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194-131
STATE OF ALASKA WELLLLASKA OIL AND GAS CONSERVATION COMM! MPLETION OR RECOMPLETION REPO AND LOG 1 a. Well Status: Oil ❑ Gas ❑ SPLUG 0 Other ❑ Abandoned Q. Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 - Development p Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL ❑ No.of Completions: Zero ` Service 0 Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 12/22/2015 i 194-131 ' 315-446 3. Address: 7. Date Spudded: 15. API Number: P.O.Box 196612 Anchorage,AK 99519-6612 10/14/1994 50-029-22512-00-00 - - 4a. Location of Well(Governmental Section): g. Date TD Reached: 16. Well Name and Number: 10/24/1994 PBU 11-32 - Surface: 48'FNL,125'FEL,Sec.33,T11N,R15E,UM - 9 Ref Elevations KB 64.1 17. Field/Pool(s): Top of Productive Interval: 5052'FSL,200'FEL,Sec.28,T11N,R15E,UM GL 29.3 BF 30.49 PRUDHOE BAY,PRUDHOE OIL , Total Depth: 81'FSL,115'FEL,Sec.21,T11N,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: • 10573'/8526' ' ADL 028325&028322 - 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 707429 • y- 5951673 - Zone - ASP 4 • 11003'/8901' - 70-054 TPI: x- 707203 y- 5956769 Zone - ASP 4 12. SSSV Depth(MD/TVD): PO Thickness of Permafrost MD/TVD: Total Depth:x- 707278 y- 5957080 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No II 13. Water Depth.if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 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 SONIC/NEU/DEN e-€mfo rrn ., '?�n„ 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 34' 114' 34' 114' 30" 260 sx Arctic Set(Approx.) 10-3/4" 45.5# NT-80 34' 3970' 34' 3807' 13-1/2" 1310 sx CS III,375 sx Class'G' 7-5/8" 29.7# NT-95/13Cr80 32' 10988' 32' 8888' 9-7/8" 650 sx Class'G' 24. Open to production or injection? Yes 0 No EZI 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 10260' 10188'/8196' ,_,�-ed 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Al/A „ • C�'1 Was hydraulic fracturing used during completion? Yes IINo 0 - Gv Per 20 AAC 25.283(i)(2)attach electronic and printed nATE information a 122Ji JAN 14 2016 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED .-.RIFIED V - �0�� 10630' Sett Bail t Plug L (C 10620' 10.2 ft Bail Cement 10573' 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 1 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate �', Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only 0 M/# VIL i/z6/I' RBDMS LI- JAN 2 2 2016 . t'‘.,i4 41 28. CORE DATA • Conventional Core(s) Yes 0 No 0 Sidewall Cores Yes 0 No (7J - 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 Il • Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sadlerochit 10357' 8340' GOC 10742' 8673' Base of Sadlerochit 10837' 8755' Formation at total depth: 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Well Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Gorrell,John Email: John.Gorrell@bp.com Printed Name: Joe Lastufka Title: Drilling Technologist Signature: Phone: +1 907 564 4091 Date: /14./`� INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 1 a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • • 11-32 Well History (Pre-Rig Sidetrack) ACT1VITYDATE t (' ***WELL SI ON ARRIVAL*** (ELINE: )(FLOW' /PLUG / DB) INITIAL T/I/O = 0/325/650. LRS RU / PT/ LOAD WELL/ FREEZE PROTECT/ RD. SLB RU/ PT. RUN 1: CROSSFLOW CHECK WITH SPINNERS. PERFORM 30 &60 FPM UP/DOWN PASSES FROM PBTD TO 10550'TAG PBTD AT 10762' OBSERVE TEMPERATURE SHIFT FROM 10665'-10635' OF —10 DegF. (151 DegF TO 159 DegF) PERFORM STATIONS AT 10660'/ 10650'/ 10635'/ 10630'/ 10625' FOR A MINIMUM OF 4 MINUTES. NO FLOW OBSERVED FROM STATIONS OR UP/DOWN OVERLAYS. POOH RUN 2: SET PLUG AT 10630'/CCL TO TOP OF PLUG =22'/CCL STOP DEPTH = 10608'. SETTING CONFIRMED AT SURFACE RUN 3: DUMP CEMENT ON PLUG.