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200-102
STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMI • WELL OMPLETION OR RECOMPLETION REPO AND LOG la. Well Status: Oil 0 Gas ❑ SPLUG 0 Other ❑ Abandoned lia • Suspended 0 1b.Well Class: 20AAC 25.105 20AAC 25.110 ' Development (3 Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero • Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 9/3/2016 - 200-102 • 316-367 3. Address: 7. Date Spudded: 15. API Number: P.O.Box 196612 Anchorage,AK 99519-6612 7/25/2000 50-029-20179-01-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 7/29/2000 PBU 06-04A• Surface: 372'FSL,1114'FEL,Sec.02,T1ON,R14E,UM • 9 Ref Elevations KB 65.2 17. Field/Pool(s): Top of Productive Interval: 1258'FNL,1125'FEL,Sec.11,T1ON,R14E,UM GL 36.7 BF 35.02 • PRUDHOE BAY,PRUDHOE OIL' Total Depth: 1400'FNL,1064'FEL,Sec.11,T1ON,R14E,UM 10. Plug Back Depth(MDTTVD): 18. Property Designation: • 8940'/8657' • ADL 028311 . 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 685873 • y- 5940968 . Zone - ASP 4 . • 9540'/9218'• 72-019 TPI: x- 685904 y- 5939338 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 685968 y- 5939198 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No I I 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/ND: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) •7865'/7637'. 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 7 q MWD,GR,RES/AIT,DT/BHC,CNL,LDL,GR,Caliper,SP,MRES tot�bt FEB d 4!f a 1,7 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT FT. TOP BOTTOM TOP BOTTOM PULLED 20" 91.5# H-40 30' 110' 30' 110' 30" 260 sx Arctic Set(Approx.) 13-3/8" 72# MN-80 29' 2720' 29' 2720' 17-1/2" 6400 sx Arctic Set 9-5/8" 47# MN-80/500-95 27' 7865' 27' 7637' 12-1/4" 1000 sx Class'G',115 sx Arctic Set 7" 26# L-80 7708' 8876' 7489' 8596' 8-1/2" 235sxClass'G' 4-1/2" 12.6# L-80 8712' 9540' 8441' 9218' 6-1/8" 140 sx Class'G' 24. Open to production or injection? Yes 0 No RI 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2"12.6#13Cr80 8718' 8663'/8394' A6�N�bN 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. C1�+ry t-1'f1 EGEIVD E Was hydraulic fracturing used during completion? I. °� ` • Per 20 AAC 25.283(i)(2)attach electronic and printed Yes 0 No D 13114 SEP 2 3 2016 information •i-RlEl(:iTh DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LV ,}j, G 9050' Set CIBP '�C 9036' 8.6 Gal Cement 8940' 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 r1 Flow Tubing Casino Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(cord: Press 24 Hour Rate '`"+ Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only vrz_ le 2/7/)(.. ,4/47 RBDMS \,\J SEP 2 6 2016/: '/(7 C1 28. CORE DATA • Conventional Core(s) Yes ❑ No ® . • Sidewall Cores Yes 0 No 0 ' 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 0 • Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 9107' 8814 separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sag River 8876' 8596' Shublik 8905' 8624' Sadlerochit-Zone 4B 8990' 8704' Zone 4A 9107' 8814' Zone 3 9210' 8910' Zone 2C 9298' 8992' Zone 2B 9342' 9033' Zone 2A 9488' 9170' 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: Tempel,Joshua Email: Joshua.Tempel@bp.com Printed Name: Joe Lastuf o Title: Drilling Technologist Signature: R ene: +1 907 564 4091 Date: CW3,t(p INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 MC 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 MC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • 06-04A Well History (Pre-Rig Sidetrack) ;ACTIVMTYDI MIT-IA PASSED to 2250 psi. First 15 min. IA loss 27 psi, second 15 min. IA loss 18 psi for a total loss of 45psi in 30 min test. Bled IAP to 500 psi (4 bbls). Slickline on well upon LRS departure: SV,WV,SSV,MV= Slickline IA,OA= OTG FWHP: 8/2/2016 1570/500/70 LRS PERFORMED MIT-IA TO 2500psi (PASSED) PULLED 4-1/2" WHIDDON CATCHER @ 8679' SLM DRIFTED TO 9000' SLM WITH 20' x 3.70" DUMMY WHIPSTOCK. 8/2/2016 ***WELL LEFT SHUT IN*** ***WELL SHUT IN UPON ARRIVAL*** (SLB ELINE- MILL XN /CIBP/CEMENT DUMP/ WHIPSTOCK) INITIAL T/IA/OA= 2300/500/0 RU WELLTEC MILL 8/9/2016 ***JOB CONTINUED ON 10-AUG-2016*** T/I/0=2446/426/76 Temp=SI Assit Eline with Mill, Load and Test(CTD) Pumped 5 bbls neat followed by 41.5 bbls 1% KCI down Tbg so Eline could mill nipple. Pumped another 258.5 bbls of 1% KCL down the tbg to load. Pumped 2 bbls methanol followed by 38 bbls 8/10/2016 diesel down tbg to FP. FWHP=0/402/181 E-Line still on well upon departure. SLB ELINE - MILL XN /CIBP/CEMENT DUMP/WHIPSTOCK) RUN 1: MILLED XN NIP AT 8696' MD W/WELLTECH MILL. (MILL OD PRERUN: 3.803" POSTRUN:3.801") RUN 2: SET 4.5" BAKER CIBP AT 9050' MD. RUN 3: RIH WITH 32' (4.3 GAL) OF CEMENT DUMP BAILER AND DUMP 7' OF CEMENT ON TOP OF CIBP. RUN 4: RIH WITH 32' (4.3 GAL) OF CEMENT DUMP BAILER AND DUMP 7' OF CEMENT ON TOP OF PREVIOUS CEMENT FOR A TOTAL OF 14' (8.6 GAL). TOC: —9036' MD RUN 5: SET BAKER WHIPSTOCK W/ANCHOR. TOWS AT 8950' MD ORIENTED 24.3 DEGREES ROHS. *RA TAGS 9.04' BELOW TOWS AT 8959' MD. RA READING: 0.500 u/HR* ALL DEPTHS CORRELATED TO SLB RST-C SIGMA BORAX LOG DATED 07-MAR-2003 8/10/2016 USING GR/CCL. (SLB ELINE - MILL XN /CIBP/CEMENT DUMP/WHIPSTOCK) PULL TO SURFACE. RD E-LINE 8/11/2016 FINAL T/IA/OA=450/450/0 T/I/0=330/385/80 Temp= S/I (CTD) Pumped 36 bbls of 50* Diesel down TBG to reach test pressure. Pressure bled off immediately after shutting down. Pumped an additional 7 bbls of diesel to determine LLR of.70 bbl a min at 2400 psi. Tags hung on well. Valve positions= MV=OPEN SSV/SV/WV=CLOSED IA/OA=OTG 8/13/2016 FWHP=1100/400/81 T/I/0=35/500/0 Pre Nordic 2. Set 4" FMC ISA BPV#548.Removed Tree cap assy. Install TS#01 and XO#01 .Torqued to API Specs. PT'd 300/5000 psi for 5 min ea =PASS. Pt'd From FC Comp to SV x WV x SSV 300/3500 psi for 5 min ea =PASS. Hung BPV sign and 8/16/2016 Test record on MV RDMO ***Job Complete*** FWP= BPV/500/0 • • 06-04A Well History (Pre-Rig Sidetrack) T/I/O = BPV/380/70. Temp = SI. Bleed IA& OA to 0 psi (pre CTD). No welihouse. AL spool disconnected and blinded. IA FL @ surface, OA FL near surface. Bled IAP to bleed trailer from 380 psi to 0 psi in 30 min (all Fluid, 5 gal). Bled OAP to bleed trailer from 70 psi to 3 psi in 2 hours (gas &fluid, 15 gal). During OA bleed IAP increased 11 psi. Monitored for 30 min. IAP increased 1 psi, and OAP increased 8 psi. FWHPs = BPV/12/11. 8/18/2016 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 12:00 T/I/O = BPV/10/50. Temp = SI. WHPs (pre CTD). OAP increased 39 psi since 8/18/16. Bled OAP from 50 psi to 0 psi in 1 hr(gas/fluid, <10 gal). Monitored for 30 min. OAP unchanged. FWHP's = BPV/10/0 8/20/2016 WV, SV, SSV= C. MV= 0. IA, OA= OTG. 16:15. T/I/0 = BPV/10/22. Temp = SI. WHPs (pre CTD). IAP unchanged. OAP increased 22 psi since 8/20/16. WV, SV, SSV= C. MV= 0. IA, OA= OTG. 11:00 8/22/2016 T/IO = BPV/7/20. Temp = SI. WHPs (Pre Rig). No AL, flowline, wellhouse or scaffolding. Swab platform and ladder installed. IAP decreased 3 psi, IAP decreased 2 psi since 8-22- 16. 8/28/2016 SV, WV= ?. SSV= C. MV= 0. IA, OA= OTG. 1650 hrs. • • S North America-ALASKA-BP Page 1 e2714. Operation Summary Report Common Well Name:06-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:9/1/2016 End Date:9/9/2016 X3-017YT-C:(2,484,446.00) Project:Prudhoe Bay I Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:10/28/1975 12:00:00AM Rig Release.9/11/2016 Rig Contractor:NORDIC CALISTA LUWI:500292017900 Active datum:newrig Nabors 7ES 65.20 @65.20usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 9/1/2016 22:00 - 23:00 1.00 MOB P PRE FINISH RIGGING DOWN ANCILLARY EQUIPMENT 23:00 - 00:00 1.00 MOB P PRE PJSM WITH CREW TO MOVE OFF WELL TESTED AND VERIFIED ESD WAS FUNCTIONAL AND IS MANNED BY TOOLPUSHER -VERIFIED 12 X 12 WHEEL CHOCK IN PLACE ASSIGNED SPOTTERS TO AREA OF RESPONSIBILITY -AGREED ON STOP WAS THE COMMAND TO STOP RIG. -PERFORMED RADIO CHECK PRIOR TO MOVING RIG. -DISCUSSED WITH CREW THAT THERE WAS NO BPV INSTALLED MOVE RIG OFF WELL. SET DOWN 9/2/2016 00:00 - 06:00 6.00 MOB P PRE MOVE RIG FROM DS'2 TO DS 06 06:00 - 07:30 1.50 MOB P PRE STAGE RIG. SET MATS INTO PLACE. -PREP LOCATION FOR PULLING OVER -PJSM ON MOVING RIG OVER WELL. DISCUSS RADIO COMMUNICATION,VISUAL I HAND SIGNALS. FUNCTION TEST ESD FOR ir MOVING SYSTEM. TOOLPUSHER IN CONTROL OF ESD DURING MOVE OVER. 07:30 - 08:00 0.50 MOB P PRE MOVE RIG OVER WELL. -RIG ACCEPT AT 0800 HRS 08:00 - 15:30 7.50 MOB P PRE CONDUCT RIG UP OPERATIONS. -CYCLE VALVES PER WELL PLAN,SECURE SSV OPEN WITH FUSIBLE CAP. TEST AND PULL TREE CAP,NU BOP. -LIFT REEL ONTO RIG,PREP FOR OPS. PULL REEL ACROSS,STAB INTO INJECTOR. CHANGE OUT PACKOFFS,STAND ASIDE. -TAKE MUD INTO PITS,FLUID PACK REEL WITH FRESH WATER 1115:30 - 17:00 1.50 BOPSUR P PRE FLUID PACK BOP. CONDUCT SHELL TEST IN PREPARATION FOR BOP TEST. -LOW TEST GOOD. GO TO HIGH TEST, LOWER DOOR SEAL LEAK. -CHANGE OUT DOOR SEAL -RE-CONDUCT SHELL TEST TO 250 PSI LOW/ 4500 PSI HIGH. ALL GOOD. 17:00 - 22:30 5.50 BOPSUR P PRE TEST BOP EQUIPMENT TO 250 PSI LOW/ r 3500 PSI HIGH PER AOGCC,BP,AND NORDIC REQUIREMENTS. -TEST WITH 2-3/8"AND 3-1/2"TEST JOINTS FROM DRILLERS CONSOLE -FUNCTION ACCUMULATOR DRAWDOWN TEST FROM CTS CONSOLE -TEST REELHOUSE IRON AND INNER REEL TO 250 PSI LOW/3500 PSI HIGH -TEST WITNESSED BY AOGCC LOU GRIMALDI Printed 9/12/2016 1.37:44PM `all depths reported in Drillers Depths` • • North America-ALASKA-BP Page Operation Summary Report Common Well Name:06-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:9/1/2016 End Date:9/9/2016 X3-017YT-C:(2,484,446.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 I Spud Date/Time:10/28/1975 12:00:00AM Rig Release:9/11/2016 Rig Contractor:NORDIC CALISTA UWI:500292017900 Active datum:newrig Nabors 7ES 65.20©65.20usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) 1 (usft) 22:30 - 00:00 1.50 BOPSUR P PRE LINE UP TO PUMP SLACK BACK WHILE VALVE CREW ON THE WAY. -POPPED OFF. INSTALLED HYDRAULIC CUTTER. CUT 156 OF THE 270'NEEDED. FOUND E-LINE. -STABBED BACK ON AND VALVE CREW 'ARRIVED. TORQUED TREE BOLTS. 9/3/2016 00:00 - 01:00 1.00 BOPSUR P PRE STAB ON AND PUMP SLACK BACK AGAIN. PULL INJECTOR OFF. 01:00 - 01:20 0.33 BOPSUR P PRE PERFORM H2S/RIG EVACUATION DRILL WITH ELLINGTONS CREW. EVERYBODY MUSTERS QUICKLY. ROLL CALL QUICKLY IDENTIFIED ONE MAN NOT ACCOUNTED FOR. 01:20 - 02:00 0.67 BOPSUR P PRE CONTINUE TO CUT COIL. CUT REMAINING COIL. NO E-LINE. 02:00 - 03:00 1 1.00 BOPSUR P PRE INSTALL COIL CONNECTOR. PT COIL CONNECTOR. PULL TEST. 03:00 - 03:30 0.50 BOPSUR P PRE INSTALL NOZZLE. STAB INJECTOR AND PUMP E-LINE FORWARD. 03:30 - 04:00 0.50 BOPSUR P PRE PJSM,PT PRESSURE BULKHEAD AND REEL IRON TO 4700# 04:00 - 06:30 2.50 BOPSUR P PRE I PJSM, MOBILIZE BPV LUBRICATOR AND I TOOLS TO FLOOR STAB ON PT LUBRICATOR LOW 300#/3500# RIH. COME ONLINE WITHN TEST PUMP TO EQUALIZE BPV. 130#ON WELL. 'PULLED OUT OF HOLE WITH BPV. OFFLOAD ALL BPV EQUIPMENT. -DAY CREW CONDUCTED PRE-SPUD 06:30 - 07:45 1.25 RIGU P PRE MAKE UP UPPER QUICK CONNECT AND FLOAT SUB ASSEMBLY. PRESSURE TEST. 07:45 - 08:15 0.50 RIGU P PRE SIMULATE 50 PPM H2S IN PITS,CONDUCT 1 RIG EVACUATION DRILL. MUSTER AT PRIMARY AND SECONDARY POINTS. CONDUCT AAR,DISCUSS EVACUATION AND NOTIFICATIONS. 08:15 - 13:15 5.00 BOPSUR P PRE PJSM FOR MAKING UP NOZZLE BHA. '-MU NOZZLE BHA WITH FLOATS,RIH -FOLLOW FLUID MANAGEMENT POLICY, STAGE IN AND STRAP FLOW BACK TANK EVERY 1000' -GASEOUS RETURNS FROM 350'TO BOTTOM 13:15 - 15:30 2.25 BOPSUR P PRE ON BOTTOM,TAG WHIPSTOCK AT 8965' UNCORRECTED DEPTH I-CIRCULATE WARM KCL AROUND CHASED BY 8.75 PPG MUD SYSTEM -CIRCULATION WENT WELL. LINE UP TO MGS,CIRCULATE BOTTOMS UP. OPEN UP '1 TO WELL,NO FLOW,MUD PROPERTIES GOOD. 15:30 - 17:00 1.50 CONDHL P PRE LINE UP FOR NORMAL RETURNS,PULL TO SURFACE CIRCULATING TO PITS. MW IN 8.75 PPG,MW OUT 8.74 PPG,ONE-FOR-ONE RETURNS. POH,NO ISSUES. FLOW CHECK AT SURFACE,NO FLOW. -POP OFF WITH INJECTOR 17:00 - 17:15 0.25 CONDHL P PRE LAY DOWN NOZZLE BHA. CLEAR AND CLEAN RIG FLOOR. - - Printed 9/12/2016 1:37:44PM *all depths reported in Drillers Depths* • • • North America-ALASKA-BP Page 3 Operation Summary Report Common Well Name:06-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:9/1/2016 End Date:9/9/2016 X3-017YT-C:(2,484,446.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:10/28/1975 12:00:00AM Rig Release:9/11/2016 Rig Contractor:NORDIC CALISTA UWI:500292017900 Active datum:newrig Nabors 7ES 65.20 @65.20usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:15 - 20:45 3.50 STWHIP P WEXIT PJSM ON MAKING UP MILLING BHA. MU 3.80" MILLS TO BHI SMART TOOLS AND STRAIGHT MOTOR. -MILLS GAUGE 3.80"GO/3.79"NOGO, STRING REAMER 3.81"GO/3.80"NOGO -RIH WITH BHA#2 20:45 21:00 0.25 STWHIP P WEXIT LOG TIE IN NOT MUCH CHARACTER TO USE. RIH START MILLING. O zi _r- 21:00 " 00:00 3.00 STWHIP P WEXIT MILL 3.80"WINDOW IN 4-1/2"CASING/LINER E,f PER BAKER REP FROM 8956.7'MD TO /'� 8959.31'MD l/( ' RATE:2.82 BPM IN,2.82 BPM OUT MUD WEIGHT:8.78 PPG IN,8.75 PPG OUT -DWOB:2-3K -CIRC PRESSURE:2530-2800 PSI —CONTINUE TO TIME MILL 1 FPH. WOB AFTER 2 FT DROPPED AWAY. MILLING LIKE VERY LITTLE THERE. 9/4/2016 00:00 - 06:00 6.00 STWHIP P WEXIT MILLING WINDOW 8959.31'TO 8964' FREE SPIN=2560 PSI AT 2.80 BPM RATE IN=2.81 BPM RATE OUT=2.81 BPM MW IN=8.76 PPG MW OUT=8.75 PPG ECD =9.95 PPG ROP=1 FPH WOB=0.6-0.9 K CIRC PSI= 2620 PSI IAP=562 PSI OAP=468 PSI PVT=324 BBLS BLED IA/OA FROM 1300/500 06:00 - 09:15 3.25 STWHIP P WEXIT CONTINUE WITH MILLING OPERATION. -USE STRICT TIME DRILL CONTROL TO ENSURE THAT MILLS DO NOT MOVE QUICKLY THROUGH THE QUESTIONABLE CASING. -MILLING PARAMETERS LOOK GOOD. MILL AT CONSISTENT 2.80 BPM,2800-2900 PSI WITH WINDOW MILL OUT OF WINDOW AND STRING REAMER ACROSS TRAY AND WINDOW EXIT. WOB RANGING FROM 1.10 TO 3.10 K. -FIRST SAMPLE CIRCULATED UP FROM WINDOW HAS SIGNS OF SHUBLIK FORMATION IN IT -MILL TO 8975'MD UNCORRECTED DEPTH -MW IN 8.75 PPG,MW OUT 8.76 PPG, ONE-FOR-ONE RETURNS,ECD INCREASED FROM 9.9 PPG TO 10.15 PPG 09:15 11:30 2.25 STWHIP P WEXIT CONDUCT REAM PASSES PER WELL PLAN AND BOT REP -PUMP HI VIS PILL DOWN -REAM PASSES GOOD,NO DRAG OR MOTORWORK. CONDUCT DRY PASS,ALL GOOD. -FLOW CHECK ONCE HI-VIS PILL OUT OF MILL. NO FLOW. 11:30 - 13:15 1.75 STWHIP P WEXIT POH WITH BHA. NO ISSUES PULLING TO SURFACE. -PJSM FOR HANDLING BHAAT SURFACE. FLOW CHECK,NO FLOW AND ALL GOOD. WELL STATIC. -PULL BHA THROUGH BOP STACK. POP OFF WITH INJECTOR. Printed 9/12/2016 1:37:44PM *all depths reported in Drillers Depths" TREE= D= 4-1/16" W WH LFEACIFMC III 06-0 4A ORI L WELLBORE OT SHOWN TUBING*** ACTUATOR= BAKER C OKB.ELEV= 60' I REF ELEV= 65.2' BF.ELEV= 35.02 208T H4-1/2"FSS X NIP,U=3.813" Max Angle=- 23°@ 6905' — -42405' H FOC Datum ND= 9139' 265T —I FOC Datum TVD= 8800'SS GAS LI=T MANDRELS 13-3/8"CSG,72#,MV-80,D=12-347" H 2720' ST MD DEV TYPE VLV LATCH FORT DATE 1 3712 3712 0 TGPD DMY RK 0 08/02/16 Minimum ID = 3.801" ( 8696' - I 2 5661 5594 22 TGPD DMY RK 0 08/02/16 4-1/2" HES XN NIPPLE, MILLED y — 3 6980 6811 23 TGPD DMY RK 0 10/23/10 -I 3- 4 7639 7424 20 TGPD DMY RK 0 11/18/03 1/ 5 8328 8078 16 KBG2 DMY BK 0 11/18/03 9-5/8"X 7"ZXP LPT&MAC LNR HGR,U=6.313" H 7708' 6 8606 8340 20 KBG2 DMY BK 0 11/18/03 9-5/8"CSG,47#,WT!-80,ID=8.681" --I 7865' — 9-5/8"MLLOUT WINDOW(06-04A) 7865' X X 8663' H 7"X 4-1/2"BKR S-3 PKR,ID=3-875" ' ' 8696' —I4-1/2"I-ES XN NP,MLLED(08/10/16)ID=3.801" TOP OF 4-1/2"LNR H 8712' 8712' —7"X 5"BKR ZXP LTP w/MC LNR HGR &6'TEIBACK,O=4.438" 4-112"TBG,12.6#,13CR FOX,.0152 bpf,D=3.958" H 8718' \ 8718' !H4-1/2"WLEG,U=3958" 8733' H 5"x 4-1/2"XO,ID=3.958" 7"LNR,26#,L-80 BTC-M,-0383 bpf,ID=6.276" H 8876' , , 8940• H BKR WHPSTOCK(08/10/16) PERFORATION SUMMARY ,--- 9036' -TOP OF CEMENT CAP(08/10/16) REF LOG: BHCS ON 12/07/75 11. -------- ANGLE AT TOP PERF: 21°@ 9180' _ 9050' 4-112"BKR CEP(08/10/16) Nate:Refer to Production DB for historical perf data • 9150' H 7"MARKER JOINT 80 SPF NIERVAL Opn/Sqz DATE 3-3/8" 6 9180-9190 i 04/21/10 9193' —I4-1/2"SPECIAL CLEARANCE WRP(04/21110) 2-7/8" 6 9195-9210 r 09/11/04 ►, 2-1/2" 4 9210-9220 09/04/00 2-1/2" 4 9210-9220 12/05/03 4-1/2"LNR, 12.6#,L-80 IBTM,.0152 bpf,ID=3.958" H 9640' PB1T —I 9540' DATE REV BY CbMbEt'fS DATE REV BY COMvLNTS PRUDHOE BAY UNIT 12/19/75 PKR141 ORIGINAL COMPLETION 07/18/16 JNUJMDCORRECTED TOL DEPTH WELL: 06-04A 11/12/78 RWO 08/08/16 BSE/JWD GLV GO(08/02/16) PERIM No:"2001020 08/14/00 N7E5 SIDETRACKED(06-04A) 08/14/16 CJS/TLH PILL NIP,SET PLUG/CMTNVS(08/10/1 API No: 50-029-20179-01 03/31/11 AJ/PJC TREE C/O(03/29/11) SEC 02,T1 ON,R14E,371'FSL&1115'FEL 04/19/16 JM1 MDR FRE-RIG EDITS 07/18/16 JNUJND ADDED REF&BF ELEV BP Exploration(Alaska) • • OF T� • • op I1/j�tv THE STATE Alaska Oil and Gas �� of LAsKA Conservation Commission 333 West Seventh Avenue 1/41,51'15-L"-1711*-- GOVERNOR BILL WALKER 05VAnchorage, Alaska 99501-3572 " Main: 907.279.1433 (4 ALA4'P Fax: 907.276.7542 www.aogcc.alaska.gov John Egbejimba �f ,•-, Drilling Supervisor SCANNED FED 0 6 L.J„, BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 06-04A Permit to Drill Number: 200-102 Sundry Number: 316-367 Dear Mr. Egbejimba: 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, y /Daniel T. Seamount, Jr. Commissioner DATED this Zday of July, 2016. RBDMS Li JUL 2 7 M STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMM N APPLICATION FOR SUNDRY APPROVALS • 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill ® Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 200-102 • Exploratory 0 Development ®• 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-20179-01-00 99519-6612 Stratigraphic 0 Service ❑ 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No ® PBU 06-04A • RECEIVE() 9. Property Designation(Lease Number): 10. Field/Pools: JUL1 5 201601 ADL 028311 • PRUDHOE BAY,PRUDHOE OIL • j'�V 11. PRESENT WELL CONDITION SUMMARY ��� V Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): '"��""""' " 9540 • 9218 9193 8894 2464 9193 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 30-110 30-110 1490 470 Surface 2691 13-3/8" 29-2720 29-2720 5380 2670 Intermediate 7838 9-5/8" 27-7865 27-7637 8150/6870 5080/4760 Liner 1168 7" 7708-8876 7489-8596 7240 5410 Liner 828 4-1/2" 8712-9540 8441-9218 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9180-9220 8882-8919 4-1/2",12.6# 13Cr80 25-8718 Packers and SSSV Type: 4-1/2"BAKER S-3 PERM PACKER Packers and SSSV MD(ft)and TVD(ft): 8663/8394 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary ® Wellbore Schematic f3 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ® Exploratory 0 Stratigraphic 0 Development 13 • Service 0 14.Estimated Date for Commencing Operations: July 25,2016 15. Well Status after proposed work: . Oil 0 WINJ 0 WDSPL 0 Suspended Ii! • 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Minge,David be deviated from without prior written approval. Email David.Minge@bp.com Printed Name John Egbejimba�/ Title Drilling Supervisor Signature s y , Phone +1 Date g�� 907 564 413971 15 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: .�- 3\CZ-3�`1 Plug Integrity 0 BOP Test IS Mechanical Integrity Test ❑ Location Clearance ❑ Other: /O f•GS / fn 3 5--c)c, p 5/ �a 2'5-1' O s � flv�vr v/ar prev -lr t7,57- n o,+fFC25-. llZC1-) - f}"/fC r 1 u 'fC h) v , 1 a er-i-1 fr1 I A.PP r o V ed J) 2 Post Initial Injection MIT Req'd? Yes No I5r Spacing Exception Required? Yes 0 No 19/ -• or Req.'ed: 1 d -- 4 o APPROVED BYTHE / Approved by: / • MI - COMMISSION Date: Vac f V7'L !/1/0 1 ORIGINAL RBDMSJUL2 UV 72016 Submit Form and Attachments in Duplicate Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. • s ' To: Alaska Oil & Gas Conservation Commission From: David Minge bp CTD Engineer Date: July 14th, 2016 Re: 06-04A Sundry Approval Sundry approval is requested to plug the 06-04A perforations as part of the drilling and completion of proposed 06-04B coiled tubing sidetrack. History and current status: 06-04A is a rotary sidetrack completed in August 2000. The well is no longer competitive due to high GOR, and has no future wellwork options. The well has passed integrity and is fit for a sidetrack. Proposed plan: 06-04B will be drilled from well 06-04A by the Nordic 2 Coiled Tubing Drilling rig on or around Aug 10th, 2016. The 06-04B sidetrack will exit through the existing 4-1/2" liner and kick off in the Shublik, targeting Ivishak reserves. The proposed sidetrack is a -2,100' horizontal Ivishak producer, which will access reserves in southern DS06. The lateral will be completed with a 3-1/2" X 3-1/4"X 2-7/8" 13Cr-85 liner which will be fully cemented and perforated. This Sundry covers plugging the existing 06-04A perforations via the 06-04B liner cement job or a liner top packer set post rig with slick line if liner lap test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. e .I. 146".-7-"7440 1 V/. ,714,1 , (65x, 44)4 1,--1 ezd e35-/-f 6o✓") 7,r6,/4 w (0Iv('Yi"' r4z wel/ Qrodvcf°1 v-1i,'tti �G Gncf (,✓a�Cr GUr of N �`�-l�. Ad R�a� /J O• ti 5-0 G 1� 1 Cup. 4,. McF/3Ta Q� S rvi e q'JGQ wp✓ld /ec.gi'vr tie?", or (0111 l T�/r �� T,tr�� a�� o�✓f t. ni for G yr f lova 602 4AI 1k/A l/(91/(d � ` TO 1-e. ''4+ 11 a 6e5T �r Gr�P,�}/1G �Yl�its✓! 0'1 well ..ior (ef��(I /�!�' r ,J ?cover IOM l��� //X1,4 f �- • 0 • Pre-Rig Work(scheduled to begin July 25th, 2016) 1. S Set DGLVs. Drift for whipstock. 2. F A/SL: Load IA with crude if necessary. MIT-IA to 2500 psi. 3. E Mill XN, load tubing, set CIBP &dump bail cement. Set 4-1/2"whipstock. 4. F A/SL: Load tubing with 1% KCL and freeze protect cap. 5. F MIT-T to verify plug integrity. 6. V Pre-CTD tree work. Set TWC if CIBP failed MIT-T. V5 7. 0 Remove wellhouse and level pad. 'V art vt Rig Work(scheduled to begin Aug 10th,2016) 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (MASP 2,464 psi) 2. Mill 3.80"window and 10' of rathole. Swap well to 9.5 ppg FloPro. 1 3. Drill build: 4-1/4" OH, 410' (18 deg DLS planned). ----F 4. Drill lateral: 4-1/4" OH, 1,700' (12 deg DLS planned). 5. Run 3-1/2" x 3-1/4"X 2-7/8" 13Cr-85 liner leaving TOL at 8,686' MD. ikiCw 6. Pump primary cement job: 23.7 bbls, 15.8 ppg, TOC at TOL * p/j' 7. Perform cleanout, GR/CCL/RPM logging run 8. Perform liner lap test to 2,400 psi 9. Perforate liner based on log interpretation (-30'). 10. Freeze protect well to 2,500' MD. 11. RDMO. Post-Ri Work 1. 0 Re-install wellhouse 2. S Set 45KB liner top packer if needed * *Approved alternate plug placement per 20 AAC 25.112(i) David Minge CTD Engineer 250-2917 CC: Well File Joe Lastufka TREE= 4-1/16"CIVV WELLHEAD= FMC 0 SA NOTES' ***CHROME TUBING*** 06-04A ORIGINAL WELLBORE NOT SHOWN*** ACTUATOR; BAKER C KB.ELEV = 60' I I BF. ELEV = 37.2 2087' H4-1/2"HES X NIP, ID=3.813" KOP= ? ,,-•// 1 Max Angle= 23 @ 6905' Datum MD= 9139' — 2405' FOC Datum TVD= 8800'SS —... ---' 2657' FOC iii IL GAS LIFT MANDRELS 13-3/8"CSG, 72#, MN-80, ID=12.347" —I 2720' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3712 3712 1 TGPD DOME RK 16 03/30/11 Minimum ID = 3.725" @ 8696' 2 5661 5594 22 TGPD SO RK 20 03/30/11 4-1/2" HES XN NIPPLE p 3 6980 6811 23 TGPD DMY RK 0 10/23/10 r 4 7639 7425 20 TGPD DMY RK 0 11/18/03 5 8328 8077 16 KBG2 DMY BK 0 11/18/03 9-5/8"X 7"ZXP LPT&HMC LNR HGR. ID=6.313" — 7798' 6 8606 8341 20 KBG2 DMY BK 0 11/18/03 9-5/8"CSG,47#, MN-80, ID=8.681" H 7865' I— 9-5/8"MILLOUT WINDOW(06-04A) 7865' 8663' —7" X 4-1/2"BKR S-3 PKR,ID=3.875" ZI IX. I I 8696' —4-1/2"HES XN NIP, ID=3.725" TOP OF 4-1/2"LNR — 8706' j 8706' —7"X 5"BKR ZXP LTP w/HMC LNR HGR &6'TEIBACK,ID=4.438" 4-1/2"TBG,12.6#, 13CR FOX. .0152 bpf ID=3.958" — 8718' `--... 8718' —4-1/2"WLEG, ID=3.958" 8733' H5"x 4-1/2"XO, ID=3.958" 7"LNR,26#, L-80 BTC-M, .0383 bpf, ID=6.276" — 8876' I--A I\ • 9150' —7"MARKER JOINT. _ PERFORATION SUMMARY REF LOG: BHCS ON 12/07/75 — 9193' —14-1/2"SPECIAL CLEARANCE WRP(04/21/10) ANGLE AT TOP PERE: 21'@ 9180' Note: Refer to Production DB for historical perf data 80 SPE INTERVAL Opn/Sqz DATE 3-3/8" 6 9180-9190 0 04/21/10 2-7/8" 6 9195-9210 C 09/11/04 2-1/2" 4 9210-9220 C 09/04/00 2-1/2" 4 9210-9220 C 12/05/03 L 4-1/2"LNR, 12.64. L-80 BTC-M,.0152 bpf, ID=3.958" H 9540' 4 PBTD Id 9540' DATE REV BY COMMENTS DATE , REV BY COMMENTS PRUDHOE BAY UNIT 12/19/75 PKR 141 ORIGINAL COMPLETION 01/05/11 MM/PJC SET PXN(12/12/10) WELL: 06-04A 11/12/78 RWO 03/09/11 BSE/PJC PULL/RESET PLUG(03/08/11) PERMIT No: 2001020 08/14/00 N7ES SIDETRACKED(06-04A) 03/26/11 TAR/PJC PULL PXN(03/13/11) API No: 50-029-20179-01 10/01/09 ATD/SV CSG CORR/PKR INFO 03/31/11 WE /PJC GLV C/O(03/30/11) SEC 02,Ti ON, R14E, 371'FSL&1115'FEL 04/29/10 JGF/PJC PERFORATING(04/21/0/10) 03/31/11 AJ/PJC TREE 00(03/29/11) 10/25/10 BSEJAGR GLV C/O(10/23/10) BP Exploration(Alaska) WELLHEAD= FMC S NOTES: ***CHROME TUBING&LNR*** - - PRG ;ED �� ORIGINAL WELLBORE NOT SHOWN*** ACTUATOR= OKB-ELEV= 60' ! 0 REF �LEV��- 208T -4-1/2"HES X NP,D=3.813" TB-F. ----- ----- ELEV= 372 0 K_OP= Max Angle= _'(g7 - 2405' --I FOC Datum MD= 2657' -I FOC DntumTVD= 8800'SS , GAS LFT MANDRELS 13-3/8"CSG,72#,MN-80,D=12.347" -) 2720' ST MD ,t1; DEV TYPE VLV LATCH PORT DATE 1 3712 3712 0 TGPD DOME RK 16 03/26/16 Minimum ID = " 2 5661 5594 22 TGPD SO RK 20 03/26/16 3 6980 6811 23 TGPD DMY RK 0 10/23/10 4 7639 7424 20 TGPD DMY RK 0 11/18/03 5 8328 8078 16 KBG2 DMY BK 0 11/18/03 9-5/8"X 7'ZXP LPT&HMC LNR HGR,D=6.313" H 7708' 6 8606 8340 20 KBG2 DMY BK 0 11/18/03 9-518"CSG,47#,M4-80,D=8.681" H 7865' — 9-5/8"MILLOUT WINDOW(06-04A) 7865' 8663' H7"X 4-1/2"BKR S-3 FKR,ID=3.875" TOP OF 3-1/2"X 3-1/4'LNR H 8686' 8686' H3.70"DEPLOY SLV,D=3.00' 8696' -14-1/2"HES XN NP,D=3.725' TOP OF 4-1/2"LNR H 8706' 8706' -7"X 5"BKRZXP LIP w/HMC LNR HGR &6'TRE3ACK,ID=4.438' 4-1/2"TBG,12.6#,13CR FOX,.0152 bpf, D=3.958" H 8718' \ 8718' -I4-1/2"WLEG,D=3.958" 8733' H5"x 4-1/2"XO,ID=3.958" 7"LNR,26#,L-80 BTC-M,.0383 bpf,D=6.276" -I 8876' 3-1/2"LNR, #,L-80 STL,.0087 bpf,ID=2.992" H 8890' ----_ 8890' H3-1/2"X 3-1/4'XO,D=2.786' -1/2"MONOBORE WHIPSTOCK(XX/XX/XX) H 8944' 4-1/2"LNR,12.6#,L-80 IBTM,.0152 bpf,ID=3.958" -� -8944' 4-1/2"MLLOUT WINDOW(06-04B)_'-_' PERFORATION SU/NARY REF LOG: ON XXIXX/XX --(PUP Jr w/RA TAG ANGLE AT TOP PERF_"@' 'bte:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SOZ ' PBTD - a•' 4 3-1/4"LNR,6.';#-13-CR,.0079 bpf,D=2.85' 11057' �1' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/19/75 PKR 141 ORIGINAL COMPLETION WELL: 06-04B 11/12/78 RWO PERMT No: 08/14/00 WES SIDETRACKED(06-04A) AR Na: 50-029-20179-0.. / / CTD(06-04B) SEC 02,T1 ON,R14E,371'FSL 8 1114'FEL 04/19/16 JMD BOLT PROPOSED - BP Exploration(Alaska) • f A I I .____N 1 I 1 a u I w of< 4. . I I i 0. A I I "I . I 1 G. 1 0401 ,:,:, \\\\\\N i Q v t � 1 1 P ,111 1 F I I I C7 1 Q �' I I O J� I .. I U. i E •• I E � p I ° a rs , .. 1 p� 1 Z I n u r I O o o I = II I 1 D I I a1 1- - , \ ® < I I \ v t. v m I f U 1 To I \ U W 1 f _ \ �m9v 1 Li W�� �g o 6.w 1 UUr , z LL \ a yVn !. = I :., ., _ ' U Y \ m .1 ` I N H ' v \ ! Z o ISI s E F.. :*11� I'—, m, _ �1 f F [ �� U U N 1111 o o _ i H a f � :• i y I U _ �l i U U _ I z .I� I Z Q I I 1 E Po = I ; i8 f Z 1.3" m U „ _� is o� sx L.) I �.� E U' 1 s iE CJ I r m U 1 g U I E I "0 VQ M. I. 'x i i n • • 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 Geologists in the 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 Geologist 1> work)the initial reviewer will cross out that erroneous entry and initial then / it on both copies of the Form 10-403 (AOGCC's and operator's copies). V Instead, check the "Suspended"box and initial that change. Drilling iv Engineer .J 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 Stat Tech for 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 Stat Tech History tab 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 Stat Tech change 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 Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. P&u. ex, -c4,� P7'6 zeb i ou; Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWeIllntegrityCoordinator @bp.com] � rt3 Sent: Tuesday, June 18, 2013 10:00 PM (i To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Peltier, Megan Cc: AK, D&C DHD Well Integrity Engineer; Climer, Laurie A; AK, D&C Projects Well Integrity Engineer Subject: NOT OPERABLE: 06-04A(PTD#2001020) IA over MOASP All, ✓ Producer 06-04A(PTD#2001020) IA went over MOASP on 06/18/2013 with TBG/IA/OA= 1264/2200/200 psi.At this time,the Drillsite is shut in for maintenance.The well has been reclassified as Not Operable until the well can be brought back online for further diagnostics. Plan Forward: 1. Ops: Bring well back online Under Evaluation 2. DHD:TIFL A wellbore schematic and TIO p lot have been included for reference. 06-04A wellbore 06-04110 plot 5C? — Z23:1,5, schematic.pdf 06-18-13.docx Alyce 6 7t.)p J` Thanks, SCANNED FEB 2 0 2014 ` o p Laurie Climer (Alternate. Jac/ 1)/shrmi-) BP Alaska - Well Integrity Coordinator G7 � WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator @BP.com 1 kR a F1ss8§1 I T I M L I 0 3 .?s 0 CT. H a) o I- co d 0 0 c c) N co 0 aa (0 co -- WELLHEAD TREE= = 4-1/16'FMIC 06-04A ORIG�,ALWELLBOR NOTn HOWN* *** ACTUATOR= BAKER C KB.ELEV= 60' I - I BF.ELEV= 37.2' , 2087' H4-1/2"HES X NIP, ID=3.813" I KOP= ? 0 Max Angle= 23 @ 6905' Datum MD= 9139' 2405' FOC Datum TVD= 8800'SS 2657' FOC 13-3/8"CSG,72#,MN-80, ID=12.347" —I 2720' li L. GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3712 3712 1 TGPD DOME RK 16 03/30/11 Minimum ID = 3.725" @ 8696' 1 2 5661 5594 22 TGPD SO RK 20 03/30/11 4-1/2" HES XN NIPPLE y ,: 3 6980 6811 23 TGPD DMY RK 0 10/23/10 4 7639 7425 20 TGPD DMY RK 0 11/18/03 5 8328 8077 16 KBG2 DMY BK 0 11/18/03 9-5/8"X 7"ZXP LPT&HMC LNR HGR,ID=6.313" I 7708' 6 8606 8341 20 KBG2 DMY BK 0 11/18/03 9-5/8"CSG,47#,MN-80, ID=8.681" —I 7865' I-- 9-5/8"MILLOUT WINDOW(06-04A) 7865' )4.144f:-.. 67V, .-; g-- 8663' H7"X 4-1/2"BKR S-3 PKR,ID=3.875" ' , 8696' H4-1/2"HES XN NIP, ID=3.725" I TOP OF 4-1/2"LNR J 8706' 8706' I 7"X 5"BKR ZXP LTP w/HMC LNR HGR &6'TEIBA CK,ID-4.438" 4-1/2"TBG,12.6#, 13CR FOX, .0152 bpf, ID=3.958" J I 8718' 4-1/2"WLEG.ID=3.958"\ 8718' 8733' I--I 5"x 4-1/2"XO, ID=3.958" I 7"LNR,26#, L-80 BTC-M, .0383 bpf, ID=6.276" —I 8876' I—'_ • 9150' I--17"MARKER JOINT I PERFORATION SUMMARY REF LOG: BHCS ON 12/07/75 _.. ANGLE ATTOPPERF: 21°@ 9180' ►� 9193' H4-1/2"SPECIAL CLEARANCE WRP(04/21/10) I Note: Refer to Production DB for historical perf data 80 SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9180-9190 0 04/21/10 2-7/8" 6 9195-9210 C 09/11/04 2-1/2" 4 9210-9220 C 09/04/00 2-1/2" 4 9210-9220 C 12/05/03 4-1/2"LNR, 12.6#, L-80 BTC-M, .0152 bpf, ID=3.958" --I 9540' I Al I. I PBTD I--I 9540' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/19/75 PKR 141 ORIGINAL COMPLETION 01/05/11 MM/PJC SET PXN(12/12/10) WELL: 06-04A 11/12/78 RWO 03/09/11 BSE/PJC PULL/RESET PLUG(03/08/11) PERMIT No:"2001020 08/14/00 N7ES SIDETRACKED(06-04A) 03/26/11' TAR/PJC PULL PXN(03/13/11) API No: 50-029-20179-01 10/01/09 ATD/SV CSG CORR/PKR INFO 03/31/11 WEC/PJC GLV C/O(03/30/11) SEC 02,T1 ON,R14E,371'FSL&1115'FEL 04/29/10 JGF/PJC PERFORATING(04/21/0/10) 03/31/11 AJ/PJC TREE C/O(03/29/11) 10/25/10 BSE/AGR GLV C/O(10/23/10) BP Exploration (Alaska) Producers with Sustained Casing Press, on IA During TAR • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator@bp.com] /2...51'( Sent: Monday, August 15, 2011 5:14 PM ' `q To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS FS3 Ops Lead; AK, OPS FS3 OSM; Cismoski, Doug A; Daniel, Ryan Cc: Walker, Greg (D &C); Stechauner, Bernhard; Lee, Timothy; Reynolds, Charles (ALASKA) Subject: Producers with Sustained Casing Pressure on IA During TAR All, The following producers were found to have sustained casing pressure on the IA during shut down for turnaround activity. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repTegStinz. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 06 -04A PTD #2001020 06 -14B (PTD #2090120)` '" � /F � 15 -36B (PTD #2060730) All the wells listed above will be classified as Not Operable until start -up operations commence and are stable or the well passes a pressure test proving integrity. After start -up, the wells will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com 8/25/2011 OPERABLE: Producer 06 -04A (PTD Regg, James B (DOA) 001020) Tubing integrity restored • Page 1 of 2 From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] � Sent: Sunday, October 24, 2010 4:57 PM 1 To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS FS3 Ops Lead; AK, OPS FS3 OSM; Cismoski, Doug A; Engel, Harry R; Stechauner, Bernhard Cc: Holt, Ryan P (ASRC); King, Whitney Subject: OPERABLE: Producer 06 -04A (PTD #2001020) Tubing integrity restored All, Producer 06 -04A (PTD #2001020) pass an M ITIA after dum gas lift valves were set. The passing test verifies that tubin integrity has been resto red. The well has been reclassified as Operable and may be placed on production when convenient for operations. Please be careful when placing the well on production as the IA is fluid packed. Thank you Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 `(1�? N OV Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Monday, October 18, 2010 11:07 AM To: 'Maunder, Thomas E (DOA)'; "Schwartz, Guy (DOA'; 'Regg, James B (DOA)'; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS FS3 Ops Lead; AK, OPS FS3 OSM; Cismoski, Doug A; Engel, Harry R; Stechauner, Bernhard Cc: Roschinger, Torin T.; Holt, Ryan P (ASRC); Quy, Tiffany Subject: UNDER EVALUATION: Producer 06 -04A (PTD #2001020) TIFL Failed All, Well 06 -04A (PTD #2001020) has been found to have sus tained casing pressure on the IA . The wellhead pressures were Tubing /IA/OA equal to 473/ on 10/16/2010. The well failed a TIFL on 10/17/2010 confirming tubing integrity is compromised. The well has been reclassified as Under Evaluation and may continue to be produced under a 28 -day clock while efforts to mitigate the communication are completed. The plan forward is: 1. DHD: TIFL - FAILED 2. Slickline: Set DGLVs 3. Pumping: MITIA to 3000 psi; LLR if fails 4. Slickline: Reset live GLVs if MIT -IA passes A TIO Plot and wellbore schematic have been included for reference. << File: 06- 04A.pdf >> << File: 06 -04A 10 -18 -10 TIO.doc >> 11/1/2010 OPERABLE: Producer 06 -04A (PTD .42001020) Tubing integrity restored • Page 2 of 2 Thank you, Mehreen Vazir (for the Well Integrity Coordinator Torin Roschinger /Gerald Murphy) Projects Well Integrity Engineer BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWellintegrityCoordinator @bp.com 11/1/2010 PBU 06 -04A PTD 2001020 10/18/2010 TIO Pressures Plot 06 -04 T10 Plot 4,000 3,000 —0 - Tbg —E -- IA 2,000 —A OA OOA �r~ OOOA On 1,000 • 10.X23, 11/28/09 12/29/09 01/29/10 03/01/10 04/01/10 05!02/10 06102/10 07/03/10 08/03/10 0/03/10 10/04/10 WE L L HEAD= FMC 06-04A SA ES: * * * CHROME TUBING '' ACTUATOR = FMC AXEL OLD STYLE KB. ELEV = 65.2' BF. ELEV = 372 2087` 4 -1/2" HES X NIP, ID = 3.813" KOP= _? Max Angle = 23 @ 6905' Datum MD = 9139' , Datum ND = 8800' SS 2405 FOC 2657' FOC 13 -3/8" CSG, 72 #, MN -80, ID = 12.347" 2720` GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 1 3712 3712 1 TGPD DOME RK 16 12/02/03 2 5661 5594 22 TGPD DOME RK 16 12/02/03 3 6980 6811 23 TGPD SO RK 24 12102/03 4 7639 7425 20 TGPD DMY RK 0 11/18/03 TOP OF 7" LNR 7708' 5 8328 8077 16 KBG2 DMY BK 0 11/18/03 6 1860 6 8341 20 IKBG2 DMY I BK 1 0 11/18/03 9 -5/8" CSG, 47 #, MN -80, ID = 8.681" 7866 9 -5/8" MILLOUT WINDOW (06 -04A) 7865' 8663` 4 -1/2" BKR S -3 PKR, ID = 3.875" Minimum ID = 3.725" @ 8696' 4 -1/2" HES XN NIPPLE $686` 4 -1/2" HES XN NIP, I = 3.725" 4 -1/2" TBG,12.6 #, 13 -CR, .0152 bpf, ID = 3.958" 8717" 8706' 7 "X 5" BKR ZXP LNP w / HMC LNR HGR & 6' TEIBACK, ID = 4.438" $717' 4 -1/2" WLEG, ID = 3.95 8733' _ 5" x 4 -1/ XO, ID = 3. 7" LNR, 26 #, L-80-0383 bpf, ID : - - 672 - 76 - 1 — [: !8Z6` PERFORATION SUMMARY REF LOG: BHCS ON 12/07/75 9193' 4-1/2" SPECIAL CLEARANCE WRP (04121/1 -) ANGLE AT TOP PERF: 21'@9180' Note: Refer to Production DB for historical perf data 80 SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 9180-9190 O 04/21/10 2 -7/8" 6 9195-9210 C 09/11/04 2 -1/2" 4 9210-9220 C 09/04/00 2 -1/2" 4 9210-9220 C 12/05/03 4 -1l2" LNR, 12.6 #, L-80_0152 bpf, ID = 3.958" 95q.0' PBTD 9540 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/19/75 P141 ORIGINAL COMPLETION WELL: 06 -04A 11112/78 WORKOVER PERMIT No: 2001020 08/14/00 SIDETRACKED (06 -04A) API No: 50- 029 - 20179 -01 10/01/09 ATD /SV CSG CORR / PKR INFO 5EC 11, T10N, R14E, 1444.31' FEL & 1299.77' FNL 04/29/10 JGF /PJC I PERFORATING (04/21/0/10) SP Exploration (Alaska) JL- STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS '~EC~IVE~ APR ~ ~ 2010 1. Operations Abandon ^ Repair Well ^ Plug Perforations y~/IC Stimulate ^ Other Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extens ~&~21SG~S.Iff1t33 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 Q Exploratory ^ 200-1020 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorage, AK 99519-6612 50-029-20179-01-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number ~ ADLO-028311 PBU 06-04A 10. Field/Pool(s): PR DH U OE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 9540 feet Plugs (measured) 9191' 4/21/10 feet true vertical 9218.5 feet Junk (measured) None feet Effective Depth measured 9540 feet Packer (measured) 8663 8717 true vertical 9218.5 feet (true vertical) 8394 8446 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 29 - 109 29 - 109 1490 470 Surface 2687 13-3/8" 72# MN-80 28 - 2715 28 - 2715 5380 2670 Production 2373 9-5/8" 47# S000-95 27 - 2400 27 - 2400 8150 5080 Production 5460 9-5/8"47# N-80 2400 - 7860 2400 - 7633 6870 4760 Liner 1168 7"26# L-80 7713 - 8881 7494 - 8601 7240 5410 Liner 828 4-1/2" 12.6# L-80 8717 - 9548 8446 - 9223 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 25 - 8718 25 -8446 Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer 8663 8394 4-1/2" Too Packer 8717. 8446 12. Stimulation or cement squeeze summary: Intervals treated (measured): } ` ~ J 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: 414 26491 7770 320 Subsequent to operation: 396 24659 7875 275 14. Attachments: 'f~ Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development Q Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre a Title Data Management Engineer Signature Phone 564-4944 Date 4/26!2010 Dft .,,,,, ,.,-~„~~.,,~,. „~,,,,'titiUR7~A1'K ~ ~ EUNl~ ~i Jr j~~~~~y O 4'LpJ~ ,> 06-04A 200-102 PERF ATT~4CHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 06-04A 9/4/00 PER 9,210. 9,220. 8,910.12 8,919.44 06-04A 11/27/03 SQZ 9,210. 9,220. 8,910.12 8,919.44 06-04A 12/5/03 RPF 9,210. 9,220. 8,910.12 8,919.44 06-04A 9/11/04 APF 9,195. 9,210. 8,896.14 8,910.12 06-04A 4121/10 APF 9,180. 9,190. 8,882.16 8,891.48 06-04A 4/21/10 BPS 9,191. 9,195. 8,892.42 8,896.14 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 • 06-04A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/20/2010 ""` WELL SI ON ARRIVAL"""* (E-LINE PERFORATING AND WRP SETTING) INITIAL T/I/O = 1900/1900/640. FLOWING WELL BECAUSE SWAB VALVE CANNOT HOLD PRESSURE FROM' ABOVE (1900 PSI MAXIMUM) t"""CONTINUED ON 21-APRIL-2010"*" 4/21 /2010 i *** CONTINUED FROM 20-APR-2010"""" (E-LINE PERFORATING AND WRP SETTING) INITIAL T/I/O = 1900/1900/640. FLOWING WELL BECAUSE SWAB VALVE CANNOT HOLD PRESSURE FROM ABOVE (1900 PSI MAXIMUM) PERFORATE: 9180' - 9190' W/ 3-3/8" PJ, 6 SPF, 60 DEG S ERFORD 4-1/2" SPECIAL CLEARANCE WRP WITH MID ELEMENT AT 9192.5'. 3.69" PLUG O POST SET, 1.90' PLUG TOP-ME. CCL TO MID ELEMENT: 14.5' CCL STOP DEPTH: 9178' TOP OF PLUG AT 9190.5' FINAL T/I/O: 210/(1900 ON GAS LIFT)/620 PSI. ***JOB COMPLETE*"" FLUIDS PUMPED BBLS 2 diesel 1 meth 3 Total TREE _ ? WELLH~AD= FMC ACTUATOR = FMC AXEL OLD STYLE KB. ELEV = 65.2' BF. ELEV = 37.2' KOP= ? Max Angle = 23 @ 6905' Datum MD = 9139' Datum TVD = 8800' SS 13-3/8" CSG, 72#, MN-80, ID = 12.347" ~~ 2720' (TOP OF 7" LNR I-) 7708, 9-518" CSG, 47#, MN-80, ID = 8.681" 7$65' Minimum ID = 3.725" @ 8696' XN Nipple 4-1/2" TBG,12.6#, 13-CR, .0152 bpf, ID = 3.958" ~-{ 8717' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" (-I $876' PERFORATION SUMMARY REF LOG: BRCS ON 12107!75 ANGLE AT TOP PERF: 21 @ 9195' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-718" 6 9195 - 9210 O 09/11/04 2-1/2" 4 9210 - 9220 O 09104!00 2-112" 4 9210 - 9220 O 12/05/03 ~ 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ PBTD I~ 9540' ~~ DATE REV BY COMMENTS DATE REV BY COMMENTS 12/19/75 P 141 ORIGINAL COMPLETION 11/23/03 MWPAG GLV C/O 11/72/78 WORKOVER 12/2-5/03 MA/JM/T GLV C/O, REI'ERF 08/14/00 SIDETRACK® (OB-04A) 09/11/04 LOK/TLP ADD PERFS 02!21!01 MWtp CORRECTIONS 10/16/04 GRC/TLH BF ELEV CORRECTION 05/09(02 CAO/KK MAX ANGLE CORRECTION 10/01/09 ATD/SV CSG CORR J PKR INFO 06/12/03 CMO/TLP KB ELEVATION CORRECTION PRUDHOE BAY UNIT WELL: 06-04A PERMIT No: 2001020 API No: 50-029-20179-01 SEC 11, T10N, R14E, 1444.31' FEL & 1299.77' FNL BP Exploration (Alaska) 2087' ~--~ 4-1 /2" X NIP, ID = 3.813" 2405' FOC 2657' FOCI GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3712 3712 1 TGPD DOME RK 16 12/02!03 2 5661 5594 22 TGPD DOME RK 16 12/02(03 3 6980 6811 23 TGPD SO RK 24 12/02/03 4 7639 7425 20 TGPD DMY RK 0 11/18/03 5 8328 8077 16 KBG2 DMY BK 0 11118/03 6 8606 8341 20 KBG2 DMY BK 0 11!18!03 9-5/8" MILLOUT WINDOW 7865' $663` 4-1/2" BKR S-3 PKR, ID = 3.875" $6Q$' 4-1/2" XN NIP, ID = 3.725" $706` 7" X 5" BKR ZXP LT PKR W ! HMC LNR HGR & 6' TIEBACK ID = 4.438" $717' 4-112" WLEG $733' 5" x 4-1/2" XO, ID = 3.958" BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ~,,;~~; ,~~I~ 70 333 West 7th Avenue Anchorage, Alaska 99501 ~Q Q .. f ~ ~.- Subject: Corrosion Inhibitor Treatments of GPB DS 06 D ~ .~ Q ~ I"'! Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 06 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-06 Date: 12/10/09 l Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 06-01 1750490 50029201720000 NA Sealed NA os-o2 1770780 50029202820000 NA Sealed NA o6-o3A 1951520 50029201860100 NA Sealed NA os-04A 2001020 50029201790100 NA Sealed NA os-o5 1780200 50029202980000 NA Sealed NA o6-o6B 2050980 50029202010200 NA Sealed NA os-o7 1780210 50029202990000 NA Sealed NA os-o8A 1951950 50029203000100 NA Sealed NA 06-09 1790730 50029204000000 NA Sealed NA o6-10A 1981960 50029204020100 NA Sealed NA os-11 1791100 50029204280000 NA Sealed NA 06-12A 1920640 50029204560100 NA 0.5 NA 3.40 10/6/2009 06-13A 2061020 50029204570100 NA Sealed NA os-148 2090120 50029204580200 NA Sealed NA 06-15 1800320 50029204590000 NA Sealed NA 06-16 1800330 50029204600000 NA Sealed NA 06-18A 2090630 50029207670100 NA 0.3 NA 1.70 11/5/2009 06-19A 2081020 50029207910100 NA 1.5 NA 6.80 10/4/2009 os-2oA 2050790 5oo2s2o7ssoloo NA 1 NA 5.10 1o/a/zoos 06-21 B 2080990 50029208020200 NA 6 NA 42.50 12/14/2009 06-22A 1930570 50029208060100 NA 1.5 NA 5.10 10/4/2009 06-23C 2080920 50029208080300 NA 4.6 NA 30.60 10/6/2009 06-24A 2000960 50029208220100 NA Sealed NA Scblumberger NO. 5353 Alaska Data & Consulting Services 2525 Gambell Sireel, Suite 400 ~~ ^ /~ ~ ~ , /- /] Company: ly j'~' State of Alaska Naska Oil & Gas Cons Comm Mchorage, AK 98503-2B3B ~~ O~ / / O ~ Attn• Christine Mahnken ATTN: eeth ~ ~v 333 West 7th Ave, Suite 100 Mchorage, AK 99501 Well Job # Log Description Date BL Color CD V-02 W-26A H-32 82WY-00018 BiJJ-00033 ANHY-00102 MEM PRODUCTION PROFILE ` MEM PRODUCTION PROFILE - - PRODUCTION PROFILE ~ G- 07l27/09 07/26/09 07M5/09 1 1 1 1 1 ~ P2-29 L2-11 L2-06 AYTU-00052 ANHY-00106 B69K-00007 INJECTION PROFILE " ~'~ -~ LDL CROSS FL W CHECK 08/0?J09 08/02/08 07/31/09 1 1 1 1 ~ ~ P2•28 L-213 V-221 AYTU-00051 B2WY-00019 AXBD-00037 INJECTION PqOflLE L-~ MEM INJECTION PROFI E' - MEM INJECTION PROFILE' - 08/01/09 07l29/09 07/28/09 1 1 1 7 ~ 7 L-220 07-22 04-02A B1JJ-00035 AZCM-00036 AYS4-D0091 MEM INJECTION PROFILE - PRODUCTION PROFIIE - - ' USIT 07/30l09 08/09/09 08/71/09 1 1 ~ 1 ~ ~ J-11A L1-09 X-28 AWLB-00029 AYS4-OD089 AXBD-00026 USIT PHODU TION PROFILE ',~ MEM INJECTION PROFILE U - 08/05/09 08/08/09 OS/77/09 1 1 > > 1 1 L2-O6 83S~-00020 PRODUCTION PROPILE ! 08/14/09 1 ~ 3-29/J-32 06-04A 75-498 AP3~-00055 BSJN-00009 B2NJ-00013 IBP SET RECORD W/CROSSGIOW - RST - MCNI - 0&08/09 08l23l09 07/15/09 1 1- 1 ~ ~ ~ 03-328 09AKA0030 OH MWD/LWD EDIT _ 02/28l09 2 ~ G•148 AWJI-00043 MCNL - 07/2M09 1 ~ L2-13A AWJI-00036 MCNL OW77/09 ~ 18-028 AWJI-00045 MCNL G~ - V ~ 08/17/09 1 1 Pi-OS AWLB-00032 RST 08/09/09 1 ~ B-16A 82WY-00020 MCNL ' - 08/03/09 1 ~ J-20B AXB0.00020 MCNI (REVISED) ~- ~ ~ r ,"C OM12/09 ~ PLEASE ACKNOWLEDGF [iFC F~a7 wv si~:uiu r eun ncruo.u.~r_ nue n...,.. ~..... r... BP Exploration (Alaska) Inc. Petrotechnical Dala Center LR2-1 900 E. Benson Blvd. Alaska Oata & Consulling Services 2525 Gambell Slrbet, Suile 400 Mchoraga, AK 99503-2838 09/11/09 j ~' .... ~ %i i~ ~_a ~ `~ ~~ t;f; .,, a ., ~~..... , . _ ~'~,~~FIL ~`~ a~-~/ Schlumberger NO. 4260 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 90(]-10;). * l5194 Field: Prudhoe Bay B CI CD Well Job# Log Description Date L o or 03-36 10831325 CH EDIT PDC GR 08/11/04 1 MPL-40 98160 OH EDIT MWD/LWD (REVISED) 03/05/98 4 1 L2-18A 11421036 RST 10/14/06 1 1 A-04 11221855 RST 03/22106 1 1 06-04A 11320998 RST 08/02/06 1 1 C-24A 11209609 MCNL 06/19/06 1 1 P2-57 A 10831796 RST 04/29/06 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SCANNED MAY 1 7 2007 Date Delivered: lVi' A\I -':,,1. I II ,Ü Received by: ZOOl 1- 05/15/07 . . F:\LaserFiche\CvrPgs _I nserts\M icrofi 1m _Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ~I" ...~~.¡.1t. ) ) 06-04A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/08/04 *** CONT FROM WSR 9-07-04 ****( ADD PREF). RUN 2-7/8 DUMMY GUN TO 9505' SLM ( NO BASE FLAGE INFO TO CORRECT TO). NOTIFIED DSO. *** LEAVE WELL SHUT-IN *** 09/11/04 Perforate 9195'-9210' 6 SPF FLUIDS PUMPED BBlS : TOTAL No Fluids Pumped 0 Page 1 --- WElLHE'AD = FMC AClUATOR= FMCAXEL OLDSlYLE KB. ELBI = 65.2' BF. ELEV = :iI. ?:l KOP= ? Wax Angle - 23 @ 6905' Datum MD - 9139' DatumlVD= 8800' SS 06-04A I SAFElY NOTES: CHROME TUBING lREE= ? . 208T 4-1/2" X NP, D = 3.813" 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 7708' ST MD TVD 1 3712 3712 2 5661 5594 3 6980 6811 4 7639 7425 5 8328 8077 6 8606 8341 GAS LFT \¡\ð,NDRELS DEV lYÆ VLV LATCH 1 TGFO DOME RK 22 TGFO DOME RK 23 TGFO S/O RK 20 TGFO DMY RK 16 KBG2 DMY BK 20 KBG2 DMY BK PORT DATE 16 12/2/03 16 12/2/03 24 12/2/03 0 11/18103 0 11/18103 0 11/18103 9-5/8" CSG, 47#, MN-80, D = 8.681" I . MLLOUT WINDOW 7865' Minimum ID = 3.725" @ 8696' XN Nipple 8663' BAKER S-3 PKR 8696' 4-1/2" XN NIP, ID = 3.725" 8717' H 4-1/2" WLEG 4-1/2"TBG,12.6#, 13-CR .0152bpf, ID=3.958" 8717' 8876' PERFORATION SUMMARY REF LOG: BHCS ON 12¡Q7/75 ANGLE AT TOP PERF: 21 @ 9195' Note: Refer to Production DB for historcal perf data SIZE SPF INTERV AL Opn/Sqz Oð. TE 2- 7/f!' 6 9195- 9210 0 09111/04 2-1/Z' 4 9210- 9220 0 09104/00 2-1/Z' 4 9210- 9220 12/05103 4-1/Z' LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 9540' Oð. TE RBI BY COMMENTS DATE REV BY COMMENTS 12/19175 ORIGINAL COMPLEIlON 11/23/03 MH/PAG GLV C/O 11/12/78 WORKOVER 12/2-5/03 \¡\ð,/JMfTF GL V C/O, REPERF 08114/00 SIŒTRACKED (06.04A\ 09/11/04 LDKlTLP ADD PERFS 02/21/01 MH/1p CORRECllONS 05109102 CAOA<K MAX ANGLE CORRECTON 06112/03 CMOITLP KB ELEV A TION CORRECTION PRUDHOE BAY UNIT WElL: 06-04A PERMIT No: 2001020 API No: 50-029-20179-01 SEC11, T10N, R14E, 1444.31' FEL& 1299.77'FNL BP Exploration (Alas ka) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Suspend D Repair WellD Pull Tubing D Operation Shutdown D Plug PerforationsŒ] Perforate New Pool D 4. Current Well Class: Perforate ŒJ WaiverD Stimulate D Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 200-1020 OtherD Name: BP Exploration (Alaska), Inc. Development Œ] 65.20 8. Property Designation: ADL-0028311 11. Present Well Condition Summary: Stratigraphic D 9. Well Name and Number: 06-04A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Exploratory D Service D 6. API Number 50-029-20179-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 9540 feet true vertical 9218.5 feet Plugs (measured) Junk (measured) None Effective Depth measured 9540 feet None true vertical 9218.5 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 29 109 29.0 - 109.0 1490 470 Liner 1168 7" 26# L-80 7713 - 8881 7494.1 - 8601.0 7240 5410 Liner 828 4-112" 12.6# L-80 8717 - 9545 8445.5 - 9223.2 8430 7500 Production 2373 9-5/8" 47# SOO-95 27 - 2400 27.0 - 2400.0 8150 5080 Measured depth: 9210 - 9220 True vertical depth: 8910.12 - 8919.44 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 25 8718 {'; ,; t: :~ MAR 1 0 20H:; Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 4-1/2" Liner Top Packer @ 8663 @ 8717 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: AI~':JŒ 0:1 8l C Oll;~; C IJ~T;(;ir';!;¡on 13' Prior to well operation: Subsequent to operation: Oil-Bbl I Gas-Mef I Water-Bbl Casing Pressure Tubing Pressure 47 I 1.5 I 7168 1950 244 Well Shut-in 940 596 ReDresentative Dailv Averaae Production or Iniection Data 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ] ServiceD Copies of Logs and Surveys run- 16. Well Status after proposed work: Operational Shutdown D OilŒ] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations. ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature Title Production Technical Assistant Phone 564-4657 Date 3/9/04 8CJìNNED MAR 12 200,~ ~IGINAL BFl -- A. .t 1œ~ Form 1 0-404 Revised 12/2003 06-04A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/17103 DRIFT WI 3.70 CENTRALIZER, SAMPLE BAILER. LOCATE XN NIPPLE @ 8668'. CORR. FACTOR = +25'. TAG TAG BTM 9423' +23 = 9448' CORR. DEPTH. 11/17103 DRIFT WI 3.70 CENTRALIZER, SAMPLE BAILER. LOCATE XN NIPPLE @ 8668'. CORR. FACTOR = +25'. TAG TAG BTM 9423' +23 = 9448' CORR. DEPTH. PERFS; 9210-9220. (228' OF RAT HOLE) SET 4 1/2" WHIDDON CATCHER SUB @ 8668' SLMD. SET DOWN @ STA#5. PULL 1" DGLV FROM STA 5. PULL 1", 5/16" PORT S/O VALVE FROM STA. #6.8606 MD. PULL 11/2" DOME FROM STA. # 4.1/4" PORT, TRO = 1700. ***CONTINUED ON 11/18/03 WSR*** 11/18/03 PULL STA. # 2. 1 1/2" DOME, 1/4" PORT, 1713 TRO. RK LATCH. 5661 MD. PULL STA. # 1.1 1/2" DOME, 1/4" PORT, 1715 TRO. RK LATCH. 3712 MD. SET 1 1/2" DGLV STA. # 1. RK. LATCH. 3712 MD. SET 1 1/2" DGLV STA. # 2. RK. LATCH. 5661 MD. SET 1 1/2" DGLV STA. # 4. RK. LATCH. 7639 MD. SET 1" DGLV STA # 5. BK LATCH. 8328 MD. SET 1" DGLV STA # 6. BK LATCH 8606 MD. LRS MITIA TO 3000 PSI (PASSED) WELL LEFT SHUT IN TURNED OVER TO DSO. 11/18/03 TI0=1950/1850/880---LOAD IA WI 484 BBLS CRUDEI MIT IA TO 3000 PSI---PASS---IA LOST 120 PSI IN 15 MIN WI TOTAL LOSS OF 160 PSI---FINAL WHP'S=70010/900. FREEZE PROTECT TBG & FL 11/25/03 CEMENT SQUEEZE I CTU #5 - BOP TEST GOOD. RIH WITH 2.5" BDJSN - TAG TD AT 9429' CTM. CORRECT TO 94481. KilL WELL WITH 1 % KCL. INJECTIVITY GOT UP TO 5.1 BPM @ 2000 PSI WHP. AFTER Kill VOLUME PUMPED - INJECTIVITY 4.9 BPM AT 950 PSI. LOAD DIESEL DOWN BACKSIDE. PUMP 46 BBLS LARC WIO AGGREGATE. MAYBE 1 BBL BEHIND PIPE. PUH TO SAFETY, TAKE SQZ UP TO 2000 PSI WHP. JFT PUMP BIOZAN AND CONTAMINATE TO TO. SQUEEZE BROKE DOWN AND WELL WENT ON A VACUUM. POOH, CIRCULATING. RIH WITH 2.5" JSN TO TO, CIRCULATING OHLE CLEAN, GOOD RETURNS TO TANK. CONDUCT INJECTIVITY TEST. 1180 PSI AT 3.3 BPM. ACIDIZE PERFS WITH 50 BBlS 12% DAD ACID. PERFS BROKE DOWN IMMEDIATELY AS ACID ENTERED. WELL WENT ON VAC. OVERFLUSHED WITH 1% KCL. POOH. FREEZE PROTECT WELL WITH DIESEL, FINAL INJECTIVITY = 5 BPM @ 1090 PSI WHP. NOTIFY DSO OF WELL STATUS. RDMO. 11/27103 CEMENT SQUEEZE I CTU #5. MIRU. RIH WITH 2.5" BDJSN. KILL WELL WITH 1% KCL. TAG TO, CORRECT TO 9448'. FLAG PIPE AT 9438'. LOAD BACKSIDE WITH 104 BBLS DIESEL. MIX CEMENT. PUMP 30 BBLS OF 15% HCL FOLLOWED BY 100 BBLS OF 1% KCL OVERFLUSH TO PERFS. PUMPED 41 BBLS OF NEET LARC CEMENT FOLLOWED BY 39 BBLS OF LARC WITH 15 PPB AGGREGATE. SQUEEZED AN ESTIMATED 42 TO 44 BBlS CEMENT BEHIND PIPE AT WELLHEAD PRESSURES UP TO 3000 PSIG. RBIH CONTAMINATING REMAINING CEMENT WITH 133 BBLS BIOZAN. LAY IN 6 BBLS TEA ACROSS PERFS. POOH JETTING AT 80%. WASH JEWELRY. FP WELL TO 2500' WITH 60/40 METHONAL. TRAP 500 PSIG WHP. WELL TO REMAIN SHUT IN FOR 3 DAYS. Page 1 06-04A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 12/01/03 DRIFT WI 2.5011 0- GUN & S- BLR TO 94241 WLM( NEEDED 9220'). SET NO- GO C- SUB IN XN NIP. @ 8779' WLM. PULLED ST A #3. LA CAME UP TO 400# FROM 50#. DID NOT HAVE VALVE. (TOOL NOT SHEARED). RIH W/3.77" GRING & 41/211 B BRUSH TO SWEEP MANDRELS. 12/02/03 Set LGLV in Station 1,2; OGLV in Station 3. 12/05/03 T/I/O=800/1450/660. (TBG FL FOR E-LlNE). TBG FL @ 4501. 12/05/03 Perforate 9210'-922014 SPF 12/17103 T/I/0=260/940/940, TEMP=WARM. OA FL AT 60' (OA FL SURVEY). FLUIDS PUMPED BBLS 592 Crude 87 15.8 PPQ LARC Neat (0.84" fliter cake, 60 API fluid loss) 232 1 .5# Biozan 92 Fresh Water 50 90: 10 DAD acid 12% 265 Methanal 809 1 % KCL 30 15% HCL Acid 39 15.8 PPQ LARC (w/AQQreQate) 6 TEA 300 1 % XS KCL 566 1 % X-SLK 254 Diesel 3322 TOTAL Page 2 --- WELLHEAD == FMC AClUATOR== FMCAXELOLDSlYLE KB. 8..BI = 65.2' BF. 8..EV == ? KOP= ? fv1ax Angle = 23 @ 6905' D:ltum M) = 9139' D:ltum TV D == 8800' SS 06-04A I SAÆTYNOTES: CHROMETUBING TREE = ? 8 2087 4-1/2" X NP, [) = 3.813" 4-1/2"TBG,12.6#, 13-CR, .0152bpf, ID==3.958" ST M) TVD 1 3712 3712 2 5661 5594 3 6980 6811 4 7639 7425 5 8328 8077 6 8606 8341 GAS LFT r-MNDRELS DEV lYÆ VLV LATCH 1 TGFÐ OOtvE RK 22 TGFÐ OOtvE RK 23 TGFÐ S/O RK 20 TGFÐ DMY RK 16 KBG2 DMY BK 20 KBG2 DMY BK PORT DATE 16 12/2/03 16 12/2/03 24 12/2/03 0 11/18/03 0 11/18/03 0 11/18/03 9-5/8" CSG, 47#, tv1\I-80, [) =8.681" I . MLLQUT WlNOOW 7865' Minimum ID = 3.725" @ 8696' XN Nipple 8663' BAKER S-3 PA CKER 8696' -i 4-1/2" XN NIP, 10 == 3.725" I 4-1/2" WLEG 8717' 17"LNR, 26#,L-80, .0383 bpf, ID=6.276" I 8876' ÆRFORA 1l0N SU'lAMARY REF LOG: BHCS ON 12/07/75 ANGLE AT TOP PERF: 21 @ 9210' Note: Refer to Produetion DB for historieal perf data SIZE SA= INTERVAL Opn/Sqz DATE 2-112" 4 9210- 9220 0 09/04/00 2-112" 4 9210- 9220 12/05/03 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID=3.958" 9540' DAlE RBI BY COMMENTS DATE REV BY COMI'vENTS 12/19/75 ORIGINAL COMPLETION 11/23/03 IVI-I/PA G GL V C/O 11/12/78 WORKOVER 12/2-5/03 r-M / JM/lP GL V C/O, REPERF 08114/00 SIŒTRACKED C06-04A) 02/21/01 MH/tp CORREC1l0NS 05/09/02 CAOIKK MAX ANGLECORRECTON 06/12/03 CMO/1LP KB ELEV A TION CORRECfION PRUDHOE BAY lj\JIT WELL: 06-04A PERMT f\b: 2001020 API f\b: 50-029-20179-01 SEC 11, T10N, R14E, 1444.31' FEL & 1299.77' FNL BP Exploration (Alas ka) 0 ~ 0 0 0 ~ ~ 0 0 ~ ~ ~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~~oo~ oooo~~ Z Z Z Z U) C) ,,- _1 ,,- Z Z Z WELL LOG TRANSMITTAL To; State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 17, 2001 RE: MWD Formation Evaluation Logs · 06-04A, AK-MW-00111 06-04A: Digital Log Images: 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 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 ,S£p 0 7 ~aska O/I & Gas Cons. WELL LOG TRANSMITTAL To: State of Alaska August 15, 2001 Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7m Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 06-04A, AK-M~00111 1 LDWG formatted Disc with verification listing. API#: 50-029-20179-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 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 20 2001 Alaska Oil & Gas Cons. Commissior: Anchorage STATE OF ALASKA ALASKA~'~.' AND GAS CONSERVATION COMM~.~'~ ,.3N 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-102 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612~ 50-029-20179-01 ~- ................... ..~ I,~,~j~ 9. Unit or Lease Name 4. Location of well at surface ; L%.~'~.L.T. ¢~; ~ 371' NSL, 1114' WEL, SEC. 02, T10N, R14E, UM { h.'~., h.-: ! .~.V_,~I~Ft~ Prudhoe Bay Unit At top of productive interval ! ~ 1293' SNL, 1112' WEL, SEC. 11, T10N, R14E, UM f V~:~,!r:;',!~:~ ! ~' 10. Well Number At total depth L~ 06-04A 1400' SNL, 1063' WEL, SEC. 11, T10N, R14E, UM 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 65.20' ADL 028311 12. Date Spudded7/25/2000 113' Date T'D' Reached 114' Date c°mp'' Susp'' °r Aband'7/29/2000 9/4/2000 115' Water depth' if °ffsh°reN/A MSL 116' NO' of C°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set121. Thickness of Permafrost 9540 9218 ETI 9456 9140 FTI [] Yes [] NoI (Nipple) 2087' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES/AlT, DT/BHC, CNL, LDL, GR, Caliper, SP, MRES 231 CASING, LINER AND CEMENTING RECORD ' CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED , , 20" 94# H-40 Surface 100' 30" 13-3/8" 72# MN-80 Surface 2720' 17-1/2" 6400 sx Amticset 9-5/8" 47# MN-SO/S00-95 Surface 7865' 12-1/4" 100 sx Class 'G', 115 sx Arcticset 7" 26# L-80 7708' 8876' 8-1/2" 235 sx Class 'G' 4-1/2" 12.6# L-80 8712' 9540' 6-1/8" 140 sx Class 'G' 24. Perforations peen to. P.roducti.on (M.D+.TVD of Top and 25. TUBING RECORD Bottom and ~mervak s~ze and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr 8718' 8663' MD TVD MD TVD 9210' - 9220' 8910' - 8919' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL IJSED Freeze Protect with 150 Bbls of Diesel 27. PRODUCTION TEST '"RiGINAL Date First Production Method of Operation (Flowing, gas lift, etc.) September 9, 2000 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO TEST PERIOD I ,, ,, Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE ,,, 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 130. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sag River 8876' 8596' Shublik 8905' 8624' Sadlerochit / Zone 4B 8990' 8704' Zone 4A 9107' 8814' Zone 3 9210' 8910' Zone 2C 9298' 8992' Zone 2B 9342' 9033' Zone 2A 9488' 9170' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubb,e ~'J~_~~~ Title TechnicalAssistant Date /~"ll'~.~ 06-04A 200-102 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / 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 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. ] i~' Form 10-407 Rev. 07-01-80 BP AMOCO Page I of 5 Operations Summary Report Legal Well Name: 06-04 Common Well Name: 06-04 Spud Date: 10/28/1975 Event Name: REENTER+COMPLETE Start: 7/17/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: -- [~I, DECOMP 7/1 8/2000 ~oo:oo 08:00 8.00 ~ RIGD ' i Prepare rig for move. Move out cuttings tank. Remove Herculite and i i ~ , '~berms. Wait on location prep leveling. i08:00 - 08:30 ! 0.50 MOB DECOMP ~Move out shop and pit modules. 08:30 - 09:00 0.50, MOB I !DECOMP Move out hoisting module. 09:00 - 14:00 5.00 RIGU i DECOMP Spot rig on well, lay mats, lay Herculite. Spot pit module and cuttings tank. Berm pits, set shop and connect mud lines. 14:00 - 14:30 0.50 RIGU I DECOMP Held pre spud safety meeting with crew and pushers. 14:30 - 15:00 0.50 WHSUR~ DECOMP Rig up DSM and pull back pressure valve. 15:00 17:00 2.00 RIGU DECOMP Fill tanks with seawater workover fluid. Connect lines and cuttings tank. Conducted H2S drill. Response time - 2:00 Mins. 17:00 - 19:30 2.50 KILL DECOMP Circulated well with seawater taking returns in open cuttings tank !outside rig walls. Filled hole with 98 bbls. of fluid indicating fluid level at 1980 ft. Circulated thru degasser and recovered small amount of oil. NO H2S! Fluid loss rate was 65 bbl/hr while circulating at 5.0 bpm and ! 48 bbl/hr at 2. bpm. 19:30 - 20:30 1.001 KILL DECOMP Set BPV in tubing hanger and tested to 1000 psi from bottom. 20:30 - 22:00 1.50 WHSUB DECOMP Removed tree and adapter flange. Found tubing hanger lift threads to be 5 1/2" Buttress casing. Located and installed hanger plug. 22:00- 00:00 2.00 BOPSUR DECOMP Nipple up BOPE. 7/19/2000 00:00 - 04:00 4.00 BOPSUR DECOMP Conducted PJSM re Crown-O-Matic. Installed shear/blind rams in middle BOP. Tested BOPE, pipe rams, annular preventer, safety and dart valves, choke manifold, rotary hose and top drive to 250/3500 psi ~er AOGCC and BP specifications. Witness of test waived by John Spaulding with AOGCC. 04:00 - 05:30 1.50 WHSUR DECOMP RU DSM with lubricator and pull tubing hanger blanking plug. Pulled BPV. 05:30 - 07:30 2.00 WHSUR DECOMP Made up tandem spear for 5 1/2" tubing on drill pipe. Engaged tubing at 25 ft. and pulled to 85K. Pulled free. Laid out tubing hanger and spear. 07:30 - 08:30 1.00 PULL DECOMP Circulated bottoms up. Required 104 bbls to fill hole and get returns indicating fluid level at 1000 ft. Lost workover fluid at 50 bbl/hr while circulating at 3.0 bpm. 08:30 - 09:00 0.50 PULL DECOMP Held PJSM with HES re spooling of SSSV control line. Rig up spooler. 09:00 - 14:00 5.00 PULL DECOMP POOH laying down 5 1/2" tubing and SSSV. Recovered 90 its + cut joint and 26 CL clamps. TOF at 3788 ft. 14:00 - 14:30 0.50 PULL DECOMP Rigged down tubing handling equipment and cleared floor. 14:30 - 17:30 3.00 FISH DECOMP Made up BHA #1 and installed wear ring in wellhead. 17:30-19:30 2.00 FISH DECOMP RIHwithBH^#1 SLM 4" drill pipe. 19:30 - 20:00 0.50 FISH DECOMP Tagged TOF at 3788 ft. and washed over to 3880 ft. 20:00 - 21:00 1.00 FISH DECOMP Circulated bottoms up at 5.0 bpm at 200 psi. 21:00 - 22:00 1.00 FISH DECOMP POOH w/DP. 22:00- 23:00 1.00 FISH DECOMP Stood back BHA. 23:00 - 00:00 1.00 FISH DECOMP Made up 8 1/2" X 5 1/2" outside cutter on washpipe and began GIH. 7/20/2000 00:00 - 01:30 1.501 FISH DECOMP RIH with outside cutter to TOF at 3788 ft. 01:30 - 03:30 2.001 FISH DECOMP Swallowed fish with cutter to 3880 ft. and pulled up to tubing collar at 3850 ft. Engaged collar dog and cut 5 1/2" tubing at 3852 ft. 03:30 - 04:30 1.00 FISH DECOMP POOH with fish to BH^. 04:30 - 05:00 0.50 FISH DECOMP Laid down jars, stood collars and laid down top joint of washpipe. 05:00 - 06:30 1.50 FISH DECOMP Laid down 68 ft. fish including 2 tubing stubs, 1 jt. 5 1/2" tubing and POGLM. Laid down washpipe and cutter. 06:30 - 07:00 0.50 FISH DECOMP Rigged down WP handling tools and cleared rig floor.. 07:00 - 07:15 0.25 FISH DECOMP PJSM with Schlumberger & crews re chemical cutter operations. 07:15 - 11:30 4.25 FISH DECOMP Rigged us Schlumberger with 4 7/16" chemical cutter. Tagged bottom · Printed: 8/10/2000 11:23:22 AM BP AMOCO page 2 of 5 Operations Summary Report Legal Well Name: 06-04 Common Well Name: 06-04 Spud Date: 10/28/1975 Event Name: REENTER+COMPLETE Start: 7/17/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: -- Date -To ] Hours ACtivitY Code t Phase Description of operations , 7/20/2000 07:15 - 11:30 i~ 4.25 FISH i i DECOMP !at 6338 ft. Cut tubing at 6320 ft. WLM. Rigged down Schlumberger. 111:30 - 13:00 I~ 1.50i FISH I /~ DECOMP i Made up fishing BHA #4 with overshot, jars and drill collars. 13:00 ~ - 14:30 ] 1.50 FISH DECOMP i RIH with overshot and found TOF at 3856 ft. DP measure. Engaged [ i I !fish and gained 37K weight. 14:3015:30 -. 15:3017:00'.1 11'00.50 FIsHFISH I DECoMpDECOMP CirculatedpOoH to BHA.b°tt°ms us at 6.0 bpm at 275 psi. 17:00 - 17:30 0.50 FISH DECOMP Stood BHA #4 in derrick. 17:30 - 21:00 3.50 FISH DECOMP Rigged up tubing handling equipment and laid down 58 full joints and 2 cut joints (2497 ft.) of tubing fish. Rigged down handling equipment. . TOF at 6353 ft. by measure of fish recovered. 21:00 - 22:30 1.50 FISH I DECOMP Ran fishing BHA #5 out of derrick torquing all connections and service breaks to specification. 22:30 - 00:00 1.50 FISH DECOMP RIH with BHA #5 on DP to 3775 ft. 7/21/2000 00:00 - 01:00 1.00 FISH DECOMP Finished RIH with overshot BHA to TOF at 6353 ft. Obtained operating 3arameters and engaged fish. 01:00 - 02:00 1.00 FISH DECOMP Jarred on fish for one hour to maximum overpull of 185 K. Fish came free. Gained 40K weight. 02:00 - 02:30: 0.50 FISH DECOMP Attempted to circulate thru fish without success. Pressured DP to 2500 psi with no circulation. Dropped circulation sub dart and opened sub. 02:30 - 04:30 , 2.00 FISH ~ DECOMP POOH with DP to BHA. i04:30 - 05:00 0.50 FISH DECOMP Stood back DC and laid down jars. 05:00 - 05:10 0.17 FISH DECOMP Held PJSM with HES re hot tapping drill pipe. i05:10 - 11:30 6.33 FISH DECOMP Hot tapped and laid down tubing stub plugged with gravel. Pulled double of tubing containing POGLM across collar. Joint above top of packoff packer plugged with gravel. Joint below POGLM open. Laid down joints by cutting with pipe cutter in mousehole. 11:30 - 12:00 0.50 FISH DECOMP Circulated surface to surface thru remaining 1623 ft. of fish. 12:00 - 14:30 2.50 FISH DECOMP Laid down remaining 1623 ft. of 51/2" tubing fish. Recovered PBR receptacle, PBR seals, Baker K-anchor, and top latch section and K-anchor seal bore from packer. 14:30 - 15:00 0.50 FISH DECOMP Rigged down tubing handling equipment and cleared floor. 15:00 - 15:30 0.50 FISH DECOMP Laid down 3joints ofwashpipe. 15:30 - 17:00 1.50 FISH DECOMP Laid and loaded out fishing tools. Cleared floor of gravel. 17:00 - 17:30 0.50 FISH DECOMP Made up casing scraper with mule shoe on drill collars. 17:30 - 19:00 1.50 FISH DECOMP Serviced top drive and slipped and cut drill line. 19:00 - 21:00 2.00 FISH DECOMP RIH to 6380 ft. with DP from derrick. 21:00 - 22:00 1.00 FISH DECOMP Continue in hole with casing scraper to 7950 ft. picking up DP. Did not tag any obstructions or bottom. 22:00 - 23:30 1.50 FISH DECOMP Circulate bottoms up and pump hi vis sweep at 12 bpm. Did not recover any solids from wellbore. 23:30 - 23:50 0.33 FISH DECOMP Attempted to pressure test casing. Pumped into formation at 3.25 bpm with pressure increasing to 2000 psi. Pressure dropped quickly to 1100 psi and pumped into formation at 3.25 bpm. Stopped pump and observed loss of fluid level. Established fluid loss rate of 120 bbl/hr. 23:50 - 00:00 0.17 FISH DECOMP Began POOH with casing scraper. 712212000 00:00 - 02:30 ! 2.50 CLEAN DECOMP Finished POOH with casing scraper to BHA. 02:30 - 03:00 ~ 0.50 CLEAN DECOMP Stood back DCs and laid down scraper: 03:00 - 03:10 0.17 REMCM'] DECOMP PJSM w/Schlumberger and crews re setting retainer. ~03:10 - 04:30 1.33 REMCM; DECOMP Rigged up SWS with lubricator and made up EZSV cement retainer on : setting tool. 04:30 - 07:00 2.50 REMCM'] DECOMP Ran GR correlation log and set EZSV cement retainer top at 7924 ft. electric log depth (7932 ft. DP measure depth). Ran GR/CCL log from 7924 ft. to surface. Rigged down SWS. , . Printed: 8/10/2000 11:23:22 AM BP AMOCO Page 3 of 5 Operations Summa Report Legal Well Name: 06-04 Common Well Name: 06-04 Spud Date: 10/28/1975 Event Name: REENTER+COMPLETE Start: 7/17/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: I , 7/22/2000 !, 07:00 - 09:00 i 2.00i REMCMTOTHR i DECOMP i Attempted to pressure test 9 5/8" casing. Pressured to 3000 psi and ;r ii ~i i ~ !held for 10 mins. then lost pressure to 0 psi. Well went on vacuum and ' ' ' ~ i took fluid at rate of 85 bbls/hr. ;09:00 - 10:00 1.00 REMCMTOTHR DECOMP Made up HES RTTS on drill collars. ~10:00 13:00 3.00 REMCMTOTHR DECOMP I RIH with RTTS to 7850 ft.. 13:00 15:00 2.00 REMCM;'OTHR DECOMP Set RTTS at 7850 ft. Could not pressure below tool. Tested 9 5/8" . , casing to 3000 psi - OK. Tagged EZSV at 7934 ft. DP measure. Reset i RTTS at 7914 ft. Could not pressure below RTTS. Retested casing to 3000 psi- OK. 15:00- 17:30 2.50 REMCM"OTHR DECOMP POOH with RTTS. 17:30 - 18:00 0.50' REMCMTOTHR DECOMP Stood back DC and laid down RTTS. 18:00 - 18:15 0.25 REMCM"OTHR DECOMP Closed blind rams and pumped into formation past failed EZSV at 10 bpm at 1550 psi. 18:15- 18:30 0.25 REMCM"OTHR DECOMP Held PJSM with Schlumberger. 18:30 - 23:00 4.50 REMCM"OTHR DECOMP Rigged up Schlumberger and made up HES EZSV cement retainer. Located casing collars and set retainer at 7882 ft. electric line measure (7890 ft. DP measure). RD SWS. 23:00 - 23:30 0.50 REMCM" DECOMP Tested 9 5/8" casing to 3000 psi for 30 rains, with 12 psi leakoff. 23:30 - 00:00 0.50 REMCM'I DECOMP Began GIH with EZSV stinger to squeeze cement production 3erforations. 7/23/2000 00:00 - 03:00 3.00 REMCM'I' DECOMP Finished GIH w/cement retainer stinger. Located on EZS¥ at 7990 ft. I DP measure and rigged up. 03:00 - 03:15 0.25 REMCM'I' DECOMP Held PJSM with Dowell. 03:15 - 04:30 1.25 REMCMT DECOMP Stung into retainer. Pressured annulus to 500 psi and pumped 27 bbls. seawater into perforations at 5.0 bpm at 1250 psi. Pumped 5 FW and tested lines to 3500 psi. Mixed 130 sx. Class G cement with .08% D-110 & .15% D-800 retarders, and .5% gel followed w/5 FVV. ;Squeezed 7.0 bbls (35 sx) into perforations 9178-9245 ft. and left 545 'ft. plug in 7.0 inch casing interval 8700-9245 ft. Maximum and final i pump in pressure - 1650 psi. 04:30 - 05:30 1.00 REMCM'I' i DECOMP Pulled stinger from retainer and circulated surface to surface at 12.0 ~ bpm. Did not recover any cement or colored water. 105:30 - 08:30 3.00 REMCM;' DECOMP POOH and laid down stinger. i08:30 - 11:30 3.00 S'I'WHIP INT2 Made up whipstock BHA and MWD. 111:30 - 13:00 1.50 STWHIP INT2 RIH with whipstock BHA to 3000 ft. 13:00 - 13:30 0.50 STWHIP INT2 Circulated and function tested MWD at 3000 ft. 13:30 - 15:30 2.00 STWHIP INT2 RIH with whipstock BHA to 7800 ft. 15:30 - 16:30 1.00 STWHIP INT2 Circulated and oriented whipstock tool face to 87 deg left of high side (273 deg). 16:30 - 17:00 0.50 s'rWHIP INT2 Set whipstock anchor on cement retainer at 7890 ft. w/20K weight. PU 10K. Sheared running lug w/45K weight. 17:00 - 18:00 1.00 STVVHIP INT2 Circulated seawater workover fluid from wellbore with 10.5 ppg LSND I milling fluid. ~ 18:00 - 00:00 6.00 STWHIP INT2 Milled whipstock window in casing from 7865 ft. to 7879 ft. 7/24/2000 00:00 - 07:30 7.50 STWHIP INT2 Finish milling window and formation to 7896'. Window: 7865' to 7889'. 07:30 - 09:00 1.50 STWHIP INT2 Circ Hi-Vis sweep while rotating & reciprocating through window. Pump dry job. Monitor well-OK. 09:00 - 11:30 2.50 STWHIP INT2 POH to BHA. 11:30 - 14:00 2.50 STWHIP INT2 Pull BHA. LD DC's & milling assembly. Clear floor. 14:00 - 15:00 1.00 BOPSUF, INT2 Pull wear ring. Jet out BOP stack. D1 Drill; OS: 1 min. 15:00 - 18:00 3.00 BOPSUF, INT2 Set test plug. Test BOPE to 250 / 3500 psi. Witnessing waived by John Spaulding AOGCC Field Inspector. Pull test plug & set wear ring. , Printed: 8/10/2000 11:23:22 AM BP AMOCO page 4 of 5 Operations Summary Report Legal Well Name: 06-04 Common Well Name: 06-04 Spud Date: 10/28/1975 Event Name: REENTER+COMPLETE Start: 7/17/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: -- ~ DRILL , 7~24~2000 i 18:00 - 20:00 I 2.00! i !INT2 MU BHA. Orient. Set motor for 1.57. Upload MWD. RIH w/BHA. !20:00 - 21:30 I~ 1.50! DRILL i !INT2 Cut drlg line & service top drive. 'I! 00:0021:30 - 00:00 i 2.50 DRILL i! i lNT2 RIH to 3500'. Check MWD. RIH to 7850'. 71251200003:00 3.00 DRILL i INT2 Orient 90? L through w ndow. Drill f/7896' to 7920'. 03:00 - 04:00 1.00 DRILL INT2 Perform FIT to 12.5~ EMW. 04:00 - 00:00 20.00 DRILL i 'INT2 Drld f/7920' to 8346'. AST: 9.75 Hrs; ART: 4.75 hfs 712612000 00:00 - 09:00 9.00 DRILL INT2 Drld f/8346' to 8586'. 09:00 - 11:30 2.50 DRILL ClRC !INT2 Change swab & liner #2 cylinder #2 pump. 11:30 - 21:00 9.50 DRILL lINT2 Drilled f/8586' to 8876'. ART: 9 hrs; AST: 6 hrs. 21:00 - 23:30 2.50 DRILL lINT2 CBU @ 12 bpm. Continue circ looking f/samples. Saw some wood-no sand. 23:30 - 00:00 0.50 DRILL INT2 Short trip out to 8300'. 712712000 00:00 - 01:00 1.00 DRILL LNR1 Finish POH to 7850'. RIH to 8876'. No fill-No problems. 01:00 - 05:00 4.00 DRILL LNR1 . Pump Hi-Vis sweep. Started getting splintery shale, which didn't clean up. Increase mud wt to 10.7#. Cuttings pretty well stopped. 05:00 - 05:30 0.50 DRILL LNR1 Drop ESS. 05:30 - 09:30 4.00 DRILL LNR1 Pump dry job. POH to BHA. SLM. 09:30 - 11:00 1.50 DRILL LNR1 ~ LD BHA. 11:00 - 12:00 1.00 CASE LNR1 RU to run 7" liner. 12:00 - 13:00 1.00 CASE LNR1 PJSM w/all personnel. Safety & TL discussion w/Dave Hebert & Tony Bunch. 13:00 - 15:00 2.00 CASE LNR1 Run 28 jts, 26#, L-80 BTC-Mod liner. MU Liner hanger/packer assembly. RIH to 1270'. 15:00 - 15:30 0.50 CASE LNR1 Circ liner volume. 15:30 - 19:30 4.00 CASE LNR1 RIH w/liner on 4" DP to 7828'. D1 Drill-OS-45 sec. 19:30 - 21:00 1.50 CASE LNR1 Circ & cond mud @ window. Staged up to 9.5 bpm. 21:00 - 21:30 0.50 CASE LNR1 RIH in open hole to 8876'. PU cement head. 21:30 - 23:00 1.50 CEMT LNR1 Circ & cond for cement. Staged up to 8 bpm. Hole getting sticky at any higher rate. Reciprocate. 23:00 - 23:30 0.50 CEMT LNR1 PJSM w/all personnel. 23:30 - 00:00 0.50 CEMT LNR1 Test to 5000 psi. Pumped 50 bbls 11.2~ spacer. Pumped 48 bbls (235 sxs) 15.8# Premium 'G'. Start displacing wi rig pumps. Reciprocating. 7/28/2000 00:00 - 00:30 0.50 CEMT LNR1 Bumped plug @ 0015 hrs. Set hanger w/3000 psi. Set liner top packer wi 4500 psi. Floats held OK. Release from packer w/RH rotation. Press DP to 1000 psi & unsting. Set 60K on packer. 00:30 - 02:30 2.00 CEMT LNR1 Circ clean @ 12 bpm while reciprocating. Recovered small amount of cement f/TOL. Clean shakers & LD cement head. 02:30 - 05:30 3.00 CEMT LNR1 POH. LD liner setting tool. 05:30 - 06:00 0.50 BOPSUF LNR1 Pull & service wear ring. Reset. 06:00 - 09:00 3.00 DRILL LNR1 MU 6 1/8" BHA. Orient. Load LWD. RIH to 677'. 09:00 - 09:30 0.50 DRILL LNR1 RIH to 2250'. Test MWD-OK. 09:30 - 11:00 1.50 DRILL LNR1 PU 4" DP to 3100'. Stand back on Driller's side. 11:00 - 12:00 1.00 DRILL LNR1 Service top drive. 12:00 - 15:00 3.00 DRILL LNR1 RIH to 8500'. Checked MWD @ 5066'. Tagged cement stringers @ 8500'. 15:00-17:00 2.00 DRILL LNR1 Drld cement stringers & cement to LC @ 8790'. ::~::~ ?( ~ 17:00 - 18:00 1.00 DRILL LNR1 Test casing to 3000 psi f/30 min-OK. .' "', ' , ...... 18:00 - 21:30 3.50 DRILL LNR1 Drill shoe track out to 8876'. 21:30 - 00:00 2.50 DRILL LNR1 Displace well to QuickDril. ~,, ~,~-~- ,~ 7/29/2000 00:00 - 00:30 0.50 DRILL LNR1 Finish displace well to QuickDril. !': ~'~ i i 00:30 - 01:00 0.50 DRILL LNR1 Drill new formation fl 8876' to 8896'. 01:00 - 01:30 0.50 DRILL LNR1 Perform FIT to 9.6~ EMW. '~'~; .... ; ' ~ ;ii~,:; !:;, 01:30 - 19:30 18.00 DRILL PROD1 Drilled 6 1/8" hole to TD @ 9540'. ART: 14 hrs; AST: I hr. Spill , Printed: 8/10/2000 11:23:22AM BP AMOCO page 5 of 5 Operations Summary RePort Legal Well Name: 06-04 Common Well Name: 06-04 Spud Date: 10/28/1975 Event Name: REENTER+COMPLETE Start: 7/17/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: 7/29/2000 101:30- 19:30 i 18.00 DRILL t !PROD1 IOS-1'10 min. H2S Drill: O8-1:30 min. i I PROD1 Circ sweep around. i19:30 - 22:00 2.50 DRILL I , 22:00 - 23:00 i 1.001 DRILL,I PROD1 Short trip above shoe @ 8876'. SLM-No correction. No fill-No problems. 23:00 - 00:00 i 1.00 DRILL i PROD1 Start circ Hi-Vis Barofiber sweep around. 7~30~2000 100:00 - 01:00 1.00 DRILL = PROD1 i Finish circ Barofiber sweep. 01:00 - 01:30 0.50 DRILL PROD1 Drop ESS. Observe well. 01:30 - 05:00 3.50 DRILL PROD1 POH to shoe. Pump dry job. POH to BHA. 05:00 - 06:00 1.00 DRILL PROD1 Slip & cut 97' drlg line. Fire Drill: OS-1'10 min. 06:00 - 09:00 3.00 DRILL PROD1 LD BHA. Remove LWD sources. Download tools. Clear floor. 09:00 - 09:30 0.50 CASE COMP Rig casing tools. 09:30 - 09:45 0.25 CASE COMP PJSM w/all personnel. i 109:45 11:00 1.25 CASE COMP Ran 19 Jts 4.5", 12.6~ L-80 IBT-Mod liner. Make up hanger/packer assembly. 11:00 - 11:30 0.50 CASE COMP Circ liner volume. 11:30 - 16:30 5.00 CASE COMP Run in hole w/liner on DP to shoe @ 8876'. MU cement head & LD. 16:30 - 18:00 1.50 CASE COMP CBU @ 9 bpm wi 795 psi. 18:00 - 18:30 0.50 CASE COMP Run liner in open hole to 9540'. No fill-No problems. No losses. MU cement head. 18:30 - 20:00 1.50 CEMT COMP :Circ & cond for cement. Staged up to 9 bpm @ 1000 psi. Reciprocated i pipe. PJSM w/all personnel. 20:00 - 21:00 1.00 CEMT COMP Cement as per well plan w/25 bbls 9.5# spacer and 25 bbls ( 140 sxs ) Premium 'G'@ 15.8 ppg. Displace w/40 bbls perf pill & 58 bbls mud. Reciprocated pipe. Observed latchup. Bumped plug to 2000 psi @ 2045 hrs. Set hanger w/3000 psi. Set liner top packer wi 4500 psi. Released w/liner. 21:00 - 23:30 2.50 CEMT COMP Circ out spacer and cement @ 12.5 bpm while reciprocating pipe. 23:30 - 00:00 0.50 CEMT COMP Pump N-Vis sweep. Start displacing well to seawater. 7/31/2000 00:00 - 02:00 2.00 CEMT COMP Finish displacing well to clean seawater. Observe well-OK. 02:00 - 07:30 5.50 CEMT COMP LDDP & liner running tool. D1 Drill: OS-1'10 min. 07:30 - 08:00 0.50 CEMT COMP Pull wear ring. 08:00 - 08:30 0.50 CEMT COMP Test casing & liner to 3000 psi f/30 min-OK. 08:30 - 09:00 0.50 RUNCOr/I COMP RU tbg handling tools. 09:00 - 09:30 0.50 RUNCOr~I COMP PJSM w/all personnel. 09:30 - 00:00 14.50 RUNCO~I COMP Run total of 268 jts 4.5", 12.6", 13-Cr Fox tbg. Space out. MU hanger. Land tbg. RILDS. 8/1/2000 00:00 - 00:30 0.50 RUNCO~I COMP Installed BPV, Tested to 1000 psi. 00:30 - 04:00 3.50 BOPSUF COMP Removed ram blocks for summer maintenance. 04:00 - 05:00 1.00 BOPSUF COMP N/D BOP's 05:00 - 09:00 4.00 WHSUR COMP N/U adapter and tree. Test flange to 5000 psi. Pulled BPV and installed tree test plug. Test tree to 5000 psi. Pulled tree test plug. 09:00- 12:00 3.00 RUNCO~ COMP Rev circ seawater with corrosion inhibitor. 12:00 - 14:00 2.00 RUNCOk COMP Dropped ball/rod. Press to 3500 psi, held for 30 min tbg test. Bleed off tbg to 1500 psi. Press annulus to 3000 psi for 30 min packer test, OK. Sheared RP. 14:00 - 16:30 2.50 RUNCOk COMP Pumped 150 bbls diesel freeze protect w/HBR. U-tubed. 16:30 - 18:00 1.50 RUNCOk COMP Set BPV. Remove secondary annulus valve. Vac fluids from pits. Secure well. Released rig @ 1800 hrs for annual maint. Printed: 8/10/2000 11:23:22 AM 06-04A · DESCRIPTION OF WORK COMPLET RIG SIDETRACK INITIAL PERFORATION Date Event Summary 7/16/2000: 7/17/2000: 8/06/2000: 8/07/2000: 8/13/2000: 8/14/2000: 8/15/2000: 9/04/2000: 9/09/2000: RIH & tagged PBTD @ 6346' SLM. MIRU ELU. PT'd BOPE to 3000 psi. RIH w/robing puncher & shot circulation holes @ 6380'. POOH. RIH w! chemical cutter & cut tubing in l~tjoint above POGLM. POOH. FP'd well. RD. Performed GLV work. Performed GLV work. RIH & performed FCO f/9066' to 9448' CTM. RIH & tagged PBTD @ 9444' MD. Performed SCMT. Tagged PBTD @ 9448'. MIRU ELU. PT'd equip. RIH w/perf guns & shot 10' of initial perforations f/: 9210' - 9220' MD Reference Log: Sperry GR/Density/Neutron Log 7/31/2000. Placed well BOL. Obtained a representative well test datal l:: 15-Aug-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 6-04A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 7,805.20' MD 7,870.00' MD 9,540.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) a~LU ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ v-v-,v-v-v- v.- v-- ?- v.- v-- -e.- w,- v-- v,- ~ v-- v,- ,~-- v-. v-- - wmwww wwwww mwwww wwwww -- ~ . . ~000~ ~0 0 0 Z o )_ ~ 'or "" STATE OF ALASKA __/ ALASKA ._ AND GAS CONSERVATION COMIV~ ,~ION PERMIT TO DRILL 20 AAC 25.005 Form 10-401 Rev. 12-01-85 D Taylor Seamount Submit In Triplicate la. Type of work [] Ddll Ba Redrill ~ lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [], Deepen ....J [] Service [] Development Gas [] Single Zone [] Multiple Zone . 2. Name of Operator 5. Datum Elevati0r~ (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 65.2' Prudhoe Bay Field / Prudhoe 31 Address ....... 6.' Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028311 4. Location of well at surface ' , 7. 'Unit or Property Name 11. Type' Bond (See 2~' AAC 25.025) ' 371' NSL, 1114' WEL, SEC. 02, T10N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1296' SNL, 1104' WEL, SEC. 11, T10N, R14E, UM 06-04A Number 25100302630-277 At total depth 9. Approximate sPud date 1391' SNL, 1073' WEL, SEC. 11, T10N, R14E, UM 07/21/00 Amount $200,000.00 12. Distance to nearest property line I1~. Dista'~ce to nearest well " 14. Number of acres in property 15. Prol~osed depth (MD and TVD) ADL 028315, 3887' MDI No Close Approach 2560 9530' MD / 9212' TVD 16.' To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} " Kick Off Depth 7900' MD Maximum Hole Angle , 21.5 ° , Maximum surface 2450 psig, At total depti~ (TVD) 8800' / 3330 psig 18. Casing Program Specifications Setting Depth Size To3 Bottom , Quantity of Cement Hole Casin.q Wei,qht Grade Couplin,q Len,qth MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 BTC-M 1130' 7750' 7498' 8880' 8560' 232 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 800' 8730' 8544' 9530' 9212' 120 sx Class 'G' , 19'."To be completed fo~ Redriil, Re'-er~iry, and 'Deepen' 0'perationsl ........ Present well condition summary Total depth: measured 9660 feet Plugs (measured) PBTD Tagged at 9445' MD (12/22/94) true vertical 9364 feet Effective depth: measured 9445 feet Junk (measured) 33' of 2-1/8" HLS Strip Gun (Lost 02/93) true vertical 9157 feet Casing Length Size Cemented M D TVD Structural Conductor 100' 20" 100' 100' Surface 2660' 13-3/8" 6400 sx Arctic Set 2720' 2720' Intermediate Production 8570' 9-5/8" 1000 sx Class 'G', 115 sx Arctic Set 8630' 8368' Liner 1335' 7" 500 .~,~~'~, ~ ~ ~,, a=~, 8320' - 9655' 8070' - 9359' Perforation depth: measured Open: 9178'-9245'ORIGINAL Sqzd: 9245'- 9262' true vertical Open: 8898' - 8963' AJa~(~ ~ {~ ~$ Cot3s~ Sqzd: 8963'- 8980' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling P'rogram [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements 'contact Engineer Narne/Nurnb~r:' "Phi/ smith, ~64'-489~ ..... Bill I~aacso~i ~64-552'~ .......... Prepare~ By N~rne~Nu~n'ber: ' Te~rie' ~ubble, '564-4628 ......... 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone ~--------~.,......~,~, ~ Title Senior Drilling Engineer Date 'T/, ~ Permit Number APl Number O/., ,,~ Approval Date See cover letter ~ '".//'~'~.- .... 50-, 029-20! 79-J~ .,~l~ ~ -- ! ~ .-~ for other requirem ,e,,n, ts ,, , '~°nditions of Approval: Samples Required [] Yes ~No Mud Log Required r'lyes Hydrogen Sulfide Measures ,~Yes r-I No Directional Survey Required ,~Yes [] No Required Working Pressure for BOPE rl 2K; [] 3K; [] 4K; I~SK; [] 10K; [] 15K Other: ~'(~(~., ~:,{::~"~"~¢-~"¥-~t~c-~'--~t'-~ by order of APproved..B¥ .... .-.,-,,,-.,~,, ^l ~,c-.kli::r3 RY Commissioner ..... th.e, c?mmission Date ',~ ~/ DS 6-04A Rigsite Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE The Kingak shale has caused problems with stuck pipe on this pad. proper drilling and connection operations are practiced at all times. weights in excess of 10.5 ppg can be expected. Ensure Mud Lost circulation has been encountered in this area even without crossing faults, such as in this well. Be prepared for lost circulation at all times, but especially at and below the Sag River formation. DS-6 is a designated H2S pad. 100 ppm has been measured on this well. Follow all applicable H2S procedures. CONSULT THE DS-6 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION RECEIVED Alaska 0il & Gas Coos. C0~~n Anchorage Version 1.0 DS 6-04A Hazards and Contingencies Page ! of 1 DS 6-04A Permit to Drill IWell Name: 16-04A Sidetrack Plan Summary I Type of Redrill (producer or injector): I Producer ISurface Location: Target Location: Bottom Hole Location: 4907' SNL 1114' WEL S2 T10N R14E Umiat 1296' SNL 1104' WEL Sll T10N R14E Umiat 1391' SNL 1073' WEL Sll T10N R14E Umiat I AFE Number: 14J0440 I I Estimated Start Date: 107/21/2000 I 19,530' I TVD: 1 9,212 I I Rig: I Nabors 7ES I Operating days to complete: 119.6 I BFIMSL: 136.7 I I RKB: 165.2 I Well Design (conventional, slimhole, etc.): I Conventional Twin Sidetrack I Objective: I Ivishak Zone 3 re-drill I Original Drilling Permit Number: 175-62 (Approved 10/22/1975) Mud Program: Milling/Cutting Casing Mud Properties: LSND Density (ppg) I FunnelVis I Yield Point 10.5 I 40 - 50I 25 - 30 Whipstock Window in 9-5/8" I I pHI HTHP FL 9 - 9.5 <15 Intermediate Mud Properties: LSND I 8-1/2" hole section From sidetrack depth to 8800' MD (8597' TVD). TD Top of Sag River. Density (PPg)I Funnel Vis I Yield P°int I 0P. Vl I tau0 10.5 - 10.7 40 - 55 20 - 28 I 1 7 5 - 8 pH 9-9.5 APl FL <10 to 6 Production Mud Properties: Low Density QUICKDRILn Density (ppg) I Funnel vis I LSRV PV 8.3-8.5+ I 40-50I <20,000cP 5-8 6 1/8" hole section I YP I Ca++ 20 - 25 <100 APl FI <10 Directional: KOP: I 7900'MD'8W'Ihole. Maximum Hole Angle: Close Approach Well: 21.5° (~ 7940' (7708' TVD) to TD None pH 9.0-9.5 RECE i. VED Alaska 0it & Gas Coas. Commission DS 6-04A Permit to Drill Logging Program: Intermediate Section Production Hole IDrilling: Open Hole: Cased Hole: Drilling: Open Hole: MWD / GR None Possible USIT MWD / GR PEX w/BHCS (NOTE: Tie-in log is original GR/CNL) Formation Markers: Formation Tops MD TVDss Comments Base Permafrost 1,776' Above Window SV3 / T5 3,893' Above Window SV1 / T3 Above Window UG4 / K15-Cl 4,478' Above Window UG 1 / UgS 5,270' Above Window W$1 / West Sak 6,060' Above Window CM3 / K-12 6,292' Above Window K-10 6,784' Above Window CM-1 / K5 7,440' Kick Off Point 7,900' 7,604' HRZ 8,362' 8,039' (291' Thick) Kingak 8,669' 8,330' (200' Thick) Sag River 8,880' 8,530' (Base of Kingak) Shublik 8,906' 8,555' Top Sadlerochit / Z4B 8,986' 8,630' Zone 4A 9,109' 8,747' TZ3 / CGOC 9,202' 8,835' 5/2000 test D$6-15:3330 psi @ 8800' (7.3 ppg) COWC 9,260' 8,890' TZ2C 9,281' 8,910' TZ2B 9,323' 8,950' HO/T 9,346' 8,972' TZ2A 9,464' 9,083' TZl 9,524' 9,140' TD 9,530' 9,145' BSAD 9,195' Not Penetrated Casin¢/Tubinq Proqram: Hole Size Csgl Wt/Ft Grade Conn Length Top Btm Tb~l O.D. MD/TVD-bkb MDrrVD-bkb 8-1/2" 7" 26# L-80 BTC-M 1130' 7750'/7498' 8880'/8560' 6-1/8" 4-1/2" 12.6# L-80 I BT-M 800' 8730'/8544' 9530'/9212' Tubing 4-1/2" 12.6# 13-Cr new VAM 8702' Surface 8730'/8544' RECEIVED Alaska Oit & Gas Cons. Commission A~chorage ,( DS 6-04A Permit to Drill Cement Calculations: ICasin(, Basis: Size 17" Intermediate - Single Stage Lead' None I Total Cement Volume: Tail: Based on 980' of open hole with 30% excess + 85' Shoe + 150' lap + 200' DP x Casing Annulus Tail TOC: 7750' MD (top of liner lap) Lead 1None Tail 48 bbls / 270 ft3 / 232 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk. Liner Size 1 4 W' Production I Basis: Tail: Based on 650' of open hole with 50% excess, 150' of 7" x 4.5" liner lap, 200' of 7" x 4" drill pipe annulus volume, and 85' of 4-1/2" shoe joint. Tail TOC: At top of liner -8,730' MD Total Cement Volume: Tail 1 25 bbl/140 ft3/120 sks of Dowell Class 'G' at 15.8 ppg and 1.17 I cf/sk. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Maximum anticipated BHP: 3330 psi @ 8800' TVDss - Zone 3 Maximum surface pressure: 2450 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/fi) · Planned BOP test pressure: · Planned completion fluid: 3500 psi 8.6 ppg Seawater / 6.8 ppg Diesel Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S · DS 6 is a designated H2S drill site with measured levels over 100 ppm. Operating Procedures for H2S precautions should be followed at all times. Standard DRILLING CLOSE APPROACH: All wells pass close approach guidelines. RECEi. VED Alaska 0i~ & Gas Cons. Commission Anchorage DS 6-04A Permit to Drill INTERMEDIATE SECTION: · The original well was drilled with 10.5 ppg mud from the HRZ to TD without any noted hole problems. · The DS6-04A well path will drill approximately 290' of HRZ and 200' of Kingak shale. Follow all established drilling and connection practices for mechanically sensitive shales. · Tight hole conditions and stuck pipe have not been reported on DS 6 wells. · Shallow gas has been an issue on only 3 wells (all to the NE) in the Put River formation. There is no Put River in this well; shallow gas is not expected. · The kick tolerance for the 8-1/2" open hole section would be an infinite volume assuming an influx from the Sag River interval at -8,600' MD. This is a worst case scenario based on a 9.0 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the surface casing shoe, and 10.0 ppg mud in the hole. PRODUCTION SECTION: · DS-6 is an H2S pad. Review and follow all applicable H2S procedures. · There are no planned fault crossings in the reservoir section. Lost circulation has been an issue on DS-6 only when faults are encountered. · The kick tolerance for the 7" shoe would be an infinite influx (annular volume) assuming an influx at section TD of 9,530' MD. This is a worst case scenario based on a 7.5 ppg pore pressure, a minimum fracture gradient of 9.5 ppg at the 7" casing shoe, and 8.3 ppg mud in the hole. Disposal: · No annular injection in this well. · Cuttings Handling: Cuffings generated from drilling operations will be hauled to grind and inject at DS,04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. SUMMARY SIDETRACK PROCEDURES Pre-Rio Work: _ * Notify the field AOGCC representative with intent to plug and abandon * 1. RU e-line and punch circulating holes in the tubing just above the fill (last tagged at 6350'). Circulate the well to sea water. 2. Chemical the tubing in the center of the first full joint of tubing above the uppermost POGLM at 3812'. Check with the 7ES Rig Supervisor regarding rig timing and determine if freeze protection to diesel will be required. Freeze protect if necessary with diesel to 2000' MD (base PF = 1776' TVDss). 3. Test the FMC GEN 1 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. On both the tubing hanger and 9 5/8" casing head, completely back out and check each lock down screw for breakage (check one at a time). Notify the ODE (Phil Smith 564-4987) immediately concerning any problems with backing out the lock down screws or other potential well head problems. 4. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 1000 psi. Secure well. 5. Remove the well house and flow lines. If necessary, level the pad. Please provide total well preparation cost on the hand over form. RECEtVED Alaska 0ii & Gas Cons. Com DS 6-04A Permit to Drill Rig 1. 2. Operations: MIRU Nabors 7ES. Pull BPV, circulate out freeze protection (if applicable) and displace well to sea water. Set TWC and test. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull and lay down 5-1/2" tubing from E-line cut at -3,775' MD. 5. RIH with outside cutter and cut the tubing below the POGLM. POH, lay down fish. 6. RU E-line and chemical cut the tubing in the center of the first full joint above the fill (last tagged at 6330' MD on 9/14/99). 7. RIH with fishing BHA and pull tubing fish. Lay down same. 8. RIH with fishing BHA and attempt to jar free the remaining tubing from the PBR. · If fish does not come free, RIH with outside cutter and fish the lowermost POGLM. RU E-line and cut the tubing just above the PBR. Fish remaining tubing and continue. 9. RIH with EZSV on drillpipe. Set retainer between 7900 and 7920' MD and bullhead 25 bbls of 15.8 ppg class G cement to cover all perforations plus 500'. Pressure test the 9 5/8" casing to 3000 psi. 10. RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock, with gyro (vertical 1~11 hole) as desired and set on BP. Mill window in 9-5/8" casing at -7,900' MD. POOH. _ · I~iCK-On' ana ari, u ;,'= no~e from/,~uu To ~,~u au [ne Top or [ne ~ag~iver rorma[~on, r~un MWD/GR. No other logs are planned for this interval. 12. Run and cement a 7" 26# L-80 intermediate drilling liner. 13. Make up and RIH with a 6-1/8" directional assembly to the landing collar. 14. Test the 9-5/8" casing and 7" liner from the landing collar to surface to 3000 psi for 30 minutes. 15. Drill out 6 1/8" hole from 8,880' to TD of 9,530'. Run MWD/GR only, 16. RU E-line and log PEX + BHC Sonic through the entire open-hole. RD E-line. 17. Run and cement a 4 ~", 12.6# L-80 IBT-Mod solid production liner through the 6-1/8" well bore. 18. Displace well to clean sea water above liner top. 19. POOH LD DP. 20. Test the 4-1/2", 7", and 9-5/8" casing from the 4-1/2" landing collar to surface to 3000 psi for 30 minutes. Run 4-1/2", 12.6# 13-Cr completion tying into the 4-1/2" liner top. Set packer @ -7700' MD and test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. 21. 22. 23. 24. 25. Estimated Pre-rig Start Date: Estimated Spud Date: Phil Smith Operations Drilling Engineer 564-4897 Set BPV, nipple down the BOPE. Nipple up and test the tree to 5000 psi. Freeze protect the well to -2100' and secure well. Rig down and move off. 07/15/00 07/21/00 RECEIVED Alaska Oit & Gas C0~s, O0~mission ~ AI aska, I rc. ~ WSSSV Tubing-NPC Casing Casing POGLM Gas Lift Mandrel/Dummy Valve 1 POGLM Gas Lift Mandrel/Valve 2 SLS PBR PKR XO Tubing-NPC SOSUB FISH Liner 06-04 NIP API: 1500292017900 H2S:' SSSV T e: Annular Fluid: Diesel/10A CaCI Reference Log: I, BHCS Last Ta : I I j -I 5-1/2" 5-1/2" NIP TTL Perf Perf Perf GL Elevation = 36.7 Nabors 7ES RKB = 65.2' 13 3/8", 72 #/ft, M N-80 Liner TopatI +/-7,750' I 4-1/2" X' Landing Nipple with 3.813" seal bore. I 2200' 4-1/2" 12.6# 13-Cr, new VAM Tubing 4-1/2' x 1-1/2" (lowermost = 1") Camco 'MMG' Gas Lift Mandrels with handling pups installed above and below. GAS LIFT MANDRELS IVD Size Valve Type 1 ' 1-1/2" RP Shear 2 ' 1-1/2" DV 3 ' 1-1/2" DV 4 ' 1" DV (or lit above packer) BAKER 9 5/8" x 7' ZXP Liner Top Packer 'Hydraulic Liner Hanger Window Milled from Whipstock Top of Window at +/- 7900' MD Cement retainer set at +/-7920' MD REC,,,=iVED JUL 1 ~ 2OO3 Alaska 0ii & Gas Cons. Commission ~chor~e 7" x 5" Baker 'S-3' Packer 4-1/2" 'XN' Landing Nipple, 3.725" ID 4-1/2" Liner top packer 18,730' I and hanger 7" 26#/ft L-80 BTCM J8~80' I 9-5/8", 47 #/ft, LBO, BTC I ~,,~o' I TOC at +/-8700' MD Top Perforation at 9178' MD PRUDHOE BAY UNIT WELL: 6-04A APl #: 50-029-20179-01 4-1/2" 12.6 #/ft, L-80, IBT-M Date Revised by 07/05/00 PGS Comments Proposed completion muJ ""' I ~°c~ c:~ iii . . o.o.q 00000 00000 0000 0 qqqqq qqqq q 0 Z Z ZZZ ZZZZZ ZZZZZ ~~ ~0~0~ ~ ~ ~~~ o~o~~o~o ~ 0 ~ ~ 0~0~ ~0~0 ~. ~ o ~ o~o~ ....... ~ ..... W~W~W W~WW ~ ..... ~q ~. ZZZZZ ZZZZ Z ~ ~ ~000 ~ qq~qq q~qq~ 00~00 0~00~ 00~00 0~00 ~0~ ~ q~qq qq~ q 0~00 ~0~ 0 ~u0 E ~ E ~[i,I o O~ ~ ooooo oooo ZZZZZ ZZZZ Shared Services Drilling 06-04A Wp 04 I DrillQuesf Eastings Scale: linch = 15Oft ST Exit ('~. 10°/10Oft 275.000° TF: 7900.00ff MD 7670.30 Begin Dir ~ 4.000°1100ft: 7940.00ff MD: 7707.981 End Dir' 8090.55ff MD, 7850.09ft Current Well Properties Well: 06-04A WPS Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure Reference: Ref. Geographical Coordinates: RKB Elevation: 5940967.54 N, 685872.80 E 941.17 S, 1173.48 E 70' 14' 37.2612' N, 148' 29' 55.0556" W 66.70ff above Mean Sea Level 66.70ft above Structure Reference North Reference: Units: True North Feet -1350 - 1:: -1500 - o Z 78OO @ 10°/100ft, 275° TF · 7900.00ft MD, 7670.30ft TVD Dir @ 4.000°/100ft' 7940.00ft MD, 7707.98ft TVD ~d Dir: 8090.55ft MD, 7850.09ft TVD -1650 - 8100 HRZ- 8105.70 TFD 8400 87O0 900O . s?o0.oo 7" Casing 8879.41 ND 8596.70 TVD ............... TSGR - 8596.70 TFD ............... Shublik- 8621.70 TFD ............... TS,4D/TZ4B - 8696. 70 TFD 06-04,4 Target 8916. 70 TI/D IL06 E ' TZ4,~ . 8813. 70 TVD TZ3/GOC . 8901.70 TVD 06-04A GeoPol~, ............... OF~C- 8956. 70 TVD ............... TZ2C - 8976. 70 TVD moo.oo TZ2B. 9016.70 TVD .............. HOT- 9038. 70 TVD -150 0 7" Casing J 8879.41 MD 8596.70 TVD 1 4 1/2" Une 9529.78 9212.23 _ 0_6-04_~ Oe__oP~v I I I I I o6-o,l.~ ~1916.~ - -1350 - -1500 ~ o Z --1650 II Target TVD s, H. O6 E I I -150 0 150 Reference is True North Propos~-~~4A Wp04 Vedical Origin:Well l, kn'izontal Origin: Well Measurement Units: North Reference: True Nocth Vertical Sectio¢4 Azimuth: 163.810' Ve?dcal Sec~on Description: Well Vertical Sectkm Origin: 0.00 N,0.00 E Measured Incl. Azlm. VerticalNortfllngs Easttnge VeRIcal D~pth Depth S~ctlon 7~00.0019.267191.g327670.30 1259,28 S 105.05 WI 7940.0020.001180.2107?07.95' I Z72.58 S106.44 W1192.44]0.000 8090.5518,837162.~677850.09 1321.54 S 99. i7 W124L45 4,000 9217.52]8.837162.3678916.70 1668.32 S 11.06E 1605.240.000 9259.7818.837162.3678956.70 168].33 S 15.20 E 1618.890.000 9439.7818.837162.3679127.06 1736.71 S 32.80 E 1676.990.000 9529.7818.837162367 9212.23 1764.41 S 41.61 E 1706.030.000 Single Well Target Data for 06-04A WPS 'IVD TVDss Ncn'thlngs Fastings ASP Y ASP X ~ 06-04A Drillea's POly Enay Point 1565.10 S 84.63 E 5939405.00 N 685996.00 E Polygea BoundatyPointA 1565. IOS 84.63E 5939405.00N 685996,00E B 1718.91 S 74.84 E 5939251.00 N 685990.00 E ) 1704.40S 26.84W 5939263.00N 685888.00E 1546.85S 46.96W 5939420.00N 685864.00E 06-04A Geopoly Entry Point 1516.52 S 60.22 W 5939450.00 N 685850.00 F, Polygon BoundatypointA 152{).83S 114.739, 5939450.00N686025.00E cB 1516.52S 60.22W 5939450.00N 685850.00E 1741.45S 65.76W 5939225.00N685850.00E D 1745.76S 109.18E 5939225.00N 686025.00E 06-04ATa~get EntxyPoint 8916.70 8850.00 1668.32S 11.06E 5939300.OONf85925.00E Point 9300 9529.78 MD 9212.23 TVD -TZ.24 - 9149. 70 TVD - TZI. 9206.70 TKD ...... B$/ID ~ 9261.70 TI/D I 1200 1500 1800 Section Azimuth: 163.810° (True North) Vertical Section RECEIVED JUL 11 A aska 0it & Gas Cons. Comn ssiOn Anchorage STATE OF ALASKA ALASK.~' IL AND GAS CONSERVATION COM~~ .;SION APPLICATION FOR SUNDRY APPROVAL · Typo of Request: [] Abandon [] Alter Casing [] Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 4. Location of well at surface 99519-6612 371' NSL, 1114' WEL, SEC. 02, T10N, R14E, UM At top of productive interval 1167' SNL, 1330' WEL, SEC. 11, T10N, R14E, UM At effective depth 1259' SNL, 1403' WEL, SEC. 11, T10N, R14E, UM At total depth 1300' SNL, 1~.~.~.' WEL, SEC. 11, T10N, R14E, UM Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 9660 feet 9364 feet 9445 feet 9157 feet Length 100' 2660' 8570' 1335' 12. [] Suspend [] Repair Well [] Operation Shutdown Size 20" 13-3/8" 9-5/8" 7" [] Plugging [] Time Extension [] Pull Tubing [] Variance [] Re-Enter Suspended Well [] Stimulate 5. Type of well: [] Development [] Exploratory r'! Stratigraphic ~ Service RECEIVED JUL i ] 2000 Alaska 0il & Gas Cons. Com~n Anchorage [] Perforate [] Other Plug Back for Sidetrack 6. Datum Elevation (DF or KB) 60' RKB 7. Unit or Property Name Prudhoe Bay Unit Plugs (measured) Junk (measured) 8. Well Number 06-04 9. Permit Number 175-062 10. APl Number 50- 029-20179-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool PBTD Tagged at 9445' MD (12/22/94) 33' of 2-1/8" HLS Stdp Gun (Lost 02/93) Cemented 6400 sx Amtic Set 1000 sx Class 'G', 115 sx Arctic Set 500 sx Class 'G' MD TVD 100, 100' 2720' 2720' 8630' 8368' 8320'-9655' 8070'-9359' Perforation depth: measured true vertical Open: 9178'-9245' Sqzd: 9245'-9262' Open: 8898'-8963' Sqzd: 8963'-8980' ORIGINAL Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80 to 8096'; 4-1/2", 12.6#, N-80 from 8096' to 8210' Packers and SSSV (type and measured depth) 9-5/8" x 5-1/2" Baker SAB packer at 8084'; 5-1/2" Camco BaI-O SSSV Nipple at 2186' 13. Attachments [] Description Summary of Proposal 4. Estimated date for commencing operation July 15, 2000 [] Detailed Operations program I15. Status of well classifications as: [] Oil [] Gas [] Suspended Service 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Phil Smith, 564-4897 [] BOp Sketch Bill Isaac. son, 564-5521 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge /wa Signed Dan Stone ,~---'--_-_~..._ ../,~, ~ Title Senior Ddlling Engineer ~i~'~'F$' "' ~ ..... "'~" ~' ~F ~'' · ~'~'~' ~'~ ;' '~'~"~ '":~'~"~' ~' ~'~ ..... ~ ~ ' ..... ~ ' ...... ~ ..... ~ ..... ' ~ ~ ~ -~'~' ~ CondEions of Approval: Noti~ Commi~ion ~ mpre~n~tive may wEne~ Plug int~d~ ~ BOP Te~ ~ L~aon clearance ~ M~hani~ Integ~ Te~ Subsequent fo~ required 10- .Approved by order of the Commission Date "~/~ =/~<3 Approval No. 300 '" J ~ / Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate I DATE CHECK NO. H 169428 ( Ioo,.- .1 v*-.uu, tRL ~::iRiR~i I Al ~ 0 DA~ INVOKE / CRED~ ME~ DE~RI~ G~ DI~ N~ ..... )~2600 :CKO~2&OOD 100. O0 ~ 00. O0 ~N~]NG INST: s/h ~errte x ; I 'FIRST :~/ATIO~BANI(":OF A,19L"'AND N oi~' ~:,: H ..~ 69 ~!2 8 :..:' ;:.?,? :."-:":::!: .:';."i: .A~?Ai~iLtATE:~ ';?::ii!':.:"::i:: '... ::::::::!!! ::'.'::':: N~'~i~DN,~'~ITY.:B.~I~K ':: ':': ~:' '~ :: CONSOL' ~ED COMME~CIA[~CCO~:""~I · ::.:.':.::..:.:::.:~' C,[EVE~D, OHiO .::.::~' .:'..':: ANCHORAGE AK 99501 ii. ],r.,qh i?R," ,:Or, ]. i?O3, P. qS~: WELl. PERMIT CHECKLIS~ COMPANY j~,"'-' ' · WELL NAME ~,"~ 4.//~ PROGRAM: exp der '"' reddl ~"'"' sew wellbore seg ann. disposal para req FIELD&POOL ~,,o.L~_/.~ INITC~_A~S ~~"~/ 7r~)/(,...- GEOLAREA _~~ UNIT# (~///~"~ ON/OFF SHORE Al3 IINISTRATION 1. Permit fee attached ....................... (~ ~N '.~ ~ 2. Lease number appropriate.." ................. 3. Unique well name and number .................. !.:~i~ 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ . 8. If deviated, is wellbore plat included ...............~1 ~ i ~:'.; 9. Operator only affected party ................... ,j N ~'; 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ ~AP'iJ~'/"/(""~DA'T'E~ 12. Permit can be issued without administrative approval ......~ 13. Can permit be approved before 15-day wait ........... ~N ENGINEERING 14. Conductor string provided ................... Y N'~ 15. Surface casing protects all known USDWs ........... Y 16. CMT vol adequate to circulate on conductor & surf csg ..... Y 5~"'~e..-~-c.,~v_ ~ ~..., ;,~ ,r,.~,,~.~. ~ 17. CMT vol adequate to tie-in long string to surf csg ........ Y . ~ 18. CMT will cover all known productive horizons. (~ N ~... 19. Casing designs adequate for C, T, B & permafrost .......~ N !=!~i!: 20. Adequate tankage or reserve pit ................. N ?;.;:~:: 21. If a re-drill, has a 10-403 for abandonment been approved... N "~q:x;3-., N ?~;:i.; 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... r~ '?~? 24. Drilling fluid program schematic & equip list adequate ..... i.i~ 25. DOPEs, do they meet regulation ................ DATE 26. DOPE press rating appropriate; test to .psig. (~ N ~c,~",, ~lrt:~-<~O 27. Choke manifold complies wi^PI RP-53 (May 84) ........ {~ N 28. Work will occur without operation shutdown ........... ~ N . , ,.. ~ ! r-~ ~ . ~',.., t__ ~ ~ 29. Is presence of H2S gas probable ................. ~N t3~\~.c,.,-,,~">.~:x~.O , ,~,,,~','~,~-~.,,3~,~,~e~.)~~~ ,.~','-.,.5,, . GE,~I-OGY 30. Permit Can be issued w/o hydrogen sulfide measures ..... ~ ~- ~c~ ~d ~ %Z-//._;~ ~ 31. Data presented on potential overpressure zones ..... ,,.~ ~..,,-'~'Y'"'N" '"" (/' ~ 32. Seismic analysis of shallow gas zones .......... ~ Y N AP~7~ DATE 33. Seabed condition survey (if off-shore) ....... ..:,.,-~.... Y N : .~---- '~'" / ~"~:~(,~ 34. Contact name/phone for weekly progress re~xploratory only] Y N ANN[ILAR DISPOSAL35. With proper cementing records, this plan ~ (A) will contain waste in a suitable receiving zone; ....... Y N A DATE (B) will not contaminate freshwater; or cause drilling waste... Y N ....... to surface; ~ (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and · ,,,,,,,,, (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ENGINEERING: UIC~Annular COMMISSION: Comments/Instructions: Z -I -1= c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well History File APPENDIX Information of detailed nature, that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ No 'special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Aug 15 14:50:55 2001 Reel Header Service name ............. LISTPE Date ..................... 01/08/15 Origin ................... STS ~ '/ ~3~ Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/08/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NI/MBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING DS 6-04A 500292017901 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 15-AUG-01 MWD RUN 2 AK-MW-00111 STEPHANE HUI TOM ANGLEN MWD RUN 3 AK-MW-00111 STEPHANE HUI TOM ANGLEN 2 10 14 371 1114 .00 65.20 36.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 7865.0 6.125 7.000 8876.0 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 WAS DIRECTIONAL ONLY TO SET THE WHIPSTOCK AND TO DRILL OUT; NO DATA ARE PRESENTED ON THIS PLOT. 3. MW/] RUN 2 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. MWD RUN 3 WAS DIRECTIONAL WITH DGR, EWR4, COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD). 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHNOOR, GEOQUEST (BP), DATED 7/10/01. 6. MWD RUNS 1, 2, & 3 REPRESENT WELL DS 6-04A WITH API#:50-029-20179-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9540'MD / 9217.61'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVIT (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLDSLIDE = SLIDE INTERVALS ADJUSTED FOR THE SLD SENSOR-TO-BIT DISTANCE. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.4 PPG MUD SALINITY: 400 PPM CHLORIDES FORMATION WATER SALINITY: 23,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START DEPTH GR 7851.0 RPX 7860.5 RPS 7860.5 RPM 7860.5 RPD 7860.5 FET 7896.5 ROP 7896.5 NCNT 8803.0 FCNT 8803.5 NPHI 8803.5 PEF 8818.0 RHOB 8877.5 DRHO 8877.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: STOP DEPTH 9503 0 9510 0 9510 0 9510 0 9510 0 9510 0 9539 5 9465 5 9466 0 9465 5 9481 5 9481 5 9481.5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 7851.0 8876.0 3 8876.0 9539.5 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999~ Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHPIM 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 FET MWD HOUR 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 24 28 32 36 40 44 48 52 7 8 9 10 11 12 13 14 Name Service Unit Min Max DEPT FT 7851 9539.5 ROP MWD FT/H 0.09 1269.87 GR MWD API 12.21 545.24 RPX MWD OHMM 0.46 2000 RPS MWD OHMM 0.47 2000 RPM MWD OHMM 0.43 2000 RPD MWD OHMM 0.23 2000 FET MWD HOUR 0.2692 53.2588 NPHI MWD PU-S 4.78 60.59 FCNT MWD CNTS 107 3112 NCNT MWD CNTS 13717 48785 RHOB MWD G/CM 2.151 2.905 DRHO MWD G/CM -0.026 0.292 PEF MWD BARN 1.16 14.28 Mean 8695.25 54.8399 117.859 13.6975 15.269 42.4795 40.8479 2.07214 24.4299 684.505 27362.9 2.35573 0.0681166 3.02703 Nsam 3378 3287 3305 3300 3300 3300 3300 3228 1325 1326 1326 1209 1209 1328 First Reading 7851 7896.5 7851 7860.5 7860.5 7860.5 7860.5 7896.5 8803.5 8803.5 8803 8877.5 8877.5 8818 Last Reading 9539.5 9539.5 9503 9510 9510 9510 9510 9510 9465.5 9466 9465.5 9481.5 9481.5 9481.5 First Reading For Entire File .......... 7851 Last Reading For Entire File ........... 9539.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7851.0 RPX 7860.5 RPS 7860.5 RPD 7860.5 RPM 7860.5 FET 7896.5 ROP 7896.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL G~ RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8838 5 8848 0 8848 0 8848 0 8848 0 8848 0 8876 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): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined 26-JUL- 00 Insite 65.41 Memory 8876.0 15.8 20.4 TOOL NUMBER PB01574HGR6 PB01574HGR6 8.500 Water Based 10.50 42.0 9.6 300 8.0 .900 .440 1.100 1.050 67.0 143.6 67.0 67.0 Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD020 FT/H 4 1 68 MWD020 API 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 7851 8876 ROP MWD020 FT/H 0.09 425.46 GR MWD020 API 61.98 411.04 RPX MWD020 OHMM 0.46 2000 RPS MWD020 OHMM 0.47 2000 RPM MWD020 OHMM 0.43 2000 RPD MWD020 OHMM 0.23 2000 FET MWD020 HOUR 0.4776 5.2324 Mean 8363.5 40.2147 161.292 4.22075 4.1491 7.89711 10.8034 1.31555 Nsam 2051 1960 1976 1976 1976 1976 1976 1904 First Reading 7851 7896.5 7851 7860.5 7860.5 7860.5 7860.5 7896.5 Last Reading 8876 8876 8838.5 8848 8848 8848 8848 8848 First Reading For Entire File .......... 7851 Last Reading For Entire File ........... 8876 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/15 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 ....... 01/08/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 8803 . 0 9465 . 5 NPHI 8803.5 FCNT 8803.5 PEF 8818.0 GR 8839.0 RPD 8848.5 RPX 8848.5 RPM 8848.5 FET 8848.5 RPS 8848.5 ROP 8876.5 RHOB 8877.5 DRHO 8877.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9465.5 9466.0 9481.5 9503.0 9510.0 9510.0 9510.0 9510.0 9510.0 9539.5 9481.5 9481.5 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 29-JUL-00 Insite 4.15 Memory 9540.0 19.0 22.7 TOOL NUMBER PBO1585GRF4 PBO1585GRF4 PBO1585GRF4 PBO1585GRF4 6.125 Water Based 8.40 40.0 9.5 1000 10.0 1.500 .690 2.600 2.8O0 68.0 156.2 68.0 68.0 Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Service Order Units Size Nsam Rep FT 4 1 68 MWD030 FT/H 4 1 68 MWD030 API 4 1 68 MWD030 OHMM 4 1 68 MWD030 OHMM 4 1 68 MWD030 OHMM 4 1 68 MWD030 OHMM 4 1 68 MWD030 HOUR 4 1 68 MWD030 PU-S 4 1 68 MWD030 CNTS 4 1 68 MWD030 CNTS 4 1 68 MWD030 G/CM 4 1 68 MWD030 G/CM 4 1 68 MWD030 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 8803 9539.5 ROP MWD030 FT/H 0.18 1269.87 GR MWD030 API 12.21 545.24 RPX MWD030 OHMM 1.22 1298.14 RPS MWD030 OHMM 1.02 970.93 RPM MWD030 OHMM 1.24 2000 RPD MWD030 OHMM 1.19 2000 FET MWD030 HOUR 0.2692 53.2588 NPHI MWD030 PU-S 4.78 60.59 FCNT MWD030 CNTS 107 3112 NCNT MWD030 CNTS 13717 48785 RHOB MWD030 G/CM 2.151 2.905 DRHO MWD030 G/CM -0.026 0.292 PEF MWD030 BARN 1.16 14.28 Mean Nsam 9171.25 14'74 76.4415 1327 53.281 1329 27.8409 1324 31.8649 1324 94.092 1324 85.6877 1324 3.16017 1324 24.4299 1325 684.505 1326 27362.9 1326 2.35573 1209 0.0681166 1209 3.02703 1328 First Reading 8803 8876.5 8839 8848.5 8848.5 8848.5 8848.5 8848.5 8803.5 8803.5 8803 8877.5 8877.5 8818 Last Reading 9539.5 9539.5 9503 9510 9510 9510 9510 9510 9465.5 9466 9465.5 9481.5 9481.5 9481.5 First Reading For Entire File .......... 8803 Last Reading For Entire File ........... 9539.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/08/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/08/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Scientific Technical Services Services Physical EOF Physical EOF End Of LIS File
