMV — WELLtF,AD= GRAY F-1 5A ',' TY NOTES: WELL ANGLE>70°@ 10038'. " ACTUATOR= BAKER C HT1AL KB.ELE 71.31' 20832600'' -1.159:15:"OTIS SSSVPACKEi2 LAND NP,D=4.562' H.. BF" EV= 37.1'' KOP= 937(7 MaxAngle@= 97° 9671' CONDUCTOR, Datum ND= 9327' —4' /1 Datum ND= 8800 SS ID= .... GAS UFT MANDRELS ST A) ND DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80 BTRS,D=12.347" -+ 2674• , 12 3013 3012 4 CA DMY RK 0 03/16/15 11 4964 4851 24 CA DMY RI< 0 09/23/03 10 6072 5850 27 CA DMY RIC 0 08/21/03 9 6213 5976 27 CA DMY RI< 0 03/16/15 Minimum ID =2.372" (_,419648' 8 6786 6489 26 CA DMY RK 0 08/21/03 TOP OF 2-7/8" LINER 7 6933 6623 25 CA DMY FK 0 08/21/03 6 7313 6970 23 CA DMY RK 0 08/21/03 5 7456 7102 22 CA 'DMY RK 0 04/23/15 1 4 7794 7417 20 CA DMY RK 0 08/21/03 3 7938 7553 20 CA DMY FE 0 08/21/03 2 8120 7724 20 CA DMY RK 0 08/21/03 1 8266 7861 20 CA DMY RK 0 04/22/05 STA#5=DMY VALVE HAS EXTENDED PACKING I I 8325' H5-112"OTIS XA SLD SLV,D=4.56Z MLLOUT WM DOW (F-156) 9069'-9077' 8386' H9 5/8"X 7'BAKER SBR TBG SEAL ASSY 8405' -19-5/8"X 5-1/2'BKR SAB PKR,D=4.892" C 8405' -I5-112"X 4-1/2"X0,0=3.958" 5-1/2"TBG,174,L-80 U4S,.0232 bpf,D=4.892" --{ 8405' TOP OF 7"BKR HGR,D= • ---I 8464' ' 8462' -{4-1/2"OTIS X NP,D=3.813' II 1 6 • H4-1/2"0115 XN NP,D=3.80- 4-1/2"TBG,12.64,L-80,.0152 bpf,D=3.958" H 8549' / 9-518'CSG,47#,L-80 BTRS,D=8.681 -1 8956' 8560' H4-1/2 WLEG,D=3.958' 8503' -{ELMD TT LOGGED 04/02/83 7'X 4-12"DELTA WF4PSTOCK(07/06/15) H 9064' 7"LM,29#,L-80 U4S,.0371 bpf,D=6.184' H -9064' JET CUT TBG(06/09/15) -{ 9145' 9150' H TOP OF CBNBJT K. !.A7.. TOP OF M-1'STOCK H 9366' 'v1% 44 MLLOUT WINDOW (F-15A) 9370'-9375' 7"LNR,294,L-80 U4S,.0371 bpf,D=6.184' -{ -9370 ', \ 9510' -I3-3/16'CIBP(04/11/15) rAvAveAveiv V PERFORATION SUMMARY 144414444444!444 // 9630' -CBP PLUG MLL®& REF LOG:MCNUCCUGR ON 09/04/03 % PUSHED TO XO(04/24/13) ANGLE AT TOP PERF:57"Q 9555' Note:Refer to Production DB for historical perf data 9630' 3-3/16"X 2-7/8" SIZE SPF INTERVAL Opn/Sqz SHOT SLY X0,0=2.440' 2" 6 9555-9585 0 04/15/10 2" 6 9700-9750 0 06/01/06 3-3/16"LNR,6.2#,L-80 TCI, - 9630' PBTD - 11197 2' 6 9865-9890 0 02/24/05 .0076 bpf,D=2.805" 2" 6 10210-10235 0 02/24/05 2" 6 10295-10320 0 02/24/05 2" 4 10570-10700 0 09/05/03 2-7/8"INR,6.16#,L-80 SR, H 11226' 2" 4 10950-11185 0 09/05/03Al, .0058 bpf,D=2.441" N, DATE REV BY COMM NTS DATE REV BY COMMENTS PRU JHOE BAY LINT 04/15182 ORIGINAL COMPLETION 05/04/15 RCT/JMD GLV C/O(04123/15) WELL: F-15A 09/06/03 DAC/KK CTD SIDETRACK(F-15A) 05/26/15 PJC REFORMAT-PRE RIG FERMI Pb: 2031370 03/11/14 SB/JMD FERF CORRECTIONS 06/26/15 GTW/NMC JET CUT TBG(06/09/15) AR No: 50-029-20651-01 03/18115 .LS/PJC PILL FLOW-THRU SUB(08/09/13) SEC 2,T11N,R13E,1996'FSL&2201'FEL 03/20115 JLS/JMD GLV CIO(03/16/15) 04/11/15 GW/PJC SET CEP@ 9510' BP Exploration(Alaska) (cOF � jsTHE STATE Alaska Oil and GasofALASI��A.���, Conservation Commission - tibt_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ^ ' Main 907.279.1433 OFALAS�� `iUl� `7 2-MS Fax 907.276 7542 SalaGES www aogcc.alaska.gov John McMullenca D 137 Engineering Team Leader BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU F-15A Sundry Number: 315-328 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, Cathy P Foerster Chair DATED this S day of June, 2015 Encl. STATE OF ALASKA RECEIVED , ALA,_..;,OIL AND GAS CONSERVATION COMMIoSION APPLICATION FOR SUNDRY APPROVAL MAY 2 7 2015 20 AAC 25.280 D?S 6/S /S 1. Type of Request: /A )cCC ❑Abandon . ®Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension ❑Operations Shutdown ❑Re-Enter Suspended Well 0 Stimulate ❑Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. 0 Exploratory 0 Stratigraphic 203-137 . 3. Address. ®Development 0 Service 6. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-20651-01-00 • 7. If perforating. 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? PBU F-15A ' Will planned perforations require a Spacing Exception? 0 Yes No 9. Property Designatior 10.Field/Pool(s). ADL 028280 ' Prudhoe Bay Field/Prudhoe Bay Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured) 11226' . 9050' ' 9510' 9038' 9510' 9630' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20"x 30" 37'- 117' 37'- 117' Surface 2674' 13-3/8" 36'-2710' 36'-2710' 4930 2670 Intermediate 8922' 9-5/8" 34'-8956' 34'-8515' 6870 4760 Production Liner 932' 7" 8463'-9370' 8047'-8912' 7240 5410 Liner 2785' 3-1/2"x 3-3/16"x 2-7/8" 8441'- 11226' 8026'-9050' Perforation Depth MD(ft): Perforation Depth TVD(ft). Tubing Size: Tubing Grade: Tubing MD(ft): 9555'- 11185' 9067'-9048' 5-1/2", 17#x 4-1/2", 12.6# L-80 8550' Packers and SSSV Type: 9-5/8"x 5-1/2" Baker SAB Packer Packers and SSSV 8405'/7992' MD(ft)and TVD(ft): 12. Attachments: 13.Well Class after proposed work. • ®Description Summary of Proposal ®BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 Service 14. Estimated Date for 15. Well Status after proposed work. Commencing Operation June 10,2015 ❑Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG 0 Suspended• 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Travis Boltz,564-5750 Printed Name. Jo . .p Hel-7 Title: Engineering Team Leader/ mail:/ Travis.Boltza@bp.com � Signature: ( / \ Phone: 564-4711 Date: s ??//C L Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number 3 IS- 3 LSI; ❑Plug Integrity 6-BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other 50P first to 352,,,p5t /4.1P5p 15 24-Z4- 1 5. J . ffr1-Y) v/alrp re•yr-v-21-rt� frsI- r-o ZSUpSi fFC 2 � v . / lZ ( ) /4`fr-vvlc,fc plvq /.?ice ( rrnCvlf' G�.pprav-ld Pcr a O f1 Spacing Exception Required? 0 Yes ISI No Subsequent Form Required: iG — 4,6 Approved ByP APPROVED BY COMMISSIONER THE COMMISSION Date. G- S -(5-- Form 10-403 Revised 1 /2012 DrRdrciTtNisAlid for 12 months from the date of approval Submit In Duplicate art. b/5/� RBDMO JUN 1 1 20].��0c ---613 s7 zZ.-tr- To: Alaska Oil & Gas Conservation Commission From: Travis Boltz by CTD Engineer Date: May 27, 2015 Re: F-15A Sundry Approval Sundry approval is requested to plug the F-15A perforations as part of drilling and completing the proposed F-15B coiled tubing sidetrack. History of F-15A: F-15A is a CTD ST drilled in 2003 targeting Zone 2 sands. Tubing leak was in the 5-1/2" tubing on 4/10/15. An extended packing GLV at 7456' MD installed on 4/23/15 resolved the TxIA communication. Proposed plan for F-15B: Drill a through tubing sidetrack with Coiled Tubing Drilling rig on or around 10 July, 2015 with Nordic 2. The F-15A sidetrack will exit the existing 7" liner and kick off in the Shublik and target Zone 2 reserves. The proposed sidetrack is a -2515' horizontal Ivishak Zone 2 producer and will be completed with a 3-1/2" x 3-1/4" x 2-7/8" L-80 solid liner, cemented in place. This Sundry covers plugging the existing F-15A perforations via the F-15B liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Corcvr- Ti,e Sub i ea- ,,i1 /rndv Cc 6OR /> � o � ham- 7-kw r-ke a( ov , i✓4 e,. cycled 7 L „yeti 404 VE"p 1.-rr/� �ecu'�{ •. 14/yip '4/ r415 -.e/{ for ( 6 hovl"d of 1(Ow for rnpa„rd re CO��, front T4c rid � 4� _ P°r t` Ovt °r- T '001, � r/(✓/ Pre-Rig Work (scheduled to begin 10 June, 2015) 1. E Jet Cut Liner 9,145'MD 2. C Liner Catch and Release 3. V Swab Valve Test, Install Sarber Spool, Set TWC �� 4. 0 Remove Wellhouse and level pad G P 5 ' ` 50`3 _2ti Rig Work (scheduled to begin July 10th, 2015) 1. MIRU and test BOPE 250 psi low and 3,500 psi high. 5609 psi MASP). 2. Mill 3.80" window and 10' of rathole. 3. Drill Build section: 4.25" OH, -500' (25° deg/100 planned) 4. Drill Later section: 4.25" OH, -2015' (12° deg/100 planned) 6. Run 3-1/2" x 3-1/4" x 2-7/8 L-80 solid liner to leaving TOL 8,450' MD. 7. Pump primary cement TOC/TOL 8,840' MD, 43 bbls of 15.8 ppg cement planned. 8. Perform liner cleanout with mill, motor and GR/CCL log. 9. Perforate liner based on log interpretation 10. Freeze protect well to 2500' MD 11. Set TWC, RDMO Post-Rig Work: 1. Re-install wellhouse, flowline and pull TVVC. 2. Set generic GLV's, SBHPS, ASRC flow back, SIT. Travis Boltz CC: Well File CTD Engineer Joe Lastufka 564-5750 ELL1 EAD= GRAY Y K V I'U A L F-1 5E3 *Arc;I nv 1 rw: VW ELL AM LL� /u-e CTL ATOR= BAKER C 1AX DOGLEG.—"@ •.ff ITIAL KB.Eli 71.31' _.ELEV= 37.1' 2083' H5-1/2"OTIS SSSV LAND MP,D=4.562" = 9370 ax "CONDUCTOR, ? ax Angle= 97°@ 9671' - 4 411, GAS LIFT MANDRELS tum MD= 9327' #' 0= ST MO ND DEV TYPE VLV LATCH PORT DATE tum ND= 8800 SS 12 3013 3012 4 CA DMY RK 0 03/16/15 9-5/8'DV PKR -I 2600' I 11 4964 4851 24 CA DMY FE 0 09/23/03 10 6072 5850 27 CA DMY FE 0 08/21/03 13-3/8'CSG,72#,L-80 BTRS,D=12.34T -I 2674' 9 6213 5976 27 CA DMY RK 0 03/16/15 8 6786 6489 26 CA DMY RK 0 08/21/03 Minimum ID = n cm 7 6933 6623 25 CA DMY FE 0 08/21/03 6 7313 6970 23 CA DMY RK 0 08/21/03 5 7456 7102 22 CA "DMY RK 0 04/23/15 4 7794 7417 20 CA DMY RK 0 08/21/03 3 7938 7553 20 CA DMY RK 0 08/21/03 2 8120 7724 20 CA DMY RK 0 08/21/03 I I 1 8266 7861 20 CA DMY FE 0 04/22/05 \i "STA#5=DMY VALVE HAS EXTENDED PACKNG 5-1/2'TBG,17#,L-80 U4S,.0232 bpf,D=4.892" -I $405• 1— 8325' H 5-1/2"OTIS XA SLD SLV,D=4.562' 8386' -{9-5/8"X 5-1/2"BKR SBR SEAL ASSY $405' -9-5/8"X 5-1/2"BKR SAB PKR,D=4.892" 8405' H5-1/2"X 4-1/2"XO,D=3.958" TOP OF 3-1/2"X 3-1/4"X 2-7/8"LNR/CMTD -1 -8450 ^8450 -13.7"BKR DEPLOY SLV,D=3.00" iFli---- -I 3-1/2"HES X NP,D=2.813" TOP OF 7"BKR HGR,D= " -( 8464' •Ho ' 8462' -14-1/T OTIS X NP,D=3.813" 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958' -{ 8549' 8506" -14-112'0715 XN NP,D=3.80' BEHIND 8550' -{4-t/2 wLEG,D=3.958" CT LNR 8503' H ELMD TT LOGG®04/02/83 9-5/8"CSG,47#,L-80 BTRS,D=8.681 H 8956' I-4 Ili 13-1/2"LNR,_#, ,.0087,13=2.992" -1 -9180 9180 -i 3-1/2"X 3-3-16"XO,ID=2.786" 7"X 41'2"DELTA WHPSTOCK(XX/XX/15) -{ -9110 FALLOUT WINDOW (F-158) 9110'-_" 7"LNR,29#,L-80 U4S,.0371 bpf,D=6.184" -I -9110 -9835 -13-3/16"X 2-7/8""XO,D=2.377" PERFORATION SUMMARY REF LOG: ON XX/?W15 ki1I1i1I1I1I ►11111 ANGLE AT TOP PERF:_"Q 411* Note:Refer to Rod uction DB for historical perf data 10%SIZE SPF INTERVAL Opn/Sqz SI-DT SQZ 3-1/4"LNR,6.6#,L-80 TCLII, -{ -9835 ` .0079,D=2.850" Av. MID - / Ne -- 2-7/8"LNR,_#,L-80 STL,.0058,D=2.441" -I -9 35 / �/ // Z5 DATE REV BY COMuBNITS DATE REV BY COMv6NRS PRLDHOE BAY INT 04/15/82 ORIGINAL COMPLETION WELL F-15B 09/06103 DAC/IO( CTD SIDETRACK(F-15A) FERM T No: XX/XX/15 CTD SIDETRACK(F-15B) API No: 50-029-20651-02 05/26/15 PJC BULD PROPOSAL SEC 2,T11 N,R13E, 1996'FSL&2201'FEL RP FYnInratinn(Alaska% TREE= . 6-3/8"CMN — 1VMHiJfAD= GRAY F-1 5A S .tY NOTES: WELL ANGLE>70°@ 10038'. ACTUATOR= BAKER C NTIAL KB.ELE 71.31' BF ELEV= 37 1 2083' -�5-i/2"OT1S SSSV LAND NP,D=4.562' KOP= 9370 J Mex Angle= 97°©9671' —"CONDUCTOR l 2600' H9-5/8*DV PACKER 1 Datum MD= 932T #, — Datum TVD= 8800'SS E)=. GAS UFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 13.3/8"CSG,72#,L-80 BTRS,13=12.347" —1 2674' J--, k 12 3413 3012 4 CA DMY RK d 03✓16/15 11 4964 4851 24 CA DMY RK 0 09/23/03 10 6072 5850 27 CA DMY RK 0 08/21/03 9 6213 5976 27 CA DMY PoC 0 03/16/15 Minimum ID =2.372" ' 9648' 8 6786 6489 26 CA DMY RK 0 08/21/03 TOP OF 2-7/8" LINER 7 6933 6623 25 CA DMY RK 0 08/21/03 6 7313 6970 23 CA DMY RK 0 08/21/03 5 7456 7102 22 CA 'DMY RK 0 04/23/15 4 7794 7417 20 CA DMY RK 0 08/21/03 3 7938 7553 20 CA DMY FM 0 08/21/03 2 8120 7724 20 CA DMY RK 0 08/21/03 1 8266 7861 20 CA DMY RK 0 04/22/05 STA#5=DMY VALVE HAS EXTENDED PACKING I I 8325' --EOMXA SLD SLV,ID=4.562" --I 8386' —(BAKER SBR TBG SEAL ASSY 8405' —9-5/8"X 5-1/2"BKR SAB PKR,D=4.892' 2 r 8405' —15-1/2-X 4-1/2"XO,D=3.958' 5-1/2"TBG,17#,L-80 U4S,.0232 bpf,13=4.892" H 8405' 8441' --1 3.7"BKR DEPLOY SLV,D=3.00" 8462' H3-1/2"FES X Ns),D=2.813" 3-1/2"LNR,8.813,L-80 STL,.0087 bpf,D=2.992 -4 8461' I —r...........------1 \\ 8461' —43-1/2'X3-3/16X0,D=2.786" TOP OF 7"BKR HGR D= " —I 8464' I1....7... 8462' —{4-1/2'OTIS X NP,D=3.813" 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958' -4 8549' / \ _ 8506' —14-1/2"OTIS XN NP,D=3.80" \ BEHIND 8550* H4-1/2 WLEG,D=3.956" CT LNR 8503' -{ELMD TT LOGGED 04/02/83 9-5/8"CSG,47#,L-80 BTRS,D=8.681 — 8956' I L 9150' H TOP OF CEMENT TOP OF WFUPSTOCK -{ 9366' '.44 '44 Ml LOUT WINDOW (F-15A) 9374'-9375' 7"LNR,29#,L-80 U4S,.0371 bpf,D=6.184' H —9370 / N, ,,`. 9510' H3-3/16"OBP(04/11/15) PERFORATION SUMMARY 41...14.4.4.4.4 * , 9630' —CEP PLUG MILLED& REF LOG:MCNUCCUGR ON 09/04/03 PUSHED TO XO(04/24/13) ANGLE AT TOP PERF:57°@ 9555' 9630' --3-3/16"X 2-718' Note:Refer to Production D8 for historical pert data ` SIZE SPF INTERVAL Opn/Sqz SHOT SQZ XO,D=2.440" 2" 6 9555-9585 0 04/15/10 2' 6 9700-9750 0 06101/06 3-3/16"LP,6.2#,L-80 TCI, -- 9630' PBTD — 11192' 2" 6 9865-9890 0 02/24/05 .0076 bpf,D=2.805' 2' 6 10210-10235 0 02/24/05 2" 6 10295-10320 0 02/24/05 2" 4 10570- 10700 O 09/05/03 2' 4 10950-11185 O 09/05/03 2-7l8"LNR 6.16#,L-80 STL, 11226' A;` .0058bpf,D=2.441" o``- ' DATE REV BY COMMENTS DATE REV BY COMMtENTS PRUDE DE BAY UNIT 04/15/82 ORIGINAL COMPLETION 05/04/15 RCT/JM)GLV CJO(04/23/15) WELL: F-15A 09/06/03 DAC/KK CTD SIDETRACK(F-15A) 05/26/15 PJC REFORMAT-PRE RIG PERMT No:'2031370 03/11/14 SB/JMD PERF CORRECTIONS API No: 50-029-20651-01 03/18/15 JLS/PJC RLL FLOW-THRU SW(08/09/13) SEC 2,T11N,R13E, 1996'FSL&2201'FEL 03/20/15 JLS/JMD GLV C/O(03/16/15) 04/11/15 GW/PJC SET CEP • 9510' BP Exploration(Alaska) - - - - - 1 1 L ... 1 r1 1 1 I1 I — 9 I Y/S I I II 4 I s �.4 • • E i• ;' d I • 1 1 .< ill I ' A I ..IIAlI..— A I 1 -I- IL. il ( "I Q q 1 (9 1 Q y .. 1 u n I o CJ Q 1 Z I I O 1 A I I- g a I 1 J 61 x1 °I I 1 Mu 1 1 m'1 e $I I ♦ • I U �i 1 \ J a x 1 1 Ce w I J 1 1 f _ \ 1 • U. i I O 5 1 u ¢ u u"< 2 w I ji U a � •�� 1 = . of I N N 1 1 :• U u a .i. _ .: '119111100111111 \ 1_ ilEF • • . A In r g ♦ 1 V I I le vg. s il I " e < moi.. I 0 .r yI f s I L _ �u u 1 U R Q' `= 1'-i : iI SI1ae U' 3 I hi! u 11 „ HH 1 U I E u = d 5 3 I g U , A ,.., , . 1 . _ I Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the Patricia or Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" —' boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Patricia or Steve work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then V check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change Jenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. zo 3- WELL LOG TRANSMITTAL DATA LOGGED 5 IAD ..i.K BEND R To: Alaska Oil and Gas Conservation Comm. April 22, 2015 Attn.: Makana Bender n`° 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 I '"_15 OG RE: Radial Cement Bond Log: F-15A Run Date: 4/10/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 F-15A Data in DLIS/LAS format, Digital Log Image files 1 CD Rom 50-029-20651-01 Radial Cement Bond Log 1 Color Log 50-029-20651-01 SCANNED MA)( 2 7 Z015 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 2o3-v 1 2510% WELL L©GRECEIVED TRANSMITTAL IPPR 2 2 2015 AOGCC PRoACTivE DIAgNosriC SERViCES, INC. DATA LOGGED S/13/2015 M K.BENDER To: AOGCC Makana Bender 333 W. 7th Ave Suite 100 SCANNED ."_ I�; 6 2 Anchorage,Alaska 99501 (907) 793-1225 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: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2 - 1 900 Benson Blvd. Anchorage,AK 99508 qancpdc@bp.com and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 09-Apr-15 F-15A BL/ CD 50-029-20651-01 2) Signed : / 9Z Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Archives\MasterTemplateFiles\Templates\DIstnbution\TransmatalSheets\BP_Transmit docx Image _oject Well History File c!er 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. ~ Q3 - L 3.. 7 Well History File Identifier Organizing (done) o Two-sided III 1111111111111111 o Rescan Needed 11111111111/111111/ RE,AN ~olor Items: o Greyscale Items: DIGITAL DATA ~iskettes, No. t o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: BY: ~ , Date: J~ ¡ ó ðS- o Other:: BY: ~ Date: f d- 1-3 OS- / X 30 = ,-~D + DatelJ- IBIOS /5/ t11P 1/111111111111" III VvlrJ /5/ Project Proofing Scanning Preparation BY: ~ Ie¡ = TOTAL PAGES Lf-O (Count does not include cover s,.hlffj¡/' '.. 10 /5/ V V ~ ,- 1111111111111111111 Production Scanning Stage 1 Page Count from Scanned File: L~() (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES BY: ~ Date:/a-/,3{êJS- Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO /5/ VV{; P NO BY: Maria Date: /5/ 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: /5/ Comments about this file: Quality Checked III 11111111I1111111 10/6/2005 Well History File Cover Page .doc STATE OF ALASKA M AL�CA OIL AND GAS CONSERVATION COMMON t� REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon Li Repair Well Plug Perforations U Perforate U Other Mill CI BP Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc . Development El • Exploratory ❑ 203 -137 -0 • 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20651 -01 -00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028281 • PBU F -15A - 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11226 feet • Plugs measured 9630 feet true vertical 9049.73 feet Junk measured None feet Effective Depth measured 9630 feet Packer measured 8401 feet true vertical 9091.54 feet true vertical 7988.64 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 76 20" 91.5# H -40 34 - 110 34 - 110 1490 470 Surface 2641 13 -3/8" 72# L -80 33 - 2674 33 - 2673.84 4930 2670 Intermediate None None None None None None Production 8924 9 -5/8" 47# L -80 32 - 8956 32 - 8514.64 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet SCANNED JUL 2 2 2013 True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) 0 8401 7988.64 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 10 5392 1 0 165 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 0 . Gas ❑ WDSPLI GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCJ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summerhays(G�BP.com Printed Name Nita Summerhays Title Petrotechnical Data Technician i ram: " -- - - r'4l/� .e / � j �� Phone 564 -4035 Date 5/15/2013 RBI MS MAY 17 20 -/3 // Form 10 -404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028281 - CTU #3 1.75" coil, (CTV= 33.4bbls) Job Scope: Mill CIBP MIRU. MU milling BHA w/ 2.69" 3- bladed Bow Mill and RIH. 4/22/2013 ** *Job continued * ** CTU #3 1.75" coil, (CTV= 33.4bbls) Job Scope: Mill CIBP RIH w/ 2.69" 3- bladed Bow Mill. Tag down on CIBP at 9589'. Begin milling on CIBP, stall 21 times. Unable to get plug pushed to the 2- 7/8"x3- 3/16" liner. POOH and inspect mill. MU venturi assembly and RIH. Reached depth and worked venturi at —9,593'. POOH. Recovered small metal pieces. MU mud motor and 5- bladed junk mill. RIH. Wet tag at 9,589'. Begin milling, but unable to make any depth. POOH and inspect mill. Cut 150' of pipe. 4/23/2013 ***Job continued on 4/24/13 WSR * ** C rU #3 1.75" coil, (CTV= 33.4bbls) Job Scope: Mill CIBP RIH w/ PDS GR /CCL and BKR 2 -5/8" venturi. Tagged down on plug at 9593'. Venturi on top of plug, started pushing plug down hole to 9620'. PUH and paint flag white at 9600'. Log jewelry log up at 50fpm from 8100 - 9620'. POOH. FP well w/ 55bbls of 60/40 methanol. Processed PDS data and confirmed the plug was pushed down to the X -O @ 9630'. RDMO. 4/24/2013 ** *Job complete * ** FLUIDS PUMPED BBLS 138 60/40 METH 673 1% SLICK KCL 811 TOTAL Perforation Attachment ADL0028281 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top ND Depth Base F -15A 4/15/2010 APF 9555 9560 9067.06 9069.71 F -15A 4/15/2010 APF 9560 9565 9069.71 9072.24 F -15A 4/15/2010 APF 9565 9570 9072.24 9074.63 F -15A 4/15/2010 APF 9570 9575 9074.63 9076.89 F -15A 4/14/2010 APF 9575 9580 9076.89 9079.01 F -15A 4/14/2010 APF 9580 9585 9079.01 9080.98 F -15A 4/24/2013 BPS 9700 9750 - 9087.13 9082.73 • F -15A 4/24/2013 BPS 9865 9890 9073.98 9071.75 F -15A 4/24/2013 BPS 10210 10235 9063.37 9061.66 F -15A 4/24/2013 BPS 10295 10320 9058.54 9056.7 F -15A 4/24/2013 BPS 10570 10700 9054.5 9052.04 F -15A 4/24/2013 BPS 10950 11185 9054.56 9048.45 BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • Casing / Tubing Attachment ADLOO28281 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 20" 91.5# H -40 34 - 110 34 - 110 1490 470 LINER 20 3 -1/2" 9.3# L -80 8441 - 8461 8026.48 - 8045.38 10160 10530 LINER 1169 3- 3/16" 6.2# L -80 8461 - 9630 8045.38 - 9091.54 LINER 906 7" 26# L -80 8464 - 9370 8048.22 - 8912.42 7240 5410 LINER 1596 2 -7/8" 6.16# L -80 9630 - 11226 9091.54 - 9049.73 13450 13890 PRODUCTION 8924 9 -5/8" 47# L -80 32 - 8956 32 - 8514.64 6870 4760 SLEEVE 5 5 -1/2" Otis Sliding Sleeve 8325 - 8330 7916.79 - 7921.51 • SURFACE 2641 13 -3/8" 72# L -80 33 - 2674 33 - 2673.84 4930 2670 TUBING 8374 5 -1/2" 17# L -80 31 - 8405 31 - 7992.42 7740 6280 TUBING 144 4 -1/2" 12.6# L -80 8405 - 8549 7992.42 - 8128.62 8430 7500 • • Tom= 6" CM/ • • IAR.LHEAD= SAFETY NOTI93: '""IA x OA CO ACTUATOR= OTIS F -1510 ENML KB. HE 71.31' BFa = 37.1' KOP= 9370 I 20103 I-- 15 071S S88V LAN? PP, D = 4.562' I MIX We = 9T 4? 9671' • 'Worn SD = 9327' DelumTVO= 8800' SS GAS LFTMAN)R8S ST M3 TVD DEI TYPE VLV LATCH PORT DATE 1 13.3/8" CSG, 7211, L-80, ID= 1Z347" i-I 2680' (---A , 12 3013 3012 4 CAM30 DOME RK 16 05103/06 11 4964 4851 24 CAM30 OIW RK 0 0923103 10 6072 5850 27 CAM:0 DIN RK 0 08121103 9 6213 5976 27 CALCO SO FE 20 05/03/06 8 6786 6489 26 CALM DMY RK 0 08121103 Mkimum ID = 2.372" @ 8848' 7 6933 6623 25 CAIOD 0151 FE 0 0812103 TM OF 2 -7118" LINER 6 7313 6970 23 CALCO DMY FE 0 08/21/03 5 7456 7102 22 CAIRO 0111 RK 0 08/2103 4 7794 7417 20 CALICO DIY FE 0 08121103 3 7938 7553 20 CALCO DIY FE 0 0812103 2 8120 7724 20 CAMX0 DIN FE 0 08/2103 1 8266 7861 20 CAM30 DMY FE 0 04/22105 I I I 8326' HOTS XA SLIDING SLEEVE, D =4.562" I MOW H BAKER SBR TBG SEAL ASSY I 8405' H9 -518" X 5-112' BKRSAB FM, D = 4.892" I 1 5-1/2' TBG, 17*, L-80 U4S, .0232 WOO = 4.892' H 8406' 8406' "i5 -1i2" X 4-,/2' XO / 8441' H 3.7' BKR OE R_OPYMEtT SLV, D = 3.0" I 84$0' H3 -1/2"I- SXNP,D = 2.8,3' I 1 3-1/2" TBG, 9.38, L-80, /0087 bpf, ID= 2.992' H 8461' I I 8481' H3- 1/2" -3/16" XO, D=2.786" I I I 8482' H4-11r OTIS X PP, D = 3.813' (B&tO CT LNR) I 8606' 4-112' one XN PP, D = 3.80' (Mike CT LJ+R) 1 14 -,/2' TBG, 12.8#, L-80, .0152 bpf, ID= 3.958' H 8645" i ( 8649' H4-1/2 BKR SOS TBG TAIL (BE HID CT L R) I 1 9-5/8" CSG, 478, L-80, D = 8.881 H 8866" I..J I 8603' Hamm LOGGED 04/02/83 (09-ti) CT LPR) I 14• - 8160' HT+oPOFCaIa�r I ITOP OF W I- EpsTOCIC H 9366' I • ! 4 4 I FALLOUT W PROW 9370' - 9375 `, ', 9630 CEBP PLUG MALL.® & PUSHED TO XO ► . 4� 4� . . 4 4 * * (04124/13) I r LPR, 298, L-80 U4S, .0371 bpf, 0 = 6.184" H 5814' 1 8630• 3 -3/16' X 2 -7/8" XO, D= 2.440' I PERFORATION SU1104ARY I( REF LOG: ICPL/CCIJGR ON 0904/03 ANGLEAT TOP PERF: 57' 0 9555' Noce: Refer to PLroduction OB for historical pert data 33/16' Lift 6.210, L-80, 9630' SIZE SPF MEZVAL OpnlSgz SHOT SQZ 0078 bpf, D = 2.805' 2' 6 9555 - 9585 0 04/15/10 2' 6 9700 - 9750 0 06101/06 2" 6 9865 - 9890 0 0224105 2" 6 10210 -10235 0 02/24/05 MID 11192' \` 2" 6 10295 -10320 0 02/24/05 2' 4 10570 -10700 0 09105/03 12 LPR, 6.161, L-80, .0058 bpf, D = 2.441" H 11226' 2' 4 10950 -11185 0 0910503 DATE REV BY COMM:NTS DATE REV BY OOMi.U4lS PRIJDEDEBAY UNT 04/15182 O11I11 P L COMPLETION 050706 DAV/PWG GLV CO (05103106) WELL F-15A 09/06103 DIACI1OC CTDSIEr ACK(F -15A) 0610106 GLMWG All) .. POUT No: I t031370 051403 JCANTLP GLV 00 04121/10 JIFISV ADD FEW (04/16/10) AR No: 50 -029- 20651 -01 0923/03 ROMJKK GLV CO 0502/13 TIW.W ML.LB) BRPUSIW TO XO (04124/13) SE: 2, T11N, R13E,1990 FSL 6 2201' R3. 03/02/05 SR31 LH ADD PERT (02/24/05) I 04/23105 RWIITLHGLV CO BP EaMori0on (Alaska) STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS ~tECE14ED APR 2 ] 2010 (~ 1. Operations Abandon ^ Repair Well ^ Plug Pertorations G f~PStimulate^ Oth r ~J~ ~ 6 S Pertormed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Ext~ ; Change Approved Program ^ Operat. Shutdown ^ Perforate 0 Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development 0 Exploratory ^ 203-1370 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-20651-01-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Numb@r: ~ ADLO-028281 • PBU F-15A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11226 feet Plugs (measured) 9600' 4/16/10 feet true vertical 9049.73 feet Junk (measured) None feet Effective Depth measured 11192 feet Packer (measured) 8405 true vertical 9048.66 feet (true vertical) 7992 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 34 - 114 34 - 114 1490 470 Surface 2646 13-3/8" 72# L-80 34 - 2680 34 - 2680 4930 2670 Intermediate 8923 9-5/8" 47# L-80 33 - 8956 33 - 8615 6870 4760 Liner 906 7" 29# L-80 8464 - 9370 8048 - 8912 8160 7020 Liner 20 3-1/2" 9.3# L-80 8441 -8461 8027 - 8045 10160 10530 Liner 1169 3-3/16" 6.2# L-80 8461 - 9630 8045 - 9092 8520 7660 Liner 1596 2-7/8" 6.16# L-80 9630 - 11226 9092 - 9050 13450 13890 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ - Tubing: (size, grade, measured and true vertical depth) 5-1/2" 17# L-80 31 -8405 31 - 7992 4-1 /2" 12.6# L-80 8405 - 8549 7992 - 8129 Packers and SSSV (type, measured and true vertical depth) 5-1/2" Baker SAB Packer _ .8405 7992 12. Stimulation or cement squeeze summary: Intervals treated (measured): - , ~~~, ~ ~~~~( Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 113 11303 13 2235 Subsequent to operation: SI 14, Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 4/20/2010 Form 1 - ~avnln~ Arrc 1 z NAI ~~y,-n ~-. yz9•~o ,~ ~s/rv F-15A 203-137 oroe ATTA!`1.111ACAIT n LJ • Sw Name Operation Date Perf Operation Code ~ Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base F-15A 9/5103 PER 10,570. 10,700. 9,054.5 9,052.04 F-15A 9/5/03 PER 10,950. 11,185. 9,054.56 9,048.45 F-15A 2/24/05 APF 9,865. 9,890. 9,073.98 9,071.75 F-15A 2/24105 APF 10,210. 10,235. 9,063.37 9,061.66 F-15A 2/24/05 APF 10,295. 10,320. 9,058.54 9,056.7 F-15A 6/1 /06 APF 9,700. 9,750. 9,087.13 9,082.73 F-15A 4/14/10 APF ~ 9,580. ~/ 9,585. 9,079.01 9,080.98 F-15A 4/14/10 APF ' 9,575. 9,580. 9,076.89 9,079.01 F-15A 4/15/10 APF ~ 9,555. 9,560. 9,067.06 9,069.71 F-15A 4/15/10 APF 9,560. 9,565. 9,069.71 9,072.24 F-15A 4/15/10 APF 9,565. 9,570. 9,072.24 9,074.63 F-15A 4115/10 APF 9,570. 9,575. 9,074.63 9,076.89 F-15A 4/16/10 BPS 9,600. 9,700. 9,085.95 9,087.13 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 F-15A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY ~ 4/14/2010T/I/0=2100/1840/760 Assist E-Line, Load Tbg (Perforating) Loaded Tbg w/ 5 bbl I 1 methanol spear, 296 bbls 1 %KCL w/ Safe Lube. Freeze protected Tbg w/ 58 bbls ~ ;crude. Pump 82 bbls crude down tbg to assist E-line w/ RIH. Continued on 04-15- j10 __ _ _-___ ~ .__,.__ _~ ~ __ _ _ . _______.... ._.K _ . _e ~e.... __. _ ._ 4/14/20101*** WELL SHUT IN ON ARRIVAL"** (E-LINE: 30' ADPERF AND SET CIBP) [INITIAL T/I/O: 2000/1850/750 PSI. ' 'ATTEMPTED TO RIH WITH 2.5" HSD GUNS, BUT COULD NOT GET PAST DOGLEG. PERFORATE 9580' - 9585' 2" HSD POWERJET `PEA RFORATE 9575' __9580' 2" HSD_POWERJET 1 '=API DATA. PENETRATION DEPTH: 18.6" HOLE SIZE: 0.20" ***JOB CONTINUED ON 15-APRIL-2010*** i • 4/15/2010 **" JOB CONTINUED FROM 14-APRIL-2010'`** (E-LINE: 30' ADPERF AND SET CIBP) PERFORATE: 9575'-9555' API DATA: 2" HSD POWERJET, PENETRATION DEPTH: 18.6" HOLE SIZE: 0.20" DRIFT 2.5" BULLNOSE TO XO @ 9630' '"*"CONTINUE JOB ON 16-APRIL-2010*"* r__~. _ _~ ~~_ ~ __ _._..__.__.~ _.~ ...__~... _ ~u ~_- --. . 4/15/20101Continued from 04-14-10 Assist E-Line Pump 234 bbls crude down tbg to assist E- ;line while RIH. Continued on 04-16-10 4/16/2010 "" JOB CONTINUED FROM 15-APRIL-2010'`"" (E-LINE: 30' ADPERF AND SET CIBP) ;SET HALLIBURTON WIDE RANGE CIBP AT 9600'. ,PLUG OD 2.281", 26" OAL PRE-SET. TOP OF PLUG AT 9599' _. FINAL T/I/O: 0/1300/800 PSI. E**"JOB COMPLETE"*" FLUIDS PUMPED BBLS 296 1 %KCL W/SAFE LUBE 8 60/40 METH 3 DIESEL 307 Total SEE = s" cn WELLtiEA~ - ACTUATOR = OTIS KB. ELEV = 71.31' BF. ELEV = 37.1' KOP = 9374' Max Angle = 97 @ 9671' Datum MD = 9327 -Datum TV D = 8800' SS 13-318" CSG, 72#, L-80, ID = 12.347" ~-~ 2680' SAFETY ES: ***IAxOACOMM*** F-15A 2093' -j 5-112" OTIS SSSV LAND Nq3, ID = 4.562" GAS LIFT MANDRELS Minimum ID = 2.372" ~ 9648' TOP OF 2-718" LINER ~ 5-1/2" TBG, 17#, L-80 IJ4S, .0232 bpf, ID = 4.892" ~ 3-112" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" ~-~ 8461' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 8549' 9-518" CSG, 47#, L-80, ID = 8.681 $956' TOP OF W HIPSTOCK ~-I 9366' ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 3013 2941 4 CAMCO DOME RK 16 05!03(06 11 4964 4780 24 CAMCO DMY RK 0 09(23!03 10 6072 5779 27 CAMCO DMY RK 0 9 6213 5904 27 CAMCO SO RK 20 05!03/06 8 6786 6418 26 CAMCO DMY RK 0 7 6933 6551 26 CAMCO DMY RK 0 6 7313 6899 23 CAMCO DMY RK 0 5 7456 7030 22 CAMCO DMY RK 0 4 7794 7345 20 CAMCO DMY RK 0 3 7938 7481 20 CAMCO DMY RK 0 2 8120 7652 20 CAMCO DMY RK 0 1 8266 7790 20 CAMGO DMY RK 0 04122/05 8325' OTIS XA SL~tVG SLEEV E, ID = 4.562" 8383' BAKER SBRTBG SEAL ASSY~ $405' 9-5/8" X 5-112" BKR SAB PKR ID = 4.892" $405' 5-112" X4-1/2" XO ~ $441' 3.7" BKR DEPLOYMENT SLV, ID = 3.0" I $460' 3-1/2" HES X NIP, ID = 2.813" 8461' 3-112" X 3-3/16" XO, ID = 2.786" $462' 4-1/2" OTIS X N~', ID = 3.813" (BEHIND CT LNR) 8505' 4-1/2" OTIS XN NIP, ~ = 3.80" (BEH~VD GT LNR) $549' 4-112 BKR 50S TBG TAB (BEHIND CT LNR) 8503' ELMD TT LOGG®04!02!83 (BEHIND CT LNR) 9150' TOP OF CEMENT MLLOUT WINDOW 9370' - 9375' ~ 7" LNR, 29#, L-80 U4S, .0371 bpf, ID = 6.184" ~ PERFORATION SUMMARY REF LOG: MCNLlCCL/GR ON 09/04/03 ANGLE AT TOP PERF: 96 @ 9700" Note: Refer to Production ~ for historical pert data SIZE SPF k'V7ERVAL Opn/Sqz DATE 2" 6 9700 - 9750 O O6/01 /06 2" 6 9865 - 9890 O 02/24/05 2" 4 10950 - 11185 O 09/05/03 2" 4 10570 - 10700 O 09/05/03 2" 6 10295 - 10320 O 02/24/05 2" 6 10210 - 10235 O 02/24/05 3-3116" LNR, 6.2#, L-80, I 9630' .0076 bpf, ID = 2.805" 9630' - j 3-3116" X 2-718" XO, ID = 2.440" ~C18P ~ 96QO, PBTD -{ 11192' ~ 2-718" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" 11226' DATE REV BY COMMEMS DATE REV BY COMMENTS 04/15182 ORIGINAL COMPLETION 05/07/06 DAV/PA GLV GO (05/03106} 09!06!03 DACfKK CTD SIDETRACK {F-15A} 06/01/06 GLMIPA ADPERF 09/14/03 JCM/TLP GLV GO 09123!03 RWL/KK GLV GO 03/02!05 SRBtfLH ADPERF (02/24/05) 04!23!05 RWUTLH GLV GO PRUDHOE BAY UNIT WELL: F-15A PERMtT No: ~L031370 API No: 50-029-20651-01 SEC 2, T11 N, R13E, 3284' SNL 8~ 2201' WEL BP Exploration {Alaska} 00/23/09 Schlumherger N0.5372 Alaska Data Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 8 Log Description Date BL Color CD 06 -09 AP3O -00052 LDL 1 "-Pi T 1 "5 07/21/09 1 1 Z•22B AWL8-00025 SBHP SURVEY j Gi 06/29/09 1 1 F -03A AV114-00024 RST 1 08/29/09 1 1 4 1-291M-25 83SQ -00018 RST 08/09/09 1 1 F -15A AYQO -00038 RST 09/03/09 1 1 18 -29C O9AKA0144 `OH D/LWD EDIT 06/23/09 4 •(THIS WELL DELIVERED 09/21/09, TRANS 9 4841 TO AOGCC TO MEET COMPLIANCE) 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc Alaska Data Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Slreel, Sole 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 c' 2009 C( II • .~. -~.-~ -~ MICROFILMED 03/0112008 DO NOT PLACE ~: t~~~~~ .~~ ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_Inserts~Microfilm Marker.doc I Gas Cons. n 1. Operations Performed: AncBQf~ Abandon 0 Repair WellO Pluç PerforationsD Stimulate ŒJ Alter Casing 0 Pull TubingD Perforate New Pool 0 WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate ŒJ Re-enter Suspended wellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development [!] ExploratoryD 203-1370 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicD ServiceD 50-029-20651-01-00 7. KB Elevation (ft): 9. Well Name and Number: 71.30 F-15A 8. Property Designation: 10. Field/Pool(s): ADL-028281 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 11226 feet true vertical 9049.7 feet Plugs (measured) None Effective Depth measured 11192 feet Junk (measured) None true vertical 9048.7 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 34 - 114 34.0 - 114.0 1490 470 SURFACE 2646 13-3/8" 72# L-80 34 - 2680 34.0 - 2679.8 4930 2670 PRODUCTION 8923 9-5/8" 47# L-80 33 - 8956 33.0 - 8614.6 6870 4760 LINER 906 7" 29# L-80 8464 - 9370 8048.2 - 8912.4 8160 7020 LINER 20 3-1/2" 9.3# L-80 8441 - 8461 8026.5 - 8045.4 10160 10530 LINER 1169 3-3/16" 6.2# L-80 8461 - 9630 8045.4 - 9091.5 8520 7660 LINER 1596 2-7/8" 6.16# L-80 9630 - 11226 9091.5 - 9049.7 13450 13890 Perforation depth: Measured depth: 9700-9750,9865-9890,10210-10235, 10295-10320, 10570-10700, 10950-11185 True vertical depth: 9087-9083,9074-9072,9063-9062,9059-9057, 9054-9052, 9055-9048 Tubinç ( size, ç¡rade, and measured depth): 5·1/2" 17# L-80 @ 31 - 8405 4-1/2" 12.6# L-80 @ 8405 - 8549 Packers & SSSV (type & measured depth): 9-5/8" Baker SAB Packer @ 8405 ···cr\NNE~\ c.:c1:' 2 (.:; 2nOp 5·1/2" OTIS SSSV Land Nip @ 2093 't~ ,,' .;'1- - _ '.' \, _ ,~:/ ~J 1- r' 1;~ ;- '''';'': 12. Stimulation or cement squeeze summary: RBDMS 8Ft SEP 2 ;) 2006 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 628 30,994 36 --- 1153 Subsequent to operation: 747 34,950 135 -- 1004 14. Attachments: 15. Well Class after proposed work: Exploratory(] DevelopmentOO ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒ] GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr A Title Petroleum Engineer Signature A".Þ/I ~ ~A tb.-J,A\ 1 Phone 564-5174 Date 9/18/06 r./ t-orm - eVlse \.../1)1-' I'¿ ~//~ . . RECEWED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 1 9 2006 REPORT OF SUNDRY WELL OPERA TIQll~n & . . F-15A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/28/2006 TestEvent --- BOPD: 606 BWPD: 31 MCFPD: 28,546 AL Rate: 06/11/2006 ASRC Acid Flow back. No well test done after flow back. The average rates for the last four hours before shutting in to rig off. The last pH @ 5. 1000 bls/d 9 mmscfpd 5% w/c 1500 WHP 45 deg WHT. 06/02/2006 CTU #9. Acid Stimulation. RIH with 2.0" JSN. Dry tag at 11,152' CTMD. PUH to 9650' CTMD and pump acid job as per program. Note: Wellhead psi went from 0 to 300 psi during acid treatment. Pooh Hand well over to Seperator for Flowback, PBGL rigged up. Job Complete **Notify DSO of well status** 06/01/2006 CTU #9. Log for flag/Add Perf/Acid stirn. MIRU. MU Weatherford and PDS tools for flag coorelation run. Bullhead kill well with 250 bbls of 2% KCI. RIH and log from 10,000' to 8900'. Painted flag at 9797' CTMD. Depth correction (-2') tied into SWS MCNL - 9/4/2003. RIH with Gun #1, (25' - SWS 2.00" HSD-PJ2006 HMX @ 6 spf). Correct depth to bottom shot at flag. Perforate interval from 9750' to 9725'. POOH. All shots fired. RIH with Gun #2 (25' - SWS 2.00" HSD-PJ2006 HMX @ 6 spf). Correct depth to top shot at flag. Perforate interval from 9700' to 9725'. POOH. All shots fired. MU 2" JSN for acid stimulation. OS/26/2006 TII/O = 2220/210/370. SI. TBG FL (pre-Perf, Acid Stirn). TBG FL @ 8788' (194 bbls) OS/24/2006 T/I/O=2280/850/400, Temp=SI. Bleed lAP < 300 psi (pre Acid Stirn). TBGP remained unchanged, lAP increased 40 psi, OAP remained unchanged from 5-21-06. InitiallA FL @ 4087' (179 bbls). Bled lAP, to DHD upright, from 810 psi to 170 psi in 3 hrs. No change in TBG & OA pressures. Monitored pressures for 30 min, TBGP remained unchanged, lAP increased 10 psi to 180 psi, OAP remained unchanged. FWHP=2280/180/400. FLUIDS PUMPED BBLS 0 PT Surface Equipment 70 60/40 Methanol Water 714 2% KCL Water 75 12% HCL Acid 859 TOTAL Page 1 OTIS 71.31' 37.1' 9370' 97 @ 9671' 9327' 8800' SS F-15A TREE = W8...LHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = 6" CrN . 2093' -i 5-112" OTIS SSSV LAND NIP, 10 = 4.562" I Minimum ID = 2.372" @ 9648' TOP OF 2-7/8" LINER ST MD lVD 12 3013 2941 11 4964 4780 10 6072 5779 9 6213 5904 8 6786 6418 7 6933 6551 6 7313 6899 5 7456 7030 4 7794 7345 3 7938 7481 2 8120 7652 1 8266 7790 GAS LIFT MANDRELS DEV TYPE VLV LATCH 4 CAMCO DOME RK 24 CAMCO DMY RK 27 CAMCO DMY RK 27 CAMCO SO RK 26 CAMCO DMY RK 26 CAMCO DMY RK 23 CAMCO DMY RK 22 CAMCO DMY RK 20 CAMCO DMY RK 20 CAMCO DMY RK 20 CAMCO DMY RK 20 CAMCO DMY RK PORT DA TE 16 05/03/06 o 09/23/03 o 20 05/03/06 o o o o o o o o 04/22/05 113-3/8" CSG, 72#, L-80, 10= 12.347" I 2680' 1 TOP OF WHIPSTOCK H 9366' 8325' -1 OTIS XA SLIDING SLEEVE, 10 = 4.562" -1 BAKER SBR TBG SEAL ASSY I -19-5/8" X 5-1/2" BKR SAB PKR, 10 - 4.892" -15-1/2" X 4-1/2" XO I -13.7" BKR DEA..OYMENT SLV, 10 = 3.0" -13-1/2" HES X NIP, ID - 2.813" , -13-1/2" X 3-3/16" XO, 10 = 2.786" I -14-1/2" OTIS X NIP, 10 = 3.813" (BEHIND CT LNR) I -14-1/2" OTIS XN NIP, 10 = 3.80" (BEHIND CT LNR) I -14-1/2 BKR SOS TBG TAIL (BEHIND CT LNR) I 1-1 ELMO TT LOGGED 04/02/83 (BEHIND CT LNR) -1 TOP OF CEMENT I 15-1/2" TBG, 17#. L-80 1J4S, .0232 bpf, 10 = 4.892" I 8405' 13-1/2" TBG, 9.3#, L-80, .0087 bpf, 10 = 2.992" I 8461' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9-5/8" CSG, 47#, L-80, 10 = 8.681 MILLOUT WINDOW 9370' - 9375' 17" LNR, 29#, L-80 1J4S, .0371 bpf, ID = 6.184" 9814' -13-3/16" X 2-7/8" XO, 10 = 2.440" I PERFORA TION SUMMARY REF LOG: MCNUCCUGR ON 09/04/03 ANGLE AT TOP PERF: 96 @ 9700" Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9700 - 9750 0 06/01/06 2" 6 9865 - 9890 0 02124/05 2" 4 10950 - 11185 0 09/05/03 2" 4 10570 - 10700 0 09/05/03 2" 6 10295 - 10320 0 02/24/05 2" 6 10210 - 10235 0 02/24/05 3-3/16" LNR, 6.2#, L-80, .0076 bpf, 10 = 2.805" I PBTD I 12-7/8" LNR, 6.16#, L-80, .0058 bpf, 10= 2.441" I DATE 04/15/82 09/06/03 09/14/03 09/23/03 03/02/05 04/23/05 REV BY COMMENTS ORIGINAL COM PLETION DAC/KK CTD SIDETRACK (F-15A) JCMlTLP GL V C/O RWL/KK GL V C/O SRBITLH ADPERF (02/24/05) RWL/TLH GLV C/O DA TE REV BY COMMENTS 05/07/06 DAV/PA GLV C/O (05/03/06) 06/01/06 GLMlPAG ADPERF PRUDHOE BA Y UNIT WELL: F-15A PERMIT No: "'2031370 API No: 50-029-20651-01 SEC 2, T11N, R13E, 3284' SNL & 2201' WEL BP Exploration (Alaska) e e WELL LOG TRANSMITTAL J,O?;--/37 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 jS&,4-\ RE: MWD Formation Evaluation Logs F-15A, 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 F-15A: LAS Data & Digital Log Images: 50-029-20651-01 1 CD Rom ~ Ji ~lì& Coöj¡' DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031370 Well Name/No. PRUDHOE BAY UNIT F-15A Operator BP EXPLORATION (ALASKA) INC s,~ ~'A..,~ API No. 50-029-20651-01-00 MD 11226 ....... TVD 9050"" Completion Date 9/6/2003"" Completion Status 1-01L Current Status 1-01L UIC N -----_.._~_._-_.- -_.~ REQUIRED INFORMATION Mud Log No Samples No Directional surve~ ~ ~--,----- DATA INFORMATION Types Electric or Other Logs Run: GR, EWR, MGR, CCL, CNL Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Data Type I ¡Ø ~g Electr Digital Dataset Med/Frmt Number Name Log Log Scale Media Run No Interval Start Stop OH/ CH . Received Comments. C ~L.U 12223 Neutron Name Interval Start Stop 8167 11188 Case 10/31/2003 LDWG edit of 2-pass Memory GR/CCL/CNL 2 Blu 8167 11188 Case 1 0/31/2003 Compensated Neutron Log - Memory GR/CCL/CNL 2 Blu 8167 11188 Case 10/31/2003 Compensated Neutron Log - Memory GR/CCL/CNL 8167 11188 Case 1 0/31/2003 LDWG edit of 2-pass Memory GR/CCL/CNL 9300 11226 9/24/2003 rr¡;~ 9300 11226 9/24/2003 . 9085 11173 Open 12/8/2003 9085 11173 Open 12/8/2003 9085 11173 Open 12/8/2003 9085 11173 Open 12/8/2003 Sample Set Sent Received Number Comments Neutron ~g ¿c ~ a.." 12223 Casing collar locator Casing collar locator ~ D ~ ~,(, Las Directional Survey Directional Survey I nd uction/Resistivity Induction/Resistivity 12298 Rate of Penetration Rpt ~D D !-Ro ett.., "/E D D 12298 Las RfiP(,..) Well Cores./Samples. Information: Rate of Penetration Permit to Drill 2031370 MD 11226 TVD 9050 ADDITIONAL INFORMATION Y~ Well Cored? Chips Received? "'VI N ' ~ Analysis Received? ----- Comments: -,._---~,-- ~---~ Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Well Name/No. PRUDHOE BAY UNIT F-15A Operator BP EXPLORATION (ALASKA) INC Completion Date 9/6/2003 Completion Status 1-01L Current Status 1-01L Daily History Received? &/N ~/N Formation Tops iá-o Date: API No. 50-029-20651-01-00 UIC N ~ })1-~ -~r- . . RE: F-15A (PTD #2031370) Classified as Problem Well . . . Subject: RE: F-15A(PTD #?031370)glassifi~d as Probl~m Well , .. . From: "NSU. ADWWell I:rït¢grity Engineer"<NSUADWWellIntegrityEngineer@BP';com> Date: Mon, 18 Apr'2005 09:02:15 -0800' ~~?~:~§n:~~;: ~7:~;:i:~ba~:'~::;·· t~alC ,," Winton - thank you for catching my typo. On that day it was 320 psi. V Thanks, Anna From: Winton Aubert [mailto:winton_aubert@admin.state.ak.us] Sent: Monday, April 18, 20058:55 AM To: NSU, ADW Well Integrity Engineer Cc: James B Regg Subject: Re: F-15A (PTD #2031370) Classified as Problem Well Anna, Is the F-15A OA pressure 3200 psi? Thanks, Winton Aubert 793-1231 NSU, ADW Well Integrity Engineer wrote: All, Well F-15A (PTD #2031370) has been found to have sustained casing pressure on the IA. The'TIO's on 04/13/05 were 2360/2140/3200. A subsequent TIFL failed due to IA re-pressurization. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. WIE: Evaluate changing out GLVs 3. SL: c/o GL Vs 4. DHD: Re- TIFL A wellbore schematic has been included for reference. «F-15A.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, flnna q)u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 1 of 1 4/18/2005 2:31 PM TREE = WELLHEAD = A.. , ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = ~A~_ "'~~,,~ DatumTVD= . 6" crw OTIS 71.31' 37.1' 97 @ 9671' _.. ~, ~,~ ,~,~.~,,,^~~~U 9327' ""'~""'","^ -~ 8800' SS 113-3/8" CSG. 72#, L-80, 10 = 12.347" H 2680' Minimum ID = 2.372" @ 9648' TOP OF 2-7/8" LINER 15-1/2" TBG, 17#, L-80 1J4S, .0232 bpf, 10 = 4.892" H 8405' 13-1/2" TBG, 9.3#, L-80. .0087 bpf, 10 = 2.992" ---j 8461' , 4-112" TBG, 12.6#, L-80. .0152 bpf, 10 = 3.958" H 8549' 19-5/8" CSG, 47#, L-80, ID = 8.681 H 8956' I TOP OF WHIPSTOCK H 9366' 17" LNR, 29#, L-80 1J4S, .0371 bpf. 10 = 6.184" ---j 9814' ÆRFORA TION SUMMARY REF LOG: MCNUCCLlGR ON 09/04/03 ANGLE AT TOP PERF: 95 @ 9865" Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 2" 6 9865 - 9890 0 02/24/05 2" 6 10210 - 10235 0 02/24/05 2" 6 10295 - 10320 0 02/24/05 2" 4 10570 - 10700 0 09/05/03 2" 4 10950 - 11185 0 09/05/03 DATE 04/15/82 09/06/03 09/14/03 09/23/03 03/02/05 REV BY COMMENTS ORIGINAL COMPLETION DAC/KK crD SIDETRACK (F-15A) JCMlTLP GL V C/O RWLlKK GL V C/O SRB/TLH ADÆRF (02/24/05) DATE F-15A ~OTES: IAxOACOMM. . 2093' H 5-1/2" OTIS SSSV LAND NIP, 10 = 4.562" 1 GAS LIFT MANDRELS ST MD TVD OEV TYÆ VLV LATCH PORT DATE . 12 3013 2941 4 CAMCO DOME RK 16 09/23/03 11 4964 4780 24 CAMCO OMY RK 0 09/23/03 10 6072 5779 27 CAMCO DMY RK 0 9 6213 5904 27 CAMCO DOME RK 16 09/23/03 L 8 6786 6418 26 CAMCO OMY RK 0 7 6933 6551 26 CAMCO OMY RK 0 6 7313 6899 23 CAMCO DMY RK 0 5 7456 7030 22 CAMeO DMY RK 0 4 7794 7345 20 CAMeO DMY RK 0 3 7938 7481 20 CAMCO OMY RK 0 2 8120 7652 20 CAMCO RKED RK 0 1 8266 7790 20 CAMCO SO RK 24 09/23/03 A I I I J G þ--I ~ ~ 1 I I , ~ I I 8325' 8383' 8405' 8405' 8441' 8460' 8461' 8462' 8505' 8549' 8503' 9150' I' . 13-3/16" LNR, 6.2#, L-80, 1-1 .0076 bpf. 10 = 2.805" H OTIS XA SLIDING SLEEVE, 10 = 4.562" ---j BAKER SBR TBG SEAL ASSY I ---j9-5/8" X 5-1/2" BKR SAB PKR, ID = 4.892" H5-1/2" X 4-1/2" XO I 1-13.7" BKR DEPLOYMENT SLV, 10=3.0" ---j3-1/2" HESX NIP, 10= 2.813" I H 3-1/2" X 3-3/16" XO, ID = 2.786" I H4-1/2" OTIS X NIP, ID = 3.813" (BEHIND CT LNR) I H4-1/2" OTIS XN NIP, 10 = 3.80" (BEHIND CT LNR) I ---j4-1/2 BKR SOS TBG TAIL (BEHIND CT LNR) I ---j ELMD IT LOGGED 04/02/83 (BEHIND CT LNR) ---j TOP OF CEI\i1ENT I MILLOUT WINDOW 9370' - 9375' H3-3/16" X 2-7/8" XO, ID = 2.440" I I PBTD H 11192' 2-7/8"LNR,6.16#,L-80,.0058bPf,ID=2.441" ---j 11226' REV BY COMMENTS PRUDHOE BAY UNIT WELL: F-15A PERMIT No: 2031370 API No: 50-029-20651-01 SEe 2, T11 N, R13E, 3284' SNL & 2201' WEL BP Exploration (Alaska) . ð03~J3T . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3 33 West 7th Avenue, Suite 100 Anchorage, Alaska December 02, 2003 RE: MWD Formation Evaluation Logs F-15A, AK-MW -2633660 1 LDWG formatted Disc with verification listing. } () d 9' c¡{ llPI#: 50-029-20651-01 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-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED Signed~ð \.~. jY'..~ ,-C ~~ DEC 082003 Alaska 00 & Gas Cons. Commiteion Anchømge ~~~\\\.{'~ 10/30/03 Sc~IußIÞel'gep NO. 3015 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Av'e-; Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color . Well Job# Log Description Date Blueline Prints CD F-1SA i"'-\?>; 10558572 MCNL 09/04/03 1 1 )~æ~ K"SAQ."', ~ I Y . > 10669977 MCNL 09/12/03 1 1 Jßk'9f}. A-23 \ ( -('J(q. 10687642 RST-SIGMA 09/07/03 1 1 !f~ - H-35 ). -I :1J 10563219 RST-SIGMA 09/29/03 1 1 02-25 . ~ '-09 ( 10563169 RST-SIGMA 06/07/03 1 1 ¡~~ 01-34 1(0 - \ q 10563167 RST-SIGMA 06/05/03 1 1 :~~:~:)Ð03~ }~ 10672316 CH EDIT SCMT 09/24/03 1 lft-)n 10672316 SCMT 09/24/03 2 MPS-14)803-11"ì'i 10559813 CH EDIT SCMT 07/19/03 1 j ri()lJ.. MPS-14 10559813 SCMT 07/19/03 2 ~ / PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 f~.E CE' VED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Date Delivered: OCT ~~ :. 2.003 Received b~~~~~ .;'D<l.; ~.r-/v'"\. G.oHlmisston /\n¡)hon~ge ~~~\'\\~ _ STATE OF ALASKA _~ ALAS~L AND GAS CONSERVATION COM.,sION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20MC 25.105 20MC 25.110 o GINJ 0 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: 3284' SNL, 2201' WEL, SEC. 02, T11N, R13E, UM Top of Productive Horizon: 4890' SNL, 4011' WEL, SEC. 02, T11 N, R13E, UM Total Depth: 4978' SNL, 5236' WEL, SEC. 02, T11 N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 652649 y- 5973529 Zone- ASP4 TPI: x- 650874 y- 5971887 Zone- ASP4 Total Depth: x- 649651 y- 5971774 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: GR, EWR, MGR, CCL, CNL One Other 5. Date Comp., Susp., or Aband. 9/6/2003 6. Date Spudded 8/29/2003 7. Date T.D. Reached 9/2/2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 71.3' 9. Plug Back Depth (MD+ TVD) 11192 + 9049 Ft 10. Total Depth (MD+TVD) 11226 + 9050 Ft 11. Depth where SSSV set (Nipple) 2093' MD 19. Water depth, if offshore N/A MSL 22. CASING SIZE 20" X 30" 13-3/8" 9-5/8" 7" WT. Insulated 72# 47#' 26# 9.3# /62# /6.16# GRÄDE Conductor L-80 L-80 L-80 L-80 CASING, liNER AND CEMENTING RECORD Smff,/I:;[)EPTH Top BOTTOM Surface 110' Surface 2674' Surface 8956' 8464' 9370' 8441 ' 11226' 23. Perforations oRen to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): 2" Gun Diameter, 4 spf MD TVD MD TVD 10570' - 10700' 9055' - 9052' 10950' - 11185' 9055' - 9048' 26. Date First Production: September 16, 2003 Date of Test Hours Tested 9/17/2003 2.5 Flow Tubing Casing Pressure Press. 222 PRODUCTION FOR TEST PERIOD ... CALCULATED ..... 24-HoUR RATE7 Oll-Bsl 36" 17-1/2" 12-1/4" 8-1/2" 3-3/4" 1 b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-137 13. API Number 50- 029-20651-01-00 14. Well Number F-15A 15. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 16. Lease Designation and Serial No. ADL 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 8 cu yds Concrete 3720 cu ft Permafrost II 1202 cu ft Class 'G', 130 cu ft PF 'C' 360 cu ft Class 'G' 124 cu ft Class 'G' 24. SIZE 5-112", 17#, L-80 4-1/2", 12.6#, L-80 25. . 3-1/2" x 3-3/16" x 2-7/8" PACKER SET (MD) 8405' DEPTH SET (MD) 8405' 8405' - 8549' CEMENT SQUEEZE, AMOUNT & KIND OF MATERIAL USED Freeze Protected with MeOH CHOKE SIZE I GAS-Oil RATIO 1760 11,355 Oil GRAVITY-API (CORR) 25.9 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-Bsl 509 ! t None :-r4'~'. . ! /'~. -.(2_ --, f VE' on;;:;; \ ~ "~.:."~ ¡ ,~, ¡.,,---.. ~----~ DEPTH INTERVAL (MD) 2200' GAs-McF 5,781 GAs-McF WATER-Bsl 234 WATER-Bsl Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SID~ f ~ 8frL SEPt ~ ORIGINAL NAME MD TVD 129. _ORMATION TESTS Include and briefly šummarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 28. GEOLOGIC MARKER 25N 9424' 8964' None 25P 9450' 8988' 21N 9598' 9085' 21P 9614' 9089' 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 ~~ (L~ Title Technical Assistant Date oq·~L{·03 F-15A 203-137 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Mary Endacott, 564-4388 Permit No. I 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-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". ()RIGINAL Form 10-407 Revised 2/2003 ...,. - BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/27/2003 8/28/2003 Rig released from 15-28A @ 14:30Hrs on 8/27/2003. Prep to move rig off well. PJSM. Pull rig off well & set down. Clean up location & conduct post operations pad inspection. PJSM. UD windwalls. Install derrick rams. Scope down & UD derrick. Jack-up rig & prep for move. Held pre-move safety meeting with crew, security, tool services &CPS. Moving rig from 15-28A to F-pad. Move rig from DS#15 to F-15. Conduct pre-operations pad inspection with DSO. SAFETY MEETING. Review procedure, hazards and mitigation for positioning rig in front of well. Position rig in front of well. SAFETY MEETING. Review procedure, hazards and mitigation for raising mast and windwalls. Raise mast and windwalls. Secure guy wires. Hang BOP stack on blocks, install dikes around tree. SAFETY MEETING. Review procedure, hazards and mitigation for backing rig over well. Back rig over well. ACCEPT RIG ON F-15AAT 1330 HRS, 08/28/03. R/U. SAFETY MEETING. Review procedure, hazards and mitigation for N/U BOPE. Nipple up BOPE. Spot tank and trailers, M/U hard line. Pick up injecter head and M/U guide arch. Stab CT into injecter head. R/U & PJSM for BOPE testing. Perform initial BOPE pressure/function test. AOGCC test witnessed by Chuck Scheve. Meanwhile fill rig pits with 2% KCL bio-water. R/U & PIT hardline to flowback tank. Bleed off 250psi between lateral valve & blinded wing valve & confirm lateral valve holding OK. Open up well & observe Opsi WHP, 305psi lAP & 105psi OAP. Held pre-operations safety meeting. Reviewed well plan, potential hazards & milling BHA M/U procedures. Cut coil & install Baker CTC. Pull test to 35k. Circulate & fill coil. PIT CTC & inner reel valve to 3500 psi. M/U window milling BHA #1 with a 3.80" HC DSM, diamond string reamer, Baker straight Xtreme motor, MHA & 2 jts of PH6 tbg. M/U injector. RIH with BHA #1 choking FP fluid & gassy returns to the tiger tank. Wt check @ 9300': Up = 39k, down = 25k. Continue RIH BHA#1 & tag TOC @ 9307'. P/U & retag @ same depth. Mill cement with 2.8bpm/1500psi & hit hard spot @ 9315'- suspect we're @ TOWS or WS/Lnr pinch pt. Note that ELMD is 46' shallower than DD. Flag pipe & correct depth to 9369.6' (pinch pt ELMD), [added 55 ft CTD]. (8 ft of cement milled at 9369.6' CTD). WEXIT Mill from 9369.6' with 2.4/2.4bpm, 1250/1500psi, <1k WOB & F-15 F-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Task Code NPT: Phase 14:30 - 15:00 0.50 MOB P PRE 15:00 - 16:00 1.00 MOB P PRE 16:00 - 19:00 3.00 MOB P PRE 19:00 - 20:00 1.00 MOB P PRE 20:00 - 20:45 0.75 MOB P PRE 20:45 - 00:00 3.25 MOB P PRE 00:00 - 05:30 5.50 MOB P PRE 05:30 - 06:30 1.00 MOB P PRE 06:30 - 06:45 0.25 MOB P PRE 06:45 - 07:30 0.75 MOB P PRE 07:30 - 07:45 0.25 MOB P PRE 07:45 - 11 :30 3.75 MOB P PRE 11 :30 - 13:00 1.50 MOB P PRE 13:00 -13:15 0.25 MOB P PRE 13:15 -13:30 0.25 MOB P PRE 13:30 - 14:00 0.50 RIGU P PRE 14:00 - 14:15 0.25 BOPSURP PRE 14:15 - 16:00 1.75 BOPSURP PRE 16:00 - 17:30 1.50 RIGU P PRE 17:30 - 18:00 0.50 BOPSUR P PRE 18:00 - 23:00 5.00 BOPSUR P PRE 23:00 - 23: 15 0.25 STWHIP P WEXIT 23: 15 - 00:00 0.75 STWHIP P WEXIT 8/29/2003 00:00 - 00:45 0.75 STWHIP P WEXIT 00:45 - 01 :30 0.75 STWHIP P WEXIT 01 :30 - 03:30 2.00 STWHIP P WEXIT 03:30 - 04:30 1.00 STWHIP P WEXIT 04:30 - 05:20 0.83 STWHIP P Pag~ 1 of 9 Start: Rig Release: Rig Number: Spud Date: 12/28/1981 End: 9/9/2003 8/28/2003 9/6/2003 N1 Description of Operations -------------------.... Printed: 9/812003 8:49:11 AM ... - BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-15 F-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Page 2 of9 Start: Rig Release: Rig Number: Phase 8/28/2003 9/6/2003 N1 Spud Date: 12/28/1981 End: 9/9/2003 WEXIT 4fph aye ROP. Mill to 9373.2 & stall2x. P/U clean @ 39k & ease back into milling. [11 ft cement milled]. WEXIT Mill to 9385' with 2.5/2.5bpm, 1250/1670psi, 1k WOB & 18fph ave ROP. Getting cement over the shakers. Meanwhile bleed down lAP from 1000psi to 100psi. [23 ft cement milled]. WEXIT Mill to 9400 ft with 2.5/2.5 bpm, 1600-2000 psi, 5K WOB, 18 fph. Cement over shaker still, Milled total of 36 ft of cement to this depth. Taking samples at shaker, still getting cement. WEXIT Milling, stall at 9414 ft. Stall at 9421 ft. Stall at 9424 ft. Mill to 9427 ft. [total of 63 ft cement milled, should have had 43 ft of cement above pinch point based on PE CMT report]. No metal on ditch magnets. Geologist inspected cuttings and saw 20% fractured dense chirt and 80% cement, indicating mill has exited 7" liner. WEXIT Ream milled section with 3.80" mill and 3.80" string reamer. Had motor work at 9373 ft each time. Possible liner exit depth. Ream up and down twice, in case window was milled. Stop pump and RIH to 9427 ft with no weight loss. Clean window. POH to run SWS GRlDirectional/CCL log to determine depth and location. Layout milling BHA. Mill had wear across the face. Position SWS unit. SAFETY MEETING. Review procedure, hazards and mitigation for RlU and run SWS logging tools. M/U SWS GR / CCI/ Directional logging tools. RIH. Log down and up tie-in passes. Correct TD = 9,430 ft. RA tag at 9376 ft. Top of whipstock at 9366 ft. Top of window at 9370 ft. Bottom of window at 9375 ft. RID SWS E-Line unit and tools. Cut off BKR CTC. M/U SWS CTC. Pull / press test. SAFETY MEETING. Review procedure, hazards and mitigation for MWD BHA M/U. M/U MWD BHA #2 with Sperry MWD and 2.57 deg, short radius motor and used Bit #2, HYC, 3.75-4.25" bi-center Bit #2. RIH BHA#2. SHT MWD @ 1050' & orienter 5250' - OK. Continue RIH thru window with pumps down & tag btm @ 9449'. Correct CTD to 9430'. PUH @ 41 k to 9410' for tie-in log. Log GR RA Pip tag @ 9374.5'. Add 1.5' to CTD. PUH to 9170'. Attempt to log in 7" & tie-into Gelogy PDC log - not getting good MWD detection due to KCL fluid in hole. RBIH to drill & swap mud. Will relog on next wiper trip. Fix hardline leak in reel house. Orient & drill to 9450' with 5R TF, 2.6/2.6bpm, 2900/3340psi, 23fph ave ROP. Meanwhile swap well to conditioned flo-pro mud. Orient & drill to 9489' with 10-15R TF, 2.6/2.6bpm, 3150/3300psi, 25fph ave ROP. Orient & drill to 9505' with 15R TF, 2.7/2.7bpm, 3150/3300psi, 16fph ave ROP. Getting 26degs ave DLS. Decide to POOH for a bigger bend motor. POOH with drilling BHA #2. OOH. SIB injector. Check BHA. Bit grades 2/4/1. C/O bit to new HYC DS100 bicenter bit. Reset SR motor bend to 3degs & Date I Task Code I NPT J From - To Hours -----.. 8/29/2003 04:30 - 05:20 0.83 STWHIP P 05:20 - 06:00 0.67 STWHIP P 06:00 - 07:00 1.00 STWHIP P 07:00 - 09:30 2.50 STWHIP P 09:30 - 10:45 1.25 STWHIP P 10:45 - 12:30 1.75 STWHIP P WEXIT 12:30 -13:00 0.50 STWHIP P WEXIT 13:00 - 13:15 0.25 STWHIP N DPRB WEXIT 13:15 -16:00 2.75 STWHIP N DPRB WEXIT 16:00 - 16:30 0.50 STWHIP N DPRB WEXIT 16:30 - 17:00 0.50 DRILL P PROD1 17:00 - 17:15 0.25 DRILL P PROD1 17:15 - 18:15 1.00 DRILL P PROD1 18:15 - 20:05 1.83 DRILL P PROD1 20:05 - 21 :15 1.17 DRILL P PROD1 21 :15 - 21 :30 0.25 DRILL N SFAL PROD1 21 :30 - 22:30 1.00 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P PROD1 8/30/2003 00:00 - 01 :00 1.00 DRILL P PROD1 01 :00 - 02:30 1.50 DRILL P PROD1 02:30 - 03:30 1.00 DRILL P PROD1 Description of Operations ........---...---. .. ----------- .. Printed: 9/8/2003 8:49: 11 AM ,.,. - BP EXPLORATION Operªtions Summary Report Page 30f 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-15 F-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/28/2003 Rig Release: 9/6/2003 Rig Number: N1 Spud Date: 12/28/1981 End: 9/9/2003 Date From - To Hours Task ¡Code NPT Phase Description of Operations , 8/30/2003 02:30 - 03:30 1.00 DRILL P PROD1 scribe tools. M/U injector. 03:30 - 05:00 1.50 DRILL P PROD1 RIH with drilling BHA #3 to 9170'. 05:00 - 05:30 0.50 DRILL P PROD1 Log GR in 7" & tie-into Gelogy PDC log. Subtract 10' from CTD. 05:30 - 05:40 0.17 DRILL P PROD1 RIH thru window with pumps down to 9410'. 05:40 - 06:00 0.33 DRILL P PROD1 Log GR & see RA tag @ 9374'. Added 2' to CTD. 06:00 - 06:45 0.75 DRILL P PROD1 Orient TF around to 20R. 06:45 - 08:25 1.67 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3100-3800 psi, 25R, 80-120FPH,64 deg incl, Drilled to 9600'. 08:25 - 10:00 1.58 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3100-3800 psi, 35R, 80-120FPH, deg incl, Drilled to 9660 ft. Well landed at 9635 ft at 10:00 -11:45 1.75 DRILL P PROD1 POH for lateral BHA. 11 :45 - 13:20 1.58 DRILL P PROD1 C/O Bit, motor, MWD probes and add Sperry Resistivity tool. Test resistivity tool at surface. 13:20 -15:15 1.92 DRILL P PROD1 RIH with 1.04 deg motor and new 3.75" Bit #4, HYC, DS49. Tag TD at 9678' and correct to 9660 ft. [-17 ft). 15:15 -16:30 1.25 DRILL P PROD1 Log MAD pass up from TD to window with Res / GR logging tool. 200 FPH logging rate. 2.5/2.5 bpm, 3050 psi. 16:30 - 18:30 2.00 DRILL P PROD1 Orient TF. Unable to get clicks on bottom. Pull to window to orient. Getting 10 deg clicks. RBIH to btm. 18:30 - 19:55 1.42 DRILL P PROD1 Orient & drill to 9739' with 90-105R TF, 2.7/2.7bpm, 3150/3550psi, 60fph ave ROP. Got out of the 21 N shale @ 1 0700'. 19:55 - 20:25 0.50 DRILL P PROD1 Orient TF around to 75R. 20:25 - 21 :30 1.08 DRILL P PROD1 Drill to 9840' with 75-95R TF, 2.7/2.7bpm, 3150/3550psi, 120fph aye ROP. 21 :30 - 22:00 0.50 DRILL P PROD1 Wiper trip clean to window. RBIH to btm. 22:00 - 22:30 0.50 DRILL P PROD1 Orient TF around to 60R. 22:30 - 22:45 0.25 DRILL P PROD1 Drill to 9860' with 55R TF, 2.7/2.7bpm, 3150/3450psi, 80fph ave ROP. 22:45 - 23:30 0.75 DRILL P PROD1 Orient & drill to 9900' with 90R TF, 2.7/2.7bpm, 3150/3500psi, 60fph ave ROP. 23:30 - 23:45 0.25 DRILL P PROD1 Orient TF to 120L. 23:45 - 00:00 0.25 DRILL P PROD1 Drill to 9910' with 115L TF, 2.7/2.7bpm, 3150/3550psi, 50fph ave ROP. 8/31/2003 00:00 - 00:20 0.33 DRILL P PROD1 Orient & drill to 9930' with 115L TF, 2.7/2.7bpm, 3200/3550psi, 60fph ave ROP. 00:20 - 00:25 0.08 DRILL P PROD1 Orient TF to 90L. 00:25 - 00:45 0.33 DRILL P PROD1 Drill to 9952' with 90L TF, 2.7/2.7bpm, 3200/3350psi, 70fph ave ROP. 00:45 - 01 :30 0.75 DRILL P PROD1 Orient & drill to 10000' with 70L TF, 2.7/2.7bpm, 3200/3550psi, 65fph ave ROP. 01 :30 - 01 :50 0.33 DRILL P PROD1 Wiper trip clean to window. 01 :50 - 02:05 0.25 DRILL P PROD1 Log GR & tie-into RA PIP tag. Subtract 4' from CTD. 02:05 - 02:25 0.33 DRILL P PROD1 RBIH to btm. 02:25 - 03:20 0.92 DRILL P PROD1 Orient TF to 90L. 03:20 - 04:30 1.17 DRILL P PROD1 Orient & drill to 10060' with 90-115L TF, 2.7/2.7bpm, 3200/3500psi, 60fph ave ROP. 04:30 - 05:00 0.50 DRILL P PROD1 Orient & drill to 10097' with 75L TF, 2.7/2.7bpm, 3200/3500psi, 75fph ave ROP. 05:00 - 05:20 0.33 DRILL P PROD1 Orient & drill to 10108' with 35L TF, 2.7/2.7bpm, 3200/3500psi, 35fph ave ROP. Wt staking. Printed: 9/8/2003 8:49: 11 AM ..... . . BP EXPLORATION Operations Summary Report Page 4 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-15 F-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/28/2003 Rig Release: 9/6/2003 Rig Number: N1 Spud Date: 12/28/1981 End: 9/9/2003 Date From - To Hours Task Code NPT Phase Description of Operations -----.-- .. 8/31/2003 05:20 - 05:25 0.08 DRILL P PROD1 Short 100' wiper. 05:25 - 05:40 0.25 DRILL P PROD1 Orient & drill to 10118' with 30L TF, 2.7/2.7bpm, 3200/3500psi, 40fph ave ROP. Pump up oft btm survey. 05:40 - 06:00 0.33 DRILL P PROD1 Orient & drill to 10140' with 20L TF, 2.7/2.7bpm, 3200/3500psi, 60fph ave ROP. 06:00 - 06:45 0.75 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 06:45 - 07:30 0.75 DRILL P PROD1 Orient TF to 65L, getting 10 deg clicks. 07:30 - 08:00 0.50 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3100 - 3600 psi, 65L, 94 deg Incl, Drilled to 10200'. 08:00 - 08:45 0.75 DRILL P PROD1 Orient TF to 11 OL 08:45 - 10:00 1.25 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3100 - 3600 psi, 110L, 92 deg Incl, Drilled to 10275'. 10:00 - 10:30 0.50 DRILL P PROD1 Orient TF to 11 OR 10:30-11:10 0.67 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3100 - 3600 psi, 110L, 92 deg Incl, Drilled to 10300'. 11:10 -12:15 1.08 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 12:15 - 12:45 0.50 DRILL P PROD1 Orient TF, very slow, getting 10 deg clicks. 12:45 -12:50 0.08 DRILL P PROD1 Drilled 4 ft, to 10,304 ft and had the wrong TF. Stacking weight Need to POH. 12:50 - 14:45 1.92 DRILL P PROD1 POH. 14:45 - 15:00 0.25 DRILL P PROD1 SAFETY MEETING. Review procedue, hazards and mitigation to C/O MWD BHA. 15:00 - 16:45 1.75 DRILL P PROD1 C/O bit, motor and orienter. Bit was ringed from drilling chert [6,8,1/8]. M/U 1.04 deg motor and new DSX49 Hycalog bit Down load Resistivity memory data. 16:45 - 18:45 2.00 DRILL P PROD1 RIH with MWD BHA #5 with 1.04 deg motor, DSX49 bit#5 and Resistivity / GR Shallow test tools. RIH clean thru window. 18:45 - 19:35 0.83 DRILL P PROD1 Log GR & did not see PIP tag. Relog tie-in. Subtract 22.5' from CTD. 19:35 - 20:05 0.50 DRILL P PROD1 RBIH & set down @ 10035'. P/U & O/pull- suspect undergauged hole. 20:05 - 20: 15 0.17 DRILL P PROD1 Orient TF to 100L 20: 15 - 20:30 0.25 DRILL P PROD1 Ream undergauge hole section from 10033' to 10301' with 70L TF, 2.7/2.7bpm, 3200/3270psi, 100fph ave ROP. 20:30 - 20:40 0.17 DRILL P PROD1 Drill to 10320' with 40R TF, 2.7/2.7bpm, 3200/3400psi, 95fph ave ROP. 20:40 - 20:45 0.08 DRILL P PROD1 Orient TF to 90R 20:45-21:15 0.50 DRILL P PROD1 Drill to 10360' with 85R TF, 2.7/2.7bpm, 3250/3500psi, 80fph ave ROP. 21:15-21:25 0.17 DRILL P PROD1 Orient TF to 150R 21 :25 - 21 :40 0.25 DRILL P PROD1 Drill to 10380' with 125R TF, 2.7/2.7bpm, 3250/3500psi, 75fph ave ROP. 21 :40 - 22:05 0.42 DRILL P PROD1 Orient 1 click & drill to 10400' with 145L TF, 2.7/2.7bpm, 3300/3600psi, 50fph ave ROP. 22:05 - 22:10 0.08 DRILL P PROD1 Orient TF to 120L 22:10 - 22:30 0.33 DRILL P PROD1 Drill to 10415' with 120L TF, 2.7/2.7bpm, 3250/3500psi, 45fph ave ROP. 22:30 - 23:05 0.58 DRILL P PROD1 Orient 1 click & drill to 10450' with 80L TF, 2.7/2.7bpm, 3250/3650psi, 60fph ave ROP. Getting 180 degs reactive. 23:05 - 00:00 0.92 DRILL P PROD1 Wiper trip clean to window. RBIH to btm. 9/1/2003 00:00 - 00:15 0.25 DRILL P PROD1 Orient TF to 90L 00:15 - 00:50 0.58 DRILL P PROD1 Drill to 10470' with 90-120L TF, 2.7/2.7bpm, 3250/3400psi, 35fph ave ROP. TF flopping 180degs. Printed: 9/812003 8:49: 11 AM ..... . BP EXPLORATION Operations Summary Report Page 5 of 9 ,. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-15 F-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/28/2003 Rig Release: 9/6/2003 Rig Number: N1 Spud Date: 12/28/1981 End: 9/9/2003 Date From - To Hours Task Code NPT Phase Description of Operations 9/1/2003 00:50 - 01 :00 0.17 DRILL P PROD1 Drill to 10472' with 70L TF, 2.7/2.7bpm, 3250/3500psi, 15fph ave ROP. TF flopping 180degs - seems like in a possible fault zone. 01:00-01:15 0.25 DRILL P PROD1 Orient TF to 70L. 01:15 - 01:45 0.50 DRILL P PROD1 Drill to 10504' with 70-90L TF, 2.7/2.7bpm, 3250/3400psi, 75fph ave ROP. Meanwhile swap well to fresh Flo-Pro mud. 01 :45 - 02:35 0.83 DRILL P PROD1 Orient & drill to 10575' with 50L TF, 2.7/2.7bpm, 3250/3400psi, 85fph ave ROP. Getting 9degs ave DLS since crossing fault zone from 10420' to 10530'. Will not achieve required LH turn with current DLS. Thus decide to POOH to increase motor bend. 02:35 - 04:35 2.00 DRILL P PROD1 POOH drilling BHA # 5. 04:35 - 05:30 0.92 DRILL P PROD1 OOH. SIB injector. PJSM. L/O BHA. Bit grades 3/4/1. C/O bit to new HYC DS49 bit. C/O orienter. Reset motor bend to 1.69degs & scribe tools. M/U injector. 05:30 - 08:00 2.50 DRILL P PROD1 RIH with drilling BHA #6 to 2200'. Shallow test BHA, OK. RIH. Tag TD at 10593 ft and corrected TD to 10,575' [-18 ft). 08:00 - 09:00 1.00 DRILL P PROD1 Orient TF to 80L. 09:00 - 09:40 0.67 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 2950 - 3500 psi, 65L, 91 deg Incl, 150 fph, Drilled to 10648 ft. 09:40 - 10:10 0.50 DRILL P PROD1 Orient TF. 10:10 -11:00 0.83 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 2950 - 3500 psi, 90L, 89 deg Incl, 120 fph, Drilled to 10750'. 11:00 -11:30 0.50 DRILL P PROD1 Wiper trip to window. Clean hole. 11:30-11:55 0.42 DRILL P PROD1 Log tie-in with RA tag at 9376', subtracted 6 ft CTD. 11 :55 - 12:30 0.58 DRILL P PROD1 RIH clean to TD. 12:30 -13:10 0.67 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 2950 - 3500 psi, 70L, 92 deg Incl, 100 fph, Drilled to 10800'. 13:10 -13:30 0.33 DRILL P PROD1 Orient TF. 13:30 - 15:50 2.33 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 2950 - 3500 psi, 80L, 89 deg Incl, 80 fph, Drilled to 10,950' 15:50 - 17:30 1.67 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 17:30 -18:10 0.67 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 2950 - 3500 psi, 60L, 91 deg Incl, 80 fph, Drilled to 11,037'. 18:10 - 18:35 0.42 DRILL P PROD1 Orient TF to 90R. 18:35 - 18:50 0.25 DRILL P PROD1 Drill to 11050' with 90R TF, 2.7/2.7bpm, 3100/3350psi, 50fph ave ROP. 18:50 - 19:20 0.50 DRILL P PROD1 Drill to 11083' with 110R TF, 2.7/2.7bpm, 3050/3250psi, 65fph ave ROP. 19:20 - 19:45 0.42 DRILL P PROD1 Drill to 11101' with 115R TF, 2.7/2.7bpm, 3050/3250psi, 45fph ave ROP. 19:45-21:10 1.42 DRILL P PROD1 Wiper trip clean to window. RBIH to btm. 21:10-21:35 0.42 DRILL P PROD1 Orient TF to 90R. 21 :35 - 22:20 0.75 DRILL P PROD1 Drill to 11140' with 90R TF, 2.7/2.7bpm, 3050/3300psi, 55fph ave ROP. 22:20 - 00:00 1.67 DRILL P PROD1 Drill & TD well @ 11220' with 120R TF, 2.7/2.7bpm, 3050/3300psi, 50fph ave ROP. 9/2/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Wiper trip clean to window. 01 :00 - 01 :20 0.33 DRILL P PROD1 Log GR & tie-into RA PIP tag. Subtract 10.5' from CTD. 01 :20 - 01 :55 0.58 DRILL P PROD1 RBIH to btm & tag TD @ 11212'. 01 :55 - 02:10 0.25 DRILL P PROD1 Drill rat hole to 11226' with 140R TF, 2.7/2.7bpm, 3000/3200psi, 85fph ave ROP. Tag & confirm TD @ 11226'. Printed: 9/812003 8:49:11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: I ~~_te _~om - To 9/2/2003 02:10 - 04:30 04:30 - 07:00 ..,. . BP,EXPLORA TION Operations Summary Report F-15 F-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Hours I Task I Code NPT I 07:00 - 07:30 07:30 - 08:00 08:00 - 10:00 10:00 - 11 :30 11:30 -11:50 11 :50 - 14:20 14:20 - 14:50 14:50 - 19:00 19:00 - 19:30 19:30 - 19:45 19:45 - 20:50 20:50 - 22:40 22:40 - 23:15 23:15 - 23:45 23:45 - 00:00 ........._-------.- 2.33 DRILL P 2.50 DRILL P 0.50 CASE P 0.50 CASE P 2.00 CASE P 1.50 CASE P 0.33 CASE P 2.50 CASE P 0.50 CASE P 4,17 CASE P 0.50 CASE P 0,25 CEMT P 1.08 CEMT P 1.83 CEMT N 0.58 CEMT N 0.50 FISH N 0.25 FISH N DPRB DPRB DPRB DPRB Page 6 of9 Start: Rig Release: Rig Number: Phase 8/28/2003 9/6/2003 N1 Spud Date: 12/28/1981 End: 9/9/2003 PROD1 PROD1 COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP Description of Operations POOH to run liner. Flag CT EOP flags @ 8400' & 6500'. OOH. SIB injector. PJSM. UO BHA. Bit grades 7-8-1/16" undergauge. Download resistivity data. Prepare rig floor to run 2-7/8" X 3-3/16" Liner. SAFETY MEETING. Review procedure, liner tally, hazards and mitigation for running liner. M/U 51 jts of 2-7/8", 6.16#, L-80, STL Liner with turbos and float equipment Fill liner. M/U TIW LSL Sub, M/U 10 jts, 3-3/16", 6.2#, L-80, TCII Liner with Turbos, 3.60" OD. M/U 28 Jts, 3-3/16", 6.2#, L-80, TCII Liner with out Turbos. M/U XO, X Nipple, BKR 3-1/2" Pups, And Baker 3.70" Deployment Sleeve. Total length of liner = 2768.7 ft. M/U BKR CT connecter. PIT CTC, Insert dart in coil and displace. Dart on seat at 60.4 bbls. RIH with Liner on CT. Stop at top flag at 9293' CTD, and correct depth to 9277'. [-16 ft]. RIH. Up wt. = 45K at 9400 ft. Dwn Wt = 29K. No wt loss thru window, RIH with liner clean and land liner at 11,228' BKB. Corrected TD is 11,226', 47K up wt. Insert 5/8" Dart and displace with FloPro, 2.6/2.6 bpm, 2610 psi, Flull returns. Slow pump at 42 bbls. Ball on seat @ 46.3bbls, Pressure up to 4050psi & release CTLRT. P/U @ 32k & confirm release. Displace well to 2% KCI at 2.7/2.6bpm & 2000psi. Meanwhile RIU Dowell cementers. Ship back used mud to ML PJSM for cement job. Identify hazards and discuss mitigations for individual tasks during cement job. Batch mix cement Pump 5 bbls of water. Pressure test cement lines to 4,000 psi. Pump 22 bbls 15.8 ppg class G latex cement at 2.17 bpm, 1,460 psi to 2,300 psi. Displace with 27 bbls of 2% KCI with 2 ppb biozan at 2.56 I 2.43 I 1,970 psi. Continue displacement with KCI 2.5 bpm, 1,500 psi. Pressure increased at 38.3 bbls into displacement (Cement just reaching liner wiper plug. CT volume is 60.4 bbls.) Pressure up to 4,100 psi. Shut down pump. Pressure dropped (liner wiper plug sheared ??). Continue displacement Pump an additional 18 bbls (liner volume is 18 bbls). Pressure spike. Liner wiper plug latched up in latch collar. Can not pump through liner. We currently have 18 bbls of cement inside the liner and 4 bbls of cement inside the CT. Discuss with Anchorage. Pressure up to 4,000 psi. No bleed off. Bleed off CT pressure to 200 psi. PU to unsting from deployment sleeve. Pressure dropped off and established circulation. Lay in 4 bbls of cement Circulate at 2.5 bpm pumping biozan and RIH to contaminate cement down to 2' above liner top. Stop at liner top and circulate. POH pumping at 3 bpm. LD CTLRT. Found CT wiper dart in collette of CTLRT. Remove CT connector and prepare coil for new connector. Wait on Baker fishing tools. Printed: 9/8/2003 8:49: 11 AM ~ - BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-15 F-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From ~ To ' Hours: Task Code NPT Phase 9/3/2003 00:00 - 00:30 0.50 FISH N DPRB COMP 00:30 - 01 :00 0.50 FISH N DPRB COMP 01 :00 - 01 :30 0.50 FISH N DPRB COMP 01 :30 - 02:35 1.08 FISH N DPRB COMP 02:35 - 02:45 0.17 FISH N DPRB COMP 02:45 - 04:45 04:45 - 05: 15 2.00 FISH 0.50 FISH N N DPRB COMP DPRB COMP 05:15 -10:00 4.75 FISH N DPRB COMP 10:00 - 10:45 0.75 CLEAN N DPRB COMP 10:45 - 11 :00 0.25 CLEAN N DPRB COMP 11 :00 - 12:00 1.00 CLEAN N DPRB COMP 12:00 - 12:45 0.75 CLEAN N DPRB COMP 12:45 - 14:45 2.00 CLEAN N DPRB COMP 14:45-15:10 0.42 CLEAN N DPRB COMP 15:10 - 15:20 0.17 CLEAN N DPRB COMP 15:20 - 16:45 1.42 CLEAN N DPRB COMP 16:45 - 19:20 2.58 CLEAN N DPRB COMP 19:20 - 20:00 0.67 CLEAN N DPRB COMP 20:00 - 22:00 2.00 CASE N DPRB COMP 22:00 - 22:20 0.33 CASE N DPRB COMP 22:20 - 00:00 1.67 CASE N DPRB COMP 9/4/2003 00:00 - 01 :45 1.75 CASE N DPRB COMP 01:45 - 02:20 0.58 CASE N DPRB COMP 02:20 - 04:00 1.67 CASE N DPRB COMP 04:00 - 04:45 0.75 CASE N DPRB COMP 04:45 - 07:45 3.00 CASE N DPRB COMP 07:45 - 08:00 0.25 CEMT N DPRB COMP 08:00 - 09:40 1.67 CEMT N DPRB COMP Page 7 of 9 Start: Rig Release: Rig Number: Spud Date: 12/28/1981 End: 9/9/2003 8/28/2003 9/6/2003 N1 Description of Operations Wait on Baker fishing tools. Install CT connector. Pull and pressure test same. Fill hole, took 15 bbls to fill. MU hydraulic GS spear, circ sub, hydraulic disconnect, Jar, check valves, CTC. RIH to top of liner. Pump at 0.6 bpm and sting into deployment sleeve. Shut down pump. Pick up. Did not latch fish. Set down w/o pump. Pick up and did not latch fish. Set down 10K. Pump at 3.6 bpm, 2,750 psi and wash out fishing profile. Shut down pump. PU and liner came free. POH with liner. PJSM on LD liner. Discuss hazards and mitigations. LD fishing BHA above spear. LD XO, X Nipple, BKR 3-1/2" Pups, Baker 3.70" Deployment Sleeve, 28 Jts, 3-3/16", 6.2#, L-80, TCII Liner with out Turbos, 10 jts, 3-3/16", 6.2#, L-80, TCII Liner with Turbos, TIW LSL Sub, 51 jts of 2-7/8",6.16#, L-80, STL Liner with turbos & float equip. Had hard cement inside liner except for last 2 jts which contains weUmarshy cement (probably cement-KCL interface). RID pipe handling tools & cleanout rig floor. Meanwhile tear down LWP & observe that LWP ID was plugged by some carbolite looking materials. Collect samples for lab analysis. PJSM for RIH cleanouUdrilling BHA. M/U cleanout BHA #8 with a used 3.75" HYC DS49 bit, BHI motor with 1.69deg bend, Sperry MGRlWD & orienter. Cut CT & install DS CTC. Pull test to 35k & pressure test to 3500psi. RIH with cleanout BHA #8 to 4000'. SHT. Continue RIH to 9300'. Subtract 18' (normal correction) from CTD. SID pump & run thru window to 9420'. Log GR & tie-into RA PIP tag. Subtract 3' from CTD. Orient TF to 20L. RIH & cleanout to TD tagged @ 11226'. Meanwhile swap the well to reconditioned Flo-Pro mud. POOH to run liner. Flag CT EOP flags @ 8400' & 6500'. LD cleanout BHA. Load pipe shed w/ liner. Drift and tally pipe. PJSM for running liner. Run 2 7/8" , 6.16#, L-80, STL liner. Continue running 2 7/8" x 3 3/16" liner. Run a total of 51 joints of 2 7/8", LSL sub, and 38 joints of 3 3/16". MU BOT CTLRT. Install Baker CTC. Pressure test to 3,500 psi, pull test to 35,000 Ibs. RIH with liner to 11,226'. Tag bottom. PU=38K, SO=12K at .5 bpm. Pump 5/8" ball at 2.15 / 2.15 bpm to release CTLRT. Liner released. PU=26 K. Displace well bore to 2% KCI at 3.15/3.15 bpm, 1,470 psi. Meanwhile RlU Dowell cementers. Ship back used mud to MI. PJSM with all personnel concerning cementing operations. Batch mix 22bbls 15.8ppg cmt with additives. Cmt to wt @ 08:40 hrs. Flush/PT lines to 4k. Pump 22bbls cmt slurry @ Printed: 9/8/2003 8:49: 11 AM .... . BP EXPLORATION Operations Summary Report Page 8 of 9 Legal Well Name: F-15 Common Well Name: F-15 Spud Date: 12/28/1981 Event Name: REENTER+COMPLETE Start: 8/28/2003 End: 9/9/2003 Contractor Name: NORDIC CALISTA Rig Release: 9/6/2003 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code I NPT Phase Description of Operations ....-----.. ! 9/4/2003 08:00 - 09:40 1.67 CEMT N DPRB COMP 2.6/2.5bpm & 1600psi. Zero MM-in. Close inner reel valve & clean lines. Load/launch CTWP. Chase with bio-KCL @ 2.7/2.7bpm & 1650psi. CTWP engage LWP at 60.3bbls away. Shear plug with 2100psi. Zero MM-in. Continue displacing LWP @ 2.3/2.2bpm, 900psi & bump @ 17.8bbls away. 19.6bbls cmt pumped around shoe. Floats held. Pressure up to 500psi & sting out of liner. CIP at 09:40hrs. 09:40 - 11 :00 1.33 CEMT P COMP POOH slowly pumping to replace voidage only. 11 :00 - 11 :45 0.75 CEMT P COMP OOH. SIB injector & UD CTLRT. 11 :45 - 12:00 0.25 EVAL P COMP PJSM on P/U & RIH CNL tools & 1-1/4" CHS tbg. 12:00 - 12:45 0.75 EVAL P COMP Initialize & test logging tools. 12:45 - 15:45 3.00 EVAL P COMP P/U logging BHA #10 with 2.2" nozzle, MCNUCCUGR logging tool carrier & 92jts of 1-1/4" CSH tbg. M/U injector. 15:30 - 16:45 1.25 EVAL P COMP RIH logging BHA#10 on CTto 8300'. 16:45 - 17:45 1.00 EVAL P COMP Log down @ 60fpm from 8300' to PBTD tagged @ 11215'. Meanwhile start pumping down 150kcps Flo-Pro perf pill. 17:45 - 18:30 0.75 EVAL P COMP Log up @ 60fpm from PBTD to 8300' while laying-in 150kcps perf pill in liner. 18:30 - 19:20 0.83 EVAL P COMP POOH logging BHA#10. 19:20 - 19:45 0.42 EVAL P COMP Stand back injector. Prepare to LD 1 1/4" CSH. 19:45 - 21:45 2.00 EVAL P COMP LD 19 joints of 1 1/4" CSH. Rack back 38 stands of CSH. 21:45 - 22:15 0.50 EVAL P COMP PJSM on removing RA source. LD CNUCCUGR. 22:15 - 23:00 0.75 EVAL P COMP Down load CNUCCUGR log. Rebuild valve on choke manifold. 23:00 - 00:00 1.00 BOPSURN DFAL COMP RU to test BOPE. Test BOPE. Witness of test waived by Chuck Sheve. 9/5/2003 00:00 - 07:00 7.00 BOPSUR N DFAL COMP Continue testing BOPE. Blind rams not holding. Rebuild/retest blind rams - OK. Finish BOPE test. 07:00 - 08:00 1.00 CEMT N COMP Line up to test liner lap. Compressive strength of cement - >2000psi. Fill hole with 2bbls & pressure up WH in 500psi intervals. WHP/IAP/OAP = 2172/0/132psi @ onset of test. After 10mins: WHPIIAP/OAP @ 2131/0/132psi. After 20m ins: WHP/IAP/OAP @ 2113/0/132psi. After 30m ins: WHP/IAP/OAP @ 2102/0/132psi. Lap passed test! 08:00 - 08:15 0.25 PERF P COMP PJSM with all personnel concerning perforating operations. 08:15 - 09:00 0.75 PERF P COMP RIU to run perf guns. RIU safety jt. 09:00 - 10:30 1.50 PERF P COMP M/U 30jts of SWS 2" perf guns & blanks with CBF firing system. 10:30 - 11 :30 1.00 PERF P COMP M/U 36 doubles of 1-1/4" CSH tbg. 11 :30 - 12:55 1.42 PERF P COMP RIH perforating BHA#11 on CT to PBTD tagged @ 11215'. Up wt check = 31 k. Retag PBTD @ 11215'. Pull to P/U wt (31 k) & correct CTD to 11190' (PBTD as per MCNL log). 12:55 - 13:40 0.75 PERF P COMP PUH to ball drop position @ 11181'. Pump 10bbl perf pill ahead. Load 5/8" steel ball. Blow ball into CT with 5bbls perf pill behind. Position guns for btm shot @ 11185'. Chase ball to seat @ 2.6bpm/3000psi. Slow to 1.2bpm/800psi @ 45bbls. Ball on seat after 53.6bbls away. Ramp up to 3050psi & observe guns fire with good pressure drop indication. Perforated interval = 10570' - 10700', 10950' - 11185'. 13:40 - 14:50 1.17 PERF P COMP POOH with perf gun BHA #11. 14:50 - 15:05 0.25 PERF P COMP PJSM on UD 1-1/4" CSH. 15:05 - 17:30 2.42 PERF P COMP SIB injector & UD 72jts of 1-1/4" CSH tbg. 17:45 - 18:15 0.50 PERF P COMP PJSM on LID Perf guns. Printed: 9/812003 8:49: 11 AM ..... .. BP EXPLORATION Operations Summary Report Legal Well Name: F-15 Common Well Name: F-15 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date I From - To ¡ Hours Task Code NPT ! . 9/5/2003 9/6/2003 18:15 - 21:30 21 :30 - 22:30 22:30 - 23:40 23:40 - 00:00 00:00 - 01 :00 01 :00 - 02:30 Phase 3.25 PERF P 1.00 PERF P 1.17 RUNCOIIIP 0.33 RIGD P 1.00 WHSUR P 1.50 WHSUR P COMP COMP COMP COMP POST POST Page 9 of 9 Start: 8/28/2003 Rig Release: 9/6/2003 Rig Number: N1 Spud Date: 12/28/1981 End: 9/9/2003 Description of Operations .." .~ - -- ...-- LD perf guns. All shots fired. Clear floor. Take perf guns out of shed. Off load KCI. MU nozzle. Stab injector. RIH to 2,200'. Lay in MeOH 50/50. PJSM for blowing down reel with N2. Blow down reel with Nitrogen. Bleed down reel. ND BOP. NU tree cap and test tree. Release rig at 02:30 on 9/6/03. Printed: 9/8/2003 8:49: 11 AM · AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 , 80,3 -»37- 15-Sep-03 Re: Distribution of Survey Data for Well F-15A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,300.00 I MD 9,370.00 I MD 11,226.00 I MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager AUachment(s) ~~~ "---- ''- ~ \~:\.~x\\ "-"~ . Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_ WOA F Pad F-15A Job No. AKMW0002633660, Surveyed: 2 September, 2003 Survey Report 2003 September, 11 . Your Ref: API 500292065101 Surface Coordinates: 5973529.00 N, 652649.00 E (70020' 04.7977" N, 148045' 41.5838" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Survey Ref: svy4093 Surface Coordinates relative to Project H Reference: 973529.00 N, 152649.00 E (Grid) Surface Coordinates relative to Structure Reference: 966.03 N, 1709.15 E (True) Kelly Bushing: 71.30ft above Mean Sea Level Elevation relative to Project V Reference: 71.30ft Elevation relative to Structure Reference: 71.30ft Si I~a ·.....y-sul! DR I L. L.. I N Ö-' s e R'V 11:: e !is A Halliburton Company Sperry-Sun Drilling Services Survey Report for PBU_WOA F Pad· F-15A Your Ref: API 500292065101 Job No. AKMW0002633660, Surveyed: 2 September, 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) (0/1 OOft) 9300.00 14.950 238.690 8773.36 8844.66 1552.508 1669.81 W 5971942.84 N 651011.13E 1748.78 Tie On Point MWD Magnetic 9370.00 14.100 239.070 8841.12 8912.42 1561.578 1684.84 W 5971933.46 N 650996.29 E 1.222 1764.26 Window Point 9411.33 18.730 244.890 8880.76 8952.06 1566.98 8 1695.18 W 5971927.85 N 650986.07 E 11.875 1774.86 9429.36 20.260 246.230 8897.75 8969.05 1569.468 1700.65 W 5971925.25 N 650980.64 E 8.840 1780.46 . 9457.23 28.550 247.710 8923.11 8994.41 1573.94 8 1711.25 W 5971920.55 N 650970.14 E 29.824 1791.28 9486.88 35.330 248.830 8948.26 9019.56 1579.738 1725.82 W 5971914.47 N 650955.69 E 22.953 1806.13 9514.52 42.560 249.630 8969.74 9041.04 1585.888 1742.06 W 5971907.99 N 650939.58 E 26.220 1822.67 9545.77 53.870 250.350 8990.53 9061.83 1593.83 8 1763.92 W 5971899.60 N 650917.89 E 36.232 1844.92 9573.88 63.610 254.280 9005.10 9076.40 1601.088 1786.79 W 5971891.89 N 650895.17 E 36.643 1868.14 9605.98 75.770 262.910 9016.24 9087.54 1606.928 1816.23 W 5971885.44 N 650865.85 E 45.467 1897.84 9635.45 87.140 270.310 9020.62 9091.92 1608.628 1845.25 W 5971883.16 N 650836.87 E 45.858 1926.91 9645.58 90.840 273.660 9020.80 9092.10 1608.26 8 1855.37 W 5971883.31 N 650826.74 E 49.265 1937.00 9671 .40 97.000 281.060 9019.03 9090.33 1604.978 1880.89 W 5971886.08 N 650801.16 E 37.228 1962.31 9716.67 95.120 289.100 9014.24 9085.54 1593.27 8 1924.32 W 5971896.90 N 650757.51 E 18.142 2005.07 9770.29 94.180 297.450 9009.89 9081.19 1572.178 1973.37 W 5971916.99 N 650708.04 E 15.620 2052.94 9795.30 94.540 302.730 9007.99 9079.29 1559.678 1994.94 W 5971929.05 N 650686.22 E 21.100 2073.83 9838.54 93.890 313.000 9004.80 9076.10 1533.23 8 2028.93 W 5971954.79 N 650651.69 E 23.734 2106.40 9867.63 95.420 316.300 9002.44 9073.74 1512.868 2049.56 W 5971974.74 N 650630.66 E 12.470 2125.93 9896.63 94.540 320.530 8999.92 9071.22 1491.268 2068.73 W 5971995.95 N 650611.05 E 14.844 2143.94 9923.12 91.890 318.240 8998.43 9069.73 1471.188 2085.94 W 5972015.66 N 650593.43 E 13.212 2160.08 9947.42 90.220 314.720 8997.99 9069.29 1453.57 8 2102.67 W 5972032.93 N 650576.35 E 16.030 2175.86 . 9973.24 89.160 308.730 8998.13 9069.43 1436.39 8 2121.93 W 5972049.72 N 650556.74 E 23.559 2194.20 10000.30 90.680 303.510 8998.16 9069.46 1420.45 8 2143.78 W 5972065.21 N 650534.57 E 20.091 2215.18 10041.10 90.480 299.390 8997.75 9069.05 1399.178 2178.58 W 5972085.78 N 650499.35 E 10.109 2248.82 10073.90 89.250 294.810 8997.83 9069.13 1384.23 8 2207.77 W 5972100.12 N 650469.86 E 14.458 2277.19 10097.30 88.190 291.810 8998.35 9069.65 1374.978 2229.25 W 5972108.94 N 650448.20 E 13.594 2298.16 10133.30 93.570 290.400 8997.80 9069.10 1362.028 2262.82 W 5972121.21 N 650414.37 E 15.449 2331.00 10161.70 94.180 287.930 8995.88 9067.18 1352.71 8 2289.58 W 5972129.97 N 650387.43 E 8.939 2357.24 10196.60 94.800 284.060 8993.15 9064.45 1343.138 2323.02 W 5972138.87 N 650353.80 E 11 .197 2390.13 10230.70 93.660 279.470 8990.63 9061.93 1336.20 8 2356.30 W 5972145.12 N 650320.38 E 13.834 2423.01 11 September, 2003 - 17:05 Page 2 of 4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA F Pad - F-15A Your Ref: API 500292065101 Job No. AKMW0002633660, Surveyed: 2 September, 2003 BPXA North Slope A/aska 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) 10270.40 92.420 272.430 8988.52 9059.82 1332.098 2395.71 W 5972148.42 N 650280.90 E 17.981 2462.14 10308.00 94.100 281.060 8986.38 9057.68 1327.698 2432.95 W 5972152.07 N 650243.58 E 23.346 2499.10 10331.90 96.390 284.590 8984.19 9055.49 1322.41 8 2456.15 W 5972156.87 N 650220.27 E 17.553 2522.00 10362.10 96.120 289.170 8980.90 9052.20 1313.698 2484.87 W 5972165.00 N 650191.38 E 15.102 2550.22 . 10393.60 92.070 293.570 8978.65 9049.95 1302.258 2514.12 W 5972175.85 N 650161.91 E 18.956 2578.83 10434.50 89.340 290.400 8978.15 9049.45 1286.94 8 2552.03 W 5972190.38 N 650123.69 E 10.228 2615.89 10473.90 86.780 287.580 8979.48 9050.78 1274.138 2589.26 W 5972202.43 N 650086.21 E 9.663 2652.39 10501.30 86.610 285.290 8981.06 9052.36 1266.39 8 2615.49 W 5972209.64 N 650059.82 E 8.367 2678.19 10533.20 87.670 282.650 8982.65 9053.95 1258.708 2646.41 W 5972216.70 N 650028.76 E 8.908 2708.66 10568.10 90.480 279.470 8983.22 9054.52 1252.01 8 2680.65 W 5972222.69 N 649994.39 E 12.158 2742.50 10598.80 90.040 274.360 8983.08 9054.38 1248.31 8 2711.11 W 5972225.77 N 649963.86 E 16.706 2772.73 10632.20 91.630 266.610 8982.59 9053.89 1248.03 8 2744.48 W 5972225.37 N 649930.49 E 23.684 2806.04 10665.70 92.950 263.440 8981.25 9052.55 1250.938 2777.82 W 5972221.79 N 649897.21 E 10.243 2839.49 10693.60 89.430 254.630 8980.67 9051.97 1256.23 8 2805.18 W 5972215.93 N 649869.97 E 33.993 2867.08 10737.40 88.990 244.230 8981.28 9052.58 1271.608 2846.12 W 5972199.74 N 649829.35 E 23.763 2908.77 10768.50 91.890 238.240 8981.04 9052.34 1286.56 8 2873.37 W 5972184.23 N 649802.41 E 21.397 2936.77 10798.20 91.630 229.960 8980.12 9051.42 1303.95 8 2897.40 W 5972166.35 N 649778.74 E 27.879 2961.67 10827.70 88.720 225.200 8980.03 9051.33 1323.84 8 2919.17 W 5972146.02 N 649757.38 E 18.910 2984.45 10853.60 87.580 218.860 8980.87 9052.17 1343.06 8 2936.49 W 5972126.45 N 649740.46 E 24.858 3002.75 10886.20 87.670 212.340 8982.22 9053.52 1369.538 2955.44 W 5972099.60 N 649722.05 E 19.985 3023.06 10915.20 88.900 205.110 8983.09 9054.39 1394.93 8 2969.36 W 5972073.92 N 649708.65 E 25.278 3038.30 . 10946.70 90.400 195.600 8983.29 9054.59 1424.43 8 2980.30 W 5972044.21 N 649698.31 E 30.562 3050.77 10975.00 90.660 188.020 8983.02 9054.32 1452.118 2986.09 W 5972016.42 N 649693.08 E 26.799 3058.00 11006.90 91.890 180.090 8982.31 9053.61 1483.89 8 2988.35 W 5971984.59 N 649691.48 E 25.150 3061.91 11029.20 93.300 176.040 8981.30 9052.60 1506.158 2987.59 W 5971962.35 N 649692.68 E 19.213 3062.33 11060.70 93.570 181.680 8979.41 9050.71 1537.588 2986.97 W 5971930.95 N 649693.95 E 17.893 3063.35 11095.90 90.930 190.310 8978.03 9049.33 1572.528 2990.64 W 5971895.93 N 649690.99 E 25.618 3068.84 11122.20 91.890 191.900 8977.38 9048.68 1598.32 8 2995.70 W 5971870.04 N 649686.45 E 7.060 3075.25 11165.60 89.600 200.000 8976.82 9048.12 1640.01 8 3007.62 W 5971828.12 N 649675.38 E 19.392 3089.33 11189.20 88.190 206.170 8977.27 9048.57 1661.708 3016.87 W 5971806.24 N 649666.58 E 26.813 3099.70 11226.00 88.190 206.170 8978.43 9049.73 1694.71 8 3033.09 W 5971772.90 N 649651.03 E 0.000 3117.63 Projected 8urvey 11 September, 2003 - 17:05 Page 3 of 4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_ WOA F Pad - F-15A Your Ref: API 500292065101 Job No. AKMW0002633660, Surveyed: 2 September, 2003 BPXA North Slope A/aska 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 267.000° (True). Magnetic Declination at Surface is 25.723°(02-Sep-03) . Based upon Minimum Curvature type calculations, at a Measured Depth of 11226.00ft., The Bottom Hole Displacement is 3474.43ft., in the Direction of 240.806° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9300.00 9370.00 11226.00 8844.66 8912.42 9049.73 1552.50 S 1561.57S 1694.71 S 1669.81 W 1684.84 W 3033.09 W Tie On Point Window Point Projected Survey Survey tool program for F-15A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) . Survey Tool Description 0.00 9300.00 0.00 8844.66 9300.00 11226.00 8844.66 BP High Accuracy Gyro (F-15) 9049.73 MWD Magnetic (F-15A) 11 September, 2003 - 17:05 Page 4 of 4 DrillQuest 3.03.02.005 . (ill ~~~~~~~ . / FRANK H. MURKOWSKI, GOVERNOR / / 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~1#ASIiA OIL AND GAS CONSERVATION COMMISSION Mary Endacott CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit F-15A BP Exploration (Alaska), Inc. Permit No: 203-137 Surface Location: 3284' SNL, 2201' WEL, Sec. 02, TIIN, R13E, UM Bottomhole Location: 4922' SNL, 7' WEL, Sec. 03, TI1N, R13E, UM Dear Mr. Endacott: 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). Sincere.)x.-~ .~ S~ Chair BY ORDER OF THE COMMISSION DATED this í7IL-day of August, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encI. Exploration, Production and Refineries Section WW\- SIll 'l.-tìO 6 ~ a. Type of work 0 Drill ORe-Entry 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 = 652649, Y = 5973529 3284' SNL, 2201' WEL, SEC. 02, T11 N, R13E, UM At top of productive interval x = 651054, Y = 5971970 4811' SNL, 3830' WEL, SEC. 02, T11 N, R13E, UM At total depth x = 649599, Y = 5971829 4922' SNL, 7' WEL, SEC. 03, T11 N, R13E, UM 12. Distance to nearest property line 113. Distance to nearest well /' ADL 028280, 7' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 9365' MD Maximum Hole Angle 18. Casing ~rogram Specifications Size Hole Casina Weiaht Grade Couclina 3-3/4" 3-3116" x 2-7/8" 6.2#/6.16# L-80 ST-L . STATE OF ALASKA . ALAS~IL AND GAS CONSERVATION COM . SION PERMIT TO DRILL / 20 AAC 25.005 / II Redrill 11 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 71.30' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028281 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / F-15A 9. Approximate spud d~ 08/20/03 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 /11150' MD I 8990' TVDss 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 900 Maximum surface 2096 psig, At total depth (TVD) 8800' / 3170 psig Setting Depth Top Bottom Lenath MD TVD MD TVD 2660' 8490' 7990' 11150' 9062' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Quantity of Cement (include staae data) 118 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 9814 feet 9345 feet 9765 feet 9297 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD 3 cu yds Concrete 110' 110' 3720 cu ft Permafrost II 2674' 2674' 1202 cu ft Class 'G', 130 cu ft PF 'C' 8956' 8515' 360 cu ft Class 'G' 8464' - 9814' 8048' - 9345' 110' 20" x 30" 2674' 13-3/8" 8956' 9-5/8" 1350' 7" Open: 9415' - 9420', 9505' - 9550' Sqzd: 9410' - 9415', 9431' - 9472' true vertical Open: 8956' - 8961', 9044' - 9088' Sqzd: 8951' - 8956', 8972' - 9012' II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II· Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report II 20 AAC 25.050 Requirements Contact Engineer NameINumber: Mary Endacott, 564-4388 Prepared By NameINumber: Terrie Hubb/e, 564-4628 21. Is~;~::y c::~~:;:~:he fOiJoing is trl1~'b;~:eOf ~; ~~~:~g:gineer Date 1/29/ ð 3 ';~~::~~::al:~:~~~1_01~;!~~:;::%~1'¿T~~:~~.: Hydrogen Sulfide Measures J:;!S Yes 0 No Directional Survey Required J2!J Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: T est- l? 0 17 E- p., ~ S- 00 p ~ t . Original Signed By ^ e! order of Approved By £arW't pe1iJ'l rçertiQ~N ~e commission Form 10-401 Rev. 12-01-8'0- U f\ \ U \ Perforation depth: measured 20. Attachments Date 9 /~6 :? SUbZ~~ 1riplicate e e BP F-15A CTD Sidetrack Summary of Operations: Phase 1: Prep work - integrity test lA, OA and tree, set whipstock Phase 2: Downsqueeze cmt into perfs, mill XN, mill window Phase 3: Drill and Complete sidetrack Mud Program: · Phase 2: Viscosified Seawater · Phase 3: Flo-Pro (8.6 - 8.7 ppg) ../ Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: /' The production liner will be ~~x 2 7/8" from 8490'MD (-7990'TVDss) to TO. The liner will be cemented with a minimum ~IS to bring cement up to ~200ft above the window. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. / · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 90 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · MWD Gamma Ray and Resistivity will be run in the open hole section. Memory CNL will be run inside the liner. Hazards · The maximum recorded H2S at F Pad is 10 ppm. / · Two mapped faults will be crossed, medium risk of lost circulation. Reservoir Pressure Res. press. is estimated to be 3170psi at 8800'ss (6.9ppg emw) estimated. Max. surface pressure with gas (0.12 psi/ft) to surface is 2096 psi. OTIS s NOTES: IA X OA COMM. , TREE '" 6" CrN WELLHEAD :: ACTUATOR :: K8. ELEV:: 8F. KOP:: Max Angle :: Datum MD :: DatumTVD :: 3300' 21 @ 6200' 9321' 8800' 113-3/8" CSG, 12#, L-SO, ID:: 12.347" Ii 2680' I ~ Minimum ID :::: 3.725" @ 8505' OTIS XN NIPPLE I 5-1/2" T8G, 17#, L-SO IJ4S, 0.0232 bpf, ID:: 4.S92" H TOPOF4-1/2"TBG H TOP OF 7" LNR 1-1 8405' I-- 8405' I M64' 14-1/2" TElG, 12.6#, L-80, 0.0152 bpf, ID:: 3.95S" H 19-5/S" CSG, 47#, L-80, ID:: S.6S1 H 8549' I 8956' ~ PERFORATION SUMMARY REF LOG: SWS 8HCS ON 04/10/82 ANGLE AT TOP PERF: 14 @ 9410' Note: Refer to Production D8 for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/S" 4 9410·9415 3-3/8" 6 9415 - 9420 3-1/8" 4 9431 - 9472 3·3/8" 6 9505 - 9520 3-3/8" 6 9520 . 9550 9765' I 7" LNR. 29#, L-80 1J4S, 0.0371 bpf, ID:: 6.184" 1-1 9814' DATE REV BY COMMENTS DATE REV BY 04/15/82 ORIGINAL COMPLETION 03/01/01 SIS-MH CONVERTED TO CANV AS 03/05/01 SIS-MD FINAL 10/05/01 RN/TP CORRECTIONS 10/04/02 BMlTP WANER SAFETY NOTE 02/09/03 A TDITP DELETE WANER SAFETY NOTE . 2093' H5-1/2" OTIS SSSV LAND NIP, ID::4.562" I GAS LIFT MANDRELS .. ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 3013 2941 4 CAMCO RK 11 4964 4780 24 CAMCO RK 10 6072 5179 27 CAMCO RK 9 6213 5904 27 CAMCO RK l 8 6186 6418 26 CAMeO RK 7 6933 6551 26 CAMCO RK 6 1313 6899 23 CAMeO RK 5 7456 7030 22 CAMeO RK 4 7794 7345 20 CAMeO RK 3 7938 7481 20 CAMCO RK 2 8120 7652 20 CAMCO RK 1 8266 1790 20 CAMCO RK 8325' ¡-I OTIS XA SLIDING SLEEVE, ID:: 4.562" 8383' 1-1 SAKER SBR TSG SEAL ASSY r MOS' - 9-5/8" X 5-1/2" BKR SAB PKR. ID:: 4.892" 1 M05' - 5-1/2" X 4-1/2" XO 1 8462' - 4-1/2" OTIS X NIP, ID:: 3.813" I I - I 8505' -4-1/2" OTIS XN NIP, ID:: 3.725" I I 8549' - 4-1/2 SKRSOS TBG TAIL I .. 8503' - ELMD TI LOGGED 04/02/83 w. -MARKER"JOIW"'1 I 1 COMMENTS PRUDHOE SAY UNIT WELL: F·15 PERMIT No: 1811300 API No: 50·029-20651·00 SEC2, T11N, R13E SP Exploration (Alaska) ObP e e .ii. ...... BP-GDB Baker Hughes INTEQ Planning Report ------'-.--.---- IN'TEQ Page: Co-ordinate(NE) Reference: Vertical (fVD) Reference: Section (VS) Reference: Survey Calculation Metllod: Well: F-15, True North System: Mean Sea Level Well (0.ooN,0.00E,267.00Azi) 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: Alaska, Zone 4 Well Centre bggm2003 Site: PB F Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5972527.29 ft 650960.70 ft Latitude: 70 19 Longitude: 148 46 North Reference: Grid Convergence: 55.283 N 31.468 W True 1.15 deg Well: F-15 Slot Name: 15 F-15 Well Position: +N/-S 967.60 ft Northing: 5973529.00 ft Latitude: 70 20 4.798 N +E/-W 1708.24 ft Easting : 652649.00 ft Longitude: 148 45 41.584 W Position Uncertainty: 0.00 ft +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 F-15 9300.00 ft Mean Sea Level 25.58 deg 80.86 deg Direction deg 267.00 Wellpath: Plan#1 F-15A 500292065101 Current Datum: 15: 1512/28/1981 00:00 Magnetic Data: 7/28/2003 Field Strength: 57566 nT Vertical Section: Depth From (TVD) ft 35.80 Height 71.30 ft Targets F-15A Fault 1 0.00 -1541.38 -2263.01 5971942.00 650418.00 70 19 49.635 N 148 46 47.655 W -Polygon 1 0.00 -1541.38 -2263.01 5971942.00 650418.00 70 19 49.635 N 148 46 47.655 W -Polygon 2 0.00 -1382.89 -1940.69 5972107.00 650737.00 70 1951.195 N 148 46 38.246 W F-15A Fault 2 0.00 -1255.25 -3100.42 5972211.00 649575.00 70 19 52.446 N 148 47 12.108 W -Polygon 1 0.00 -1255.25 -3100.42 5972211.00 649575.00 70 19 52.446 N 148 47 12.108 W -Polygon 2 0.00 -1547.21 -2615.23 5971929.00 650066.00 70 19 49.577 N 148 46 57.939 W F-15A Polygon1.1 0.00 -989.12 -2709.89 5972485.00 649960.00 70 19 55.065 N 148 47 0.709 W -Polygon 1 0.00 -989.12 -2709.89 5972485.00 649960.00 70 19 55.065 N 148 47 0.709 W -Polygon 2 0.00 -1564.17 -3206.74 5971900.00 649475.00 70 19 49.407 N 148 47 15.208 W -Polygon 3 0.00 -1718.63 -2989.82 5971750.00 649695.00 70 19 47.889 N 148 47 8.873 W -Polygon 4 0.00 -1375.91 -2627.74 5972100.00 650050.00 70 19 51.261 N 148 46 58.306 W -Polygon 5 0.00 -1474.76 -2439.70 5972005.00 650240.00 70 19 50.290 N 148 46 52.815 W -Polygon 6 0.00 -1338.95 -2231.88 5972145.00 650445.00 70 1951.626N 148 46 46.748 W -Polygon 7 0.00 -1082.15 -2316.68 5972400.00 650355.00 70 1954.151 N 148 46 49.226 W F-15A T1.3 8990.00 -1641.71 -3083.28 5971825.00 649600.00 70 19 48.645 N 148 4711.603 W F-15A T1.1 8995.00 -1626.34 -1872.63 5971865.00 650810.00 70 19 48.800 N 148 46 36.257 W F-15A T1.2 8995.00 -1245.72 -2635.09 5972230.00 650040.00 70 19 52.542 N 148 46 58.522 W Annotation MD ft 9300.00 8773.36 TIP 9365.00 8836.28 KOP 9385.00 8855.60 3 9435.00 8901.41 4 ObP e BP-GDB e ... ..... Baker Hughes INTEQ Planning Report INTEQ Company: 6PAmOC() Page: 2 Field: Pf\Jdhøø6¡:\y Co-ordinate(NE) Reference: Well: F-15, True North Site: PBF Pad Vertical (TVD) Reference: System: Mean Sea Level Well: F,.15 Section (VS) Reference: Well (0.00N,O.00E,267.00Azi) Wellpath: Plan#1 F-15A Calculation Method: Minimum Curvature Db: Oracle ___'_"__'___.'~__.._.. _.~"...___.' ._..____._....~.._ __hu.' Annotation 9630.90 8994.40 5 10060.90 8994.40 6 11150.00 8990.27 TO Plan: Plan #1 Date Composed: 7/28/2003 Identical to Lamar's Plan #1 Version: 2 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 9300.00 14.95 238.69 8773.36 -1552.50 -1669.81 0.00 0.00 0.00 0.00 9365.00 14.10 239.07 8836.28 -1560.92 -1683.77 1.32 -1.31 0.58 173.79 9385.00 15.80 241.33 8855.60 -1563.48 -1688.25 9.00 8.52 11.30 20.00 9435.00 30.82 251.61 8901.41 -1570.83 -1706.49 31.00 30.03 20.56 20.00 9630.90 90.00 268.97 8994.40 -1590.29 -1867.39 31.00 30.21 8.86 20.00 10060.90 90.00 320.57 8994.40 -1416.18 -2244.77 12.00 0.00 12.00 90.00 11150.00 90.23 189.87 8990.27 -1637.56 -3083.93 12.00 0.02 -12.00 270.30 Survey 9300.00 14.95 238.69 8773.36 -1552.50 -1669.81 5971942.95 651011.25 1748.78 0.00 0.00 TIP 9325.00 14.62 238.83 8797.53 -1555.81 -1675.27 5971939.54 651005.87 1754.40 1.32 173.79 MWD 9350.00 14.30 238.98 8821.74 -1559.03 -1680.61 5971936.20 651000.59 1759.90 1.32 173.65 MWD 9365.00 14.10 239.07 8836.28 -1560.92 -1683.77 5971934.25 650997.47 1763.15 1.32 173.51 KOP 9375.00 14.95 240.26 8845.96 -1562.19 -1685.93 5971932.94 650995.33 1765.38 9.00 20.00 MWD 9385.00 15.80 241.33 8855.60 -1563.48 -1688.25 5971931.60 650993.05 1767.76 9.00 18.84 3 9400.00 20.23 245.93 8869.86 -1565.52 -1692.41 5971929.47 650988.93 1772.02 31.00 20.00 MWD 9425.00 27.77 250.40 8892.69 -1569.24 -1701.86 5971925.56 650979.56 1781.65 31.00 15.62 MWD 9435.00 30.82 251.61 8901.41 -1570.83 -1706.49 5971923.88 650974.96 1786.36 31.00 11.53 4 9450.00 35.22 254.36 8913.98 -1573.21 -1714.30 5971921.34 650967.20 1794.29 31.00 20.00 MWD 9475.00 42.66 257.83 8933.42 -1576.95 -1729.55 5971917.30 650952.03 1809.71 31.00 17.69 MWD 9500.00 50.18 260.43 8950.64 -1580.33 -1747.32 5971913.55 650934.33 1827.63 31.00 14.99 MWD 9525.00 57.74 262.52 8965.34 -1583.31 -1767.30 5971910.17 650914.42 1847.74 31.00 13.19 MWD 9550.00 65.34 264.28 8977.25 -1585.82 -1789.11 5971907.21 650892.66 1869.66 31.00 11.96 MWD 9575.00 72.95 265.84 8986.14 -1587.83 -1812.37 5971904.73 650869.45 1892.99 31.00 11.12 MWD 9590.17 77.52 266.71 8990.00 -1588.78 -1827.01 5971903.49 650854.84 1907.65 30.65 10.56 F-15A T1 9600.00 80.57 267.27 8991.86 -1589.28 -1836.64 5971902.78 650845.22 1917.30 31.54 10.34 MWD 9625.00 88.20 268.65 8994.31 -1590.17 -1861.49 5971901.40 650820.40 1942.16 31.00 10.23 MWD 9630.90 90.00 268.97 8994.40 -1590.29 -1867.39 5971901.15 650814.50 1948.06 31.00 10.10 5 9650.00 90.00 271.26 8994.40 -1590.25 -1886.49 5971900.80 650795.41 1967.13 12.00 90.00 MWD 9675.00 90.00 274.26 8994.40 -1589.05 -1911.45 5971901.50 650770.42 1992.00 12.00 90.00 MWD 9700.00 90.00 277.26 8994.40 -1586.54 -1936.33 5971903.50 650745.51 2016.70 12.00 90.00 MWD 9725.00 90.00 280.26 8994.40 -1582.73 -1961.03 5971906.80 650720.73 2041.18 12.00 90.00 MWD 9750.00 90.00 283.26 8994.40 -1577.64 -1985.50 5971911.40 650696.16 2065.35 12.00 90.00 MWD 9775.00 90.00 286.26 8994.40 -1571.27 -2009.68 5971917.27 650671.87 2089.16 12.00 90.00 MWD 9800.00 90.00 289.26 8994.40 -1563.65 -2033.48 5971924.41 650647.91 2112.53 12.00 90.00 MWD 9825.00 90.00 292.26 8994.40 -1554.79 -2056.86 5971932.79 650624.36 2135.41 12.00 90.00 MWD 9850.00 90.00 295.26 8994.40 -1544.71 -2079.73 5971942.39 650601.29 2157.73 12.00 90.00 MWD 9875.00 90.00 298.26 8994.40 -1533.46 -2102.05 5971953.19 650578.74 2179.43 12.00 90.00 MWD 9900.00 90.00 301.26 8994.40 -1521.05 -2123.76 5971965.15 650556.80 2200.45 12.00 90.00 MWD 9925.00 90.00 304.26 8994.40 -1507.53 -2144.78 5971978.25 650535.51 2220.74 12.00 90.00 MWD 9950.00 90.00 307.26 8994.40 -1492.92 -2165.06 5971992.44 650514.93 2240.23 12.00 90.00 MWD 9975.00 90.00 310.26 8994.40 -1477.27 -2184.55 5972007.69 650495.12 2258.87 12.00 90.00 MWD 10000.00 90.00 313.26 8994.40 -1460.62 -2203.20 5972023.95 650476.14 2276.62 12.00 90.00 MWD ObP e BP-GDB e B.. ..... Baker Hughes INTEQ Planning "Report tNTEQ Co-ordinate(NE) Reference: Vertical (fVD) Reference: Section (VS) Reference: Survey Calculation Method: Oracle _..____'_._....___.___..___..__ _._.._____._........_...___._.. _n__...__"__' Survey MD ft 10025.00 90.00 316.26 8994.40 -1443.02 -2220.95 5972041.19 650458.04 2293.43 12.00 90.00 MWD 10050.00 90.00 319.26 8994.40 -1424.51 -2237.75 5972059.34 650440.87 2309.24 12.00 90.00 MWD 10060.90 90.00 320.57 8994.40 -1416.18 -2244.77 5972067.54 650433.68 2315.81 12.00 90.00 6 10075.00 90.01 318.87 8994.40 -1405.42 -2253.89 5972078.11 650424.35 2324.35 12.00 270.30 MWD 10100.00 90.02 315.87 8994.39 -1387.02 -2270.82 5972096.15 650407.05 2340.30 12.00 270.30 MWD 10125.00 90.04 312.87 8994.38 -1369.54 -2288.68 5972113.26 650388.83 2357.22 12.00 270.30 MWD 10150.00 90.06 309.87 8994.36 -1353.02 -2307.44 5972129.40 650369.74 2375.09 12.00 270.30 MWD 10175.00 90.07 306.87 8994.33 -1337.50 -2327.04 5972144.51 650349.83 2393.85 12.00 270.29 MWD 10200.00 90.09 303.88 8994.29 -1323.03 -2347.42 5972158.57 650329.16 2413.45 12.00 270.29 MWD 10225.00 90.10 300.88 8994.25 -1309.65 -2368.53 5972171.52 650307.79 2433.83 12.00 270.29 MWD 10250.00 90.12 297.88 8994.21 -1297.38 -2390.32 5972183.33 650285.76 2454.94 12.00 270.28 MWD 10275.00 90.13 294.88 8994.15 -1286.28 -2412.71 5972193.98 650263.14 2476.72 12.00 270.28 MWD 10300.00 90.14 291.88 8994.09 -1276.36 -2435.66 5972203.43 650240.00 2499.12 12.00 270.27 MWD 10325.00 90.16 288.88 8994.03 -1267.66 -2459.09 5972211.65 650216.40 2522.06 12.00 270.26 MWD 10350.00 90.17 285.88 8993.96 -1260.19 -2482.95 5972218.63 650192.40 2545.50 12.00 270.26 MWD 10375.00 90.18 282.88 8993.88 -1253.99 -2507.16 5972224.34 650168.06 2569.35 12.00 270.25 MWD 10400.00 90.20 279.88 8993.80 -1249.06 -2531.67 5972228.77 650143.46 2593.57 12.00 270.24 MWD 10425.00 90.21 276.88 8993.71 -1245.42 -2556.40 5972231.91 650118.67 2618.07 12.00 270.23 MWD 10450.00 90.22 273.88 8993.61 -1243.07 -2581.28 5972233.74 650093.74 2642.80 12.00 270.22 MWD 10475.00 90.23 270.88 8993.52 -1242.04 -2606.26 5972234.27 650068.75 2667.69 12.00 270.21 MWD 10500.00 90.24 267.88 8993.42 -1242.31 -2631.25 5972233.49 650043.77 2692.67 12.00 270.19 MWD 10525.00 90.25 264.88 8993.31 -1243.89 -2656.20 5972231.40 650018.86 2717.66 12.00 270.18 MWD 10550.00 90.26 261.88 8993.20 -1246.78 -2681.03 5972228.01 649994.10 2742.61 12.00 270.17 MWD 10575.00 90.26 258.88 8993.09 -1250.95 -2705.68 5972223.33 649969.54 2767.44 12.00 270.16 MWD 10600.00 90.27 255.88 8992.97 -1256.42 -2730.07 5972217.37 649945.27 2792.08 12.00 270.14 MWD 10625.00 90.28 252.88 8992.85 -1263.15 -2754.14 5972210.15 649921.34 2816.48 12.00 270.13 MWD 10650.00 90.28 249.88 8992.73 -1271.13 -2777.83 5972201.69 649897.82 2840.55 12.00 270.11 MWD 10675.00 90.29 246.88 8992.60 -1280.35 -2801.07 5972192.01 649874.78 2864.24 12.00 270.10 MWD 10700.00 90.29 243.87 8992.48 -1290.76 -2823.79 5972181.13 649852.27 2887.47 12.00 270.08 MWD 10725.00 90.30 240.87 8992.35 -1302.35 -2845.94 5972169.09 649830.37 2910.20 12.00 270.07 MWD 10750.00 90.30 237.87 8992.22 -1315.09 -2867.45 5972155.92 649809.12 2932.34 12.00 270.05 MWD 10775.00 90.30 234.87 8992.09 -1328.93 -2888.26 5972141.66 649788.59 2953.86 12.00 270.04 MWD 10800.00 90.30 231.87 8991.96 -1343.84 -2908.32 5972126.35 649768.84 2974.67 12.00 270.02 MWD 10825.00 90.30 228.87 8991.83 -1359.78 -2927.58 5972110.02 649749.92 2994.73 12.00 270.01 MWD 10850.00 90.30 225.87 8991.70 -1376.71 -2945.97 5972092.72 649731.88 3013.98 12.00 269.99 MWD 10875.00 90.30 222.87 8991.57 -1394.58 -2963.45 5972074.50 649714.76 3032.38 12.00 269.98 MWD 10900.00 90.29 219.87 8991.44 -1413.34 -2979.97 5972055.41 649698.63 3049.86 12.00 269.96 MWD 10925.00 90.29 216.87 8991.31 -1432.93 -2995.49 5972035.51 649683.51 3066.38 12.00 269.94 MWD 10950.00 90.29 213.87 8991.18 -1453.31 -3009.96 5972014.83 649669.46 3081.90 12.00 269.93 MWD 10975.00 90.28 210.87 8991.06 -1474.43 -3023.35 5971993.46 649656.51 3096.37 12.00 269.91 MWD 11000.00 90.28 207.87 8990.94 -1496.21 -3035.61 5971971.43 649644.69 3109.75 12.00 269.90 MWD 11025.00 90.27 204.87 8990.82 -1518.60 -3046.71 5971948.82 649634.05 3122.02 12.00 269.88 MWD 11050.00 90.26 201.87 8990.70 -1541.55 -3056.63 5971925.67 649624.60 3133.12 12.00 269.87 MWD 11075.00 90.26 198.87 8990.59 -1564.98 -3065.33 5971902.07 649616.38 3143.04 12.00 269.86 MWD 11100.00 90.25 195.87 8990.48 -1588.84 -3072.80 5971878.07 649609.40 3151.74 12.00 269.84 MWD 11125.00 90.24 192.87 8990.37 -1613.05 -3079.00 5971853.74 649603.69 3159.20 12.00 269.83 MWD 11150.00 90.23 189.87 8990.27 -1637.56 -3083.93 5971829.14 649599.26 3165.41 12.00 269.82 TO e Nordic 1 big hole e All Measurements are from top of Riser 7/28/2003 ~ Q) en .- cr: top of bag ...JI Schlumberger BAG 71/16" 5000psi ,. .. bttm of bag 1 .............(....... middle of slips Blind/Shears middle of pipes TOTs 23/8" combi ram/slips 1....;::...............71/1611 5000psi .......... r-- middle of flow cross Mud Cross Mud Cross 7 1/16" 5000psi ......... '---' middle of blind/shears I variable bore pipe 3 1/2"-21/8" I 2 3/8" combi ram/slips I E:" , I···· / ...................... / TOTs I.................········· 7 1/16" 5000psi middle of pipe/slips Flow Tee p055094 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS 6/9/2003 INV# CK060403N PERMIT TO DRILL FEE f· l SA THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX PAY: TO THE ORDER OF: NATIONAL CITY BANK Ashland, Ohio 1110 5 50 q 1.111 I: 0... 1 20 j B q 51: 0 1 2 ? B q bill DATE 6/9/2003 I I CHECK NO. 055094 VENDOR DISCOUNT NET 56-389 412 No. P 055094 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT I I **;~~~($1oo.00******1 ~O-;i"'\Lln~.;:'~~·:7·~~\::·;;~.?:{::.\;:;:··:~.:ß·(:;~,:~:. i%~I~¡W;'~:;:' 0'.. ".:............. ....... ....-'!'.......\..t._.i..u..._.........~......,'"..... ......",.. \i.,.-\', ........... .:~~.:.,:.':'\. :....:..... ;~v:"( :",<~.':"".,t H e -- e e TRANSMITAL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS 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" Tbe permit is for a new wellbore segment of existing weD ~ Permit No, API No. Production sbould continue to be reported as a function· of tbe original API number. stated above. BOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot bole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates Tbe permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv 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 tbe permafrost or from where samples are first caught and 10' sample intervals tbrough target zones. WELL PERM.IT ~~K1-I~T Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UNIT F-15A Program DEV Well bore seg PTD#: 2031370 Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Initial Class/Type DEV /1-0IL GeoArea 890 Unit 11650 On/Off Shore ~ Annular Disposal Administration 1 P~rmitfee attache.d_ _ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . 2 .Leas~.numberappropriate.. . . . . . . . . . . . . . . . . . . Yes _ . . . . . . . . . . . . _ . _ . . . . . . . . . . . .. _............. . . . . . . . 3 _U_nique well.nam~_aod Ol!mb.er . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . _ . _ . _ _ _ . . . . _ _ _ _Y~S _ _ _ . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . _ _ . . . . . . . . . . . . . . . . 4 WelUocat~d ina d.efil1e.d 'pool. . . .. ......................... . . . y~s . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ 5 WelUocated proper distance. from driJling ul1itb.oUl1d.ary. . . . . . . . . . . . . . . . . . . . . y~s . . _ . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . 6 WeU JQcat~d pr.oper .distance. from QtlJer weUs. . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7S.utficiel1t <lcreage.ayailable in.drilJiog unjt _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8 Jf.d~yiated, js. weJlbQre platil1cJuded . . . . . . . . . . . . . . . . . . . . . . . . . y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9 .O'per.ator 0111Y' affected party. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes . . . . . . .. ........................... . . . . . . . . . . . . . . . . . . . . 10 .O.perator has.appropriate.Qond inJorce . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y.es. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ . . _ _ . . . . . . . . . . . . 11 P~rmit c.an be iSSl!ed wjtlJout co.nserva.tiOI1 order . . . . . . . . . . . . . . . . . . . . . . . . . . . y~s . . . . . . . . . . . . . . . . . . . . .. ............................. . . . . . . . . . . . . 12 P~rmit c.ao be iSSl!ed wjtlJout ad.mil1istratille.approyaL . . .. .............. . y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8/1/2003 13 Can permit be approved before 15-day wait Yes 14 WelUocated within area and.strata.authorized by.lnjectioo Ord~r # (putlOtl in.c.omm.ents).(For NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . 15 AJI weUs.within .1l4.mile.area.of reyiew id~otified (For servjC;ew.e[l Ol1ly). . . . . . . _ . . . . . . . .NA . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . _ . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . 16 PfE~-produced.iojector; .duratiQnofpre-.pro.duGÌiool~ssthan.3m0l1ths(Forservtcewel[onJy). .NA..................................................... ............. 17 .AÇMP. Fjndjngof Con.sißteoçy.h.as bee.nJssued. for.this pr.olect . . . . . . . . . . NA . . . . . . . . . . . . . . . . . 18C.ondu.ctor string.prQvided . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ...... NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19 .S.urfaC;e .casil1g. proteds alLknown. USDWs . . . . . . . . . . . . . . . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20 .CMT v.ol adeQuate.to circ.ulate.oncOl1ductor & su.rf.C$g . . . . . . . . . . . . . . . .NA _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21CMTv.oladeQu.ate.totie-tnJong.striogto.sUrfcsg. ..... NA.. ...... ................. _ ........... 22 .CMTwiU coyer aU Kl1o.w.n.productiye IJQrizon.s. . . . . _ . . . . . . . . . . . . y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ............... 23 .C.asing designs ad.e(Jua.te for c,or, B.&.permafrost . . . . . . . . . . . . y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24A.dequate.tan.kageor re.serve pit. . _ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . CTDU. _ . . . . . . _ . _ . . . . . . . . . . . . _ . . . . . . . . . . .. ...... _ . 25 Jf.aJe-drilt has.a. 1.0,403 fQr abandon.me.nt be~n apprQved . . . .. _.......... _ . Yes. _ 7/30/2003. _ . . . . . . . . . . . . . _ . _ _ _ . . . . . . . . . . 26 .Adequ<lteweUbore separatjo.n.pro. )Osed. . . . . . . . . . _ . _ . . . . . . . . . _ _ _ . . . . . . . . .Y~S _ . _ . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27 Jf.divecter required, does it meet reguJatiol1s _ . . . . . . . . . _ . . _ _ . . . . . . . . . _ NA . . . . . . . Sidetrack. _........ . . . . . . . . . . _ . . . . . . . . . . . . _ _ . . . . . . . Appr Date 28 Drilliog fluid program sc.hematic.& eq.uipJistadequate_ . . . _ . . . . . . . y~s . . . . . . . Max MW.8..7: ppg. . . . . . . _ . _ . . . . . . . . . . . . . . _ . _ . . . . . . . . . . . WGA 8/1/2003 29 BOPEs, do they meet reguJatiol1 . . . . . . . . . _ . . . . . . . . . _ . . y~s . _ . . . . . . . . . . . _ _ . . . . . . . . . . . . _ .......... _ . . _ _ . 30 BOPE.Pfess rating ap.propriate; .testto(put psig in .commel1ts) . . . . . . . . _ . . . . . . . y~s _ . . . . . Test to .3500. psi.MSF> 20.96 psi.. _ . . . . . . . . . . . . _ _ _ . . . . . . . . . . . . . . . 31 Choke. manifold compJies. w/API RF>-53. (May 84). _ . . . . . . . . . y~s . . . . . . .. .......... _ . _ _ . . . . . . . . . . . . . _ . . . . . . . . . . 32 Work will occ.ur withoutoperatjonshutdo.w.n . . . . . _ . _ . . . . . . . . . . . y~s . . . . . . . _ . . . _ . . . _ . . . . . . . _ _........ 33 .Is presence_ of H2S gas prob.able. . . . . . . . . . . . _ . . . . . _ y~s . . . . . . . 10. ppm. _ . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . _ . _ . . . . . . . . . . . . 34 MeçhanicalcoodjtioootweUswithil1f\ORYerified(For.s.ervjcew~lJonJY')....... _. _.. NA ...... _ ......... _. _ _............ _ _........... Appr RPC Date Engineering Geology Appr RPC Date 8/1/2003 Geologic Commissioner: ÞTu - - - - - - - - - - - - - - - - - - - 35 P~rmitc.an be issued w/o hydrogens.ulfide measures. . . . . . . . _ _ . . . . . . . . . . . . . No. . . . . . . . _ 36 Datapreseoted on potential oyerpres_sure .zones. . . . . . . . . . . . . _ ........ NA . 37S~ism¡c.analysjs of shaJlow gas zones . . . . . . _ . . . . . . . . . _ . . . . . . . . . . . . NA . . . . . . . . 38 .S~abed .condWoo Sl!rvey.(if off-shore) . . . . . . . . . . . . . . . . . .. _....... .NA . . . . . . . . . . 39 . CQntact l1amelphoneJorweekly progress.reports [exploratory only] . . . . .NA . . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - -- Date: Engineering Commissioner: Public ~ Commissioner ~Date c.£'~~ c-' ..... ....s~ Date f/)).? o o e . e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . ÐO,3 ~I 3 '=f- Sperry-Sun Drilling Services LIS Scan Utility } )..^- q g $Revision: 3 $ LisLib $Revision: 4 $ Mon Dec 01 14:30:34 2003 Reel Header Service name.............LISTPE Date.....................03!12/01 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!12!01 Origin...................STS Tape Name................UNKNOWN Continuation Number......Ol 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 F-15A 500292065101 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 01-DEC-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002633660 B. JAHN WHITLOW / EG MWD RUN 2 MW0002633660 B. JAHN WHITLOW ! EG MWD RUN 3 MW0002633660 B. JAHN WHITLOW / EG JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0002633660 B. JAHN WHITLOW ! EG MWD RUN 5 MW0002633660 B. JAHN WHITLOW ! EG # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 UN BE 3284 2201 MSL 0) 71. 31 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.125 4.500 9370.0 RECEIVED # REMARKS: DEC 08 2003 Alaska Oä & Gas Cons. Comm_n Anchonsge ~~~\~~ . . 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THE WELL WAS EFFECTED BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 9370'MD AND THE BOTTOM WAS AT 9375'MD. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (GM), UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 3 - 5 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 6. UPHOLE DGR DATA ACQUIRED WHILE RIH FOR RUN 2 (9086.5'-9128'MD) AND RUN 3 (9355'-9403'MD) WERE MERGED WITH RUN 1 DATA. EWR4 DATA FROM 9630'MD TO WINDOW ARE MAD PASS DATA AND ARE MERGED WITH RUN 2 DATA. NO SEPARATE MAD PASS DATA ARE PRESENTED. 7. LOG AND DIGITAL DATA ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY RUN IN F-15A ON 4 SEPTEMBER 2003. THESE PDC DATA WERE PROVIDED TO SSDS BY KURT COONEY (BP) ON 3 NOVEMBER 2003. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 8. MWD RUNS 1 - 5 REPRESENT WELL F-15A WITH API#: 50-029-20651-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11226'MD/8978'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SPACING) . SEMP = SMOOTHED PHASE SPACING) . SEDP = SMOOTHED PHASE SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . SHI FT- DERIVED RESISTIVITY (SHALLOW SHIFT-DERIVED RESISTIVITY (MEDIUM SHIFT-DERIVED RESISTIVITY (DEEP $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation...... .03/12/01 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 FET RPD RPM 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9085.0 9368.5 9368.5 9368.5 STOP DEPTH 11173.5 11186.0 11186.0 11186.0 RPS RPX ROP $ . . 9368.5 9368.5 9432.0 11186.0 11186.0 11217.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9098.0 9109.0 9111.5 9115.5 9125.0 9355.0 9368.5 9373.5 9376.5 9386.0 9389.5 9401. 0 9407.5 9419.5 9424.0 9427.5 9435.0 9445.5 9450.0 9459.5 9473.5 9488.0 9501.0 9523.0 9534.0 9557.5 9561.5 9564.0 9569.0 9579.5 9590.0 9608.0 9612.5 9615.5 9629.5 9645.5 9670.0 9677.5 9705.0 971 7.0 9726.0 9737.5 9739.5 9753.0 9784.0 9813.0 9820.5 9830.5 9835.0 9877.5 9889.0 9906.5 9913.0 9921. 5 9964.0 9976.5 9993.0 9997.0 10030.0 10036.0 10046.5 10054.5 10064.0 10071.5 10079.0 10092.5 GR 9099.5 9110.0 9112.5 9116.0 9125.5 9358.0 9369.5 9374.0 9376.0 9382.5 9385.5 9395.0 9402.0 9419.0 9424.0 9427.0 9433.5 9443.5 9449.5 9458.0 9471. 5 9486.5 9499.0 9523.5 9531.0 9556.0 9561.5 9563.5 9570.0 9579.0 9588.0 9606.5 9611.0 9615.0 9628.5 9645.0 9674.5 9680.5 9705.5 9715.5 9726.5 9736.5 9740.0 9754.5 9784.0 9816.0 9822.0 9831.0 9836.5 9877.5 9887.5 9908.5 9916.5 9924.0 9971.5 9983.0 10000.0 10004.0 10037.0 10042.0 10051. 0 10059.5 10068.5 10075.5 10081. 5 10095.5 10100.5 10120.0 10123.0 10133.5 10147.5 10176.5 10189.5 10202.0 10227.0 10238.0 10244.5 10253.0 10271.0 10302.5 10312.0 10323.5 10364.5 10427.5 10452.5 10459.5 10485.5 10504.5 10524.0 10611.5 10621. 0 10635.5 10648.0 10664.0 10684.0 10701. 0 10716.5 10730.0 10764.0 10774.0 10804.0 10824.0 10828.0 10834.5 10869.5 10895.0 10912.5 10934.5 10960.0 10970.0 10979.5 10986.5 10994.0 10996.5 11022.5 11029.0 11036.0 11044.5 11053.5 11077.5 11086.0 11118.5 11123.5 11129.0 11145.5 11154.5 11164.5 11167.5 11172.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: . 10102.5 10125.0 10128.0 10137.5 10151.0 10176.0 10187.0 10201. 0 10225.0 10237.0 10244.5 10254.0 10271. 0 10304.0 10315.5 10326.0 10367.0 10430.5 10455.0 10465.0 10489.0 10509.5 10531.0 10614.0 10621.0 10635.0 10650.0 10666.0 10686.5 10706.5 10721. 0 10735.0 10769.0 10777.5 10803.5 10825.0 10829.5 10834.0 10870.5 10897.0 10918.0 10939.5 10962.0 10971. 5 10980.5 10987.5 10997.5 11000.0 11024.5 11031.0 11036.5 11046.5 11053.5 11078.5 11084.5 11119.5 11127.0 11132.0 11151.0 11160.5 11172.0 11174.5 11180.5 BIT RUN NO 1 2 3 4 5 MERGED MAIN PASS. MERGE TOP 9086.5 9482.0 9369.5 10260.0 10532.0 . MERGE BASE 9508.0 9660.0 10304.0 10574.5 11226.0 . . $ # 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-t~~e...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9085 11217.5 10151. 3 4266 9085 11217.5 ROP MWD FT/H 0.51 2514.79 102.793 3572 9432 11217.5 GR MWD API 14.8 438.2 35.0868 3730 9085 11173.5 RPX MWD OHMM 0.31 2000 9.29751 3636 9368.5 11186 RPS MWD OHMM 0.45 2000 12.9135 3636 9368.5 11186 RPM MWD OHMM 0.27 2000 14.4234 3636 9368.5 11186 RPD MWD OHMM 0.3 2000 17.2161 3636 9368.5 11186 FET MWD HOUR 0.19 20.23 3.06571 3636 9368.5 11186 First Reading For Entire File..........9085 Last Reading For Entire File...........11217.5 File Trailer Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/12/01 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/12/01 Maximum Physical Record..65535 Fil e 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 GR 2 header data for each bit run in separate files. 1 .5000 START DEPTH 9086.5 STOP DEPTH 9481.5 . ROP $ 9431. 0 9508.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR # 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 .IIN Max frames per record.............Undefined Absent value......................-999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code 30-AUG-03 Insite 4.3 Memory 9508.0 9370.0 9508.0 14.1 35.3 TOOL NUMBER 72829 4.125 .0 Flo Pro 8.60 65.0 9.5 20000 .0 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 . .0 138.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9086.5 9508 9297.25 844 9086.5 9508 ROP MWD010 FT/H 5.46 301. 42 37.352 155 9431 9508 GR MWD010 API 14.8 438.2 46.3038 338 9086.5 9481. 5 . First Reading For Entire File..........9086.5 Last Reading For Entire File...........9508 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/12/0l 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/l2/0l Maximum Physical Record..65535 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 ROP $ 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 9482.0 9508.5 STOP DEPTH 9634.0 9660.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR # 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 TERM PERATURE: MUD FILTRATE AT MT: 30-AUG-03 Insite 4.3 Memory 9660.0 9508.0 9660.0 35.3 87.1 TOOL NUMBER 72829 4.125 .0 Flo Pro 8.60 65.0 9.5 20000 .0 .000 .000 .000 .0 144.9 .0 . . MUD CAKE AT MT: .000 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....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 Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD020 MWD020 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9482 9660 9571 357 9482 9660 ROP MWD020 FT/H 0.51 719.11 74.8688 304 9508.5 9660 GR MWD020 API 18.41 155.77 40.57 305 9482 9634 First Reading For Entire File..........9482 Last Reading For Entire File...........9660 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/12/01 Maximum Physical Record..65535 Fil e Type................ LO Next File Name...........STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/12/01 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 4 header data for each bit run in separate files. 3 .5000 START DEPTH STOP DEPTH . RPS FET RPD RPX RPM GR ROP $ 9369.5 9369.5 9369.5 9369.5 9369.5 9634.5 9660.5 10272.0 10272.0 10272.0 10272.0 10272.0 10259.5 10304.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR 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: M.'\TRIX 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 . 31-AUG-03 Insite 4.3 Memory 10304.0 9660.0 10304.0 88.2 97.0 TOOL NUMBER 82758 126589 3.750 .0 Flo Pro 8.60 65.0 9.0 20000 7.6 .080 .040 .320 .210 70.0 152.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 . . RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9369.5 10304 9836.75 1870 9369.5 10304 ROP MWD030 FT/H 2.67 2514.79 123.718 1288 9660.5 10304 GR MWD030 API 18.82 149.46 36.9172 1251 9634.5 10259.5 RPX MWD030 OHMM 0.31 2000 12.1584 1806 9369.5 10272 RPS MWD030 OHMM 0.45 2000 16.6166 1806 9369.5 10272 RPM MWD030 OHMM 0.27 2000 19.0369 1806 9369.5 10272 RPD MWD030 OHMM 0.3 2000 23.2609 1806 9369.5 10272 FET MWD030 HOUR 0.19 20.23 4.77297 1806 9369.5 10272 First Reading For Entire Fi1e..........9369.5 Last Reading For Entire File...........10304 File Trailer Service name........... ..STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/12/01 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.......03/12/01 Maximum Physical Record..65535 Fi 1 e 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 RPX RPS RPM FET RPD ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 10260.0 10272.5 10272.5 10272.5 10272.5 10272.5 10304.5 STOP DEPTH 10531. 5 10544.0 10544.0 10544.0 10544.0 10544.0 10574.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 01-SEP-03 Insite 4.3 Memory 10575.0 10304.0 10575.0 86.6 . MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR 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): HUD PH: MUD CHLORIDES (PPH): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEHPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: HUD 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 Speci fication 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 96.4 TOOL NUMBER 82758 126589 3.750 .0 Flo Pro 8.60 65.0 8.5 20000 .0 .080 .040 .320 .210 Name Service Order Uni t.s Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP HWD040 FT/H 4 1 68 4 ," GR HWD040 API 4 1 68 8 3 RPX HWD040 OHMM 4 1 68 12 4 RPS HWD040 OHMM 4 1 68 16 5 RPM HWD040 OHMM 4 1 68 20 6 RPD HWD040 OHMM 4 1 68 24 7 FET HWD040 HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT HWD040 FT/H HWD040 API HWD040 OHMM HWD040 OHMM HWD040 OHMM MWDO 4 0 OHMM HWD040 HOUR Min 10260 2.26 19.99 2.2 2.17 2.23 2.83 0.24 Max 10574.5 323.59 43.95 8.13 8.07 8.34 8.91 10.41 First Reading For Entire File..........10260 Last Reading For Entire File...........10574.5 Hean 10417.3 87.2169 29.0871 4.46331 4.59222 4.74934 5.11243 1. 98787 Nsam 630 541 544 544 544 544 544 544 . 70.0 150.0 70.0 70.0 First Reading 10260 10304.5 10260 10272.5 10272.5 10272.5 10272.5 10272.5 Last Reading 10574.5 10574.5 10531.5 10544 10544 10544 10544 10544 . . File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/12/01 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.006 Physical EOF File Header Service name.............STSLIB.006 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/12/01 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.005 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 $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 10532.0 10544.5 10544.5 10544.5 10544.5 10544.5 10575.0 STOP DEPTH 11182.0 11194.5 11194.5 11194.5 11194.5 11194.5 11226.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 02-SEP-03 Insite 4.3 Memory 11226.0 10575.0 11226.0 87.6 93.6 # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 TOOL NUMBER 827 58 126589 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 .0 # 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): Flo Pro 8.60 65.0 9.0 20000 10.6 .080 68.0 . . MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .040 .210 .200 156.0 68.0 98.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O 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 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 10532 11226 10879 1389 10532 11226 ROP MWD050 FT/H 0.76 866.68 99.7937 1303 10575 11226 GR MWD050 API 17.28 64.59 30.7092 1301 10532 11182 RPX MWD050 OHMM 2.35 15.6 6.06257 1301 10544.5 11194.5 RPS MWD050 OHMM 2.37 14.85 6.12298 1301 10544.5 11194.5 RPM MWD050 OHMM 2.44 14.57 6.22719 1301 10544.5 11194.5 RPD MWD050 OHMM 3.13 14.83 6.49275 1301 10544.5 11194.5 FET MWD050 HOUR 0.2 6.92 1.10965 1301 10544.5 11194.5 First Reading For Entire Fi1e..........10532 Last Reading For Entire File...........11226 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/12/01 Maximum Physical Record. .65535 File Type................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name.............LISTPE Date.. ........... ..... ...03/12/01 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.................... .03/12/01 Origin.................. .STS Reel Name................UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.. ...............STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