(RUN 1/5). TAGGED POSISET PLUG AT 10630'. RUN 4: DUMP CEMENT ON PLUG.(RUN 2/5) RUN 5: DUMP CEMENT ON PLUG.(RUN 3/5). 8/24/2015 ***JOB CONTINUED ON 25-AUG-2015 *** ***Job continued from 8/23/15*** T/I/O= 27/250/450 Temp=S/I Assist E-line (Pre CTD) Pumped 5 bbls McOH, 260 bbls of 1% KCL for a load and kill for E Line. Freeze protected with 38 bbls of DSL. E-line in control of well upon LRS departure. Hung FP info tag on WV 8/24/2015 Final WHP T/I/O= 0/421/750 ***JOB CONTINUED FROM 24-AUG-2015 *** POOH WITH BAILER#3. RUN 6: DUMP CEMENT BAILER#4. RUN 7: DUMP CEMENT BAILER#5. 10.2FT TOTAL CEMENT DUMPED ON TOP OF POSISET PLUG. RUN 8: SET BAKER WHIPSTOCK. TOP OF WHIPSTOCK AT 10573'. ORIENTATION = 29 DEG LOHS. RD SLB. WELL SI ON DEPARTURE. FINAL T/I/O = 0/250/395 PSI 8/25/2015 ***JOB COMPLETE*** T/I/O=vac/215/389 Temp=SI MIT-T FAILED to 3000 psi , MIT-IA PASSED to 3000 psi , MIT-OA PASSED to 1200 psi (PRE RIG) Pressured up tubing with 14.6 bbls diesel to reach 3061 psi on 6th attempt. MIT-T lost 47 psi in 1st 15 minutes, 41 psi in 2nd 15 minutes and 41 psi in 3rd 15 minutes for a total loss of 129 psi in a 45 minute test. Bled down tubing psi. Pumped 4.4 bbls diesel down IA to reach 3012 psi. MIT-IA lost 72 psi in 1st 15 minutes and 19 psi in 2nd 15 minutes for a total loss of 91 psi in a 30 minute test. Bled IAP. Pressured up OA with 2 bbls diesel to reach 1223 psi. MIT-OA lost 41 psi in 1st 15 minutes and 9 psi in 2nd 15 minutes for a total loss of 50 psi in a 30 minute test. Bled OAP. Caution tags hung, 8/27/2015 AFE sign installed. FWHP's=300/280/380 T/I/O=SSV/270/390. Temp = SI. Bleed IAP & OAP to < 50 psi. (Pre-CTD). ALP @ 1990 psi &SI @ IA casing valve & Lateral valve. IA&OA FL's = Surface. See Log for Details. Bled OAP from 390 psi to 10 psi in 3 hours (fluid &gas), IAP decreased 50 psi to 240 psi during OAP bleed. Bled IAP from 240 psi to 0 psi in 30 minutes (all fluid). Bled ALP (between IA casing valve & Lateral valve)from 1990 psi to 0 psi in 15 minutes. Rig down & monitor. No change in IAP, OAP increased 10 psi to 20 psi in 1 hour&ALP @ 0+ psi. Final WHP's = SSV/0/20. Job Complete. 10/30/2015 SV, WV& SSV= C. MV =O. IA&OA = OTG. NOVP. 13:15. T/I/0=135/40/200 Installed Test spool #3 & PT to 300 psi-low&5000 psi (passed) Set 4" CIW TWC#433 @ 115"w/2" ext. & performed LTT on TWC (passed); Installed Nordic 11/24/2015 platform FWP=-TWC/40/200 RDMO ***See log for details***Job complete*** S • 11-32 Well History (Pre-Rig Sidetrack) T/I/O =SSV/35/220. Temp = SI. Bled WHP's to 0 psi (pre RIG). Well is disconnected from the system, no flow line or well house. IA FL @ surface, OA FL near surface. Bled IAP to slop trailer from 35 psi to 0 psi in —5 min (-5 gallons). Bleed OAP to slop trailer from 220 psi to 0 psi in 2 hrs (all gas). Monitor for 30 min. IAP remained at 0 psi, OAP increased to 0+. See log for details. Job complete. Final WHP's =0/0/0+. SV, SSV = C. WV= LOTO. MV= O. IA, OA= OTG. 13:30 12/3/2015 T/I/O =TWC/0/30. Temp = SI. WHPs (Pre Rig). WH &flowlines removed. 12/15/2015 SV, WV, SSV = C. MV= O. IA, OA = OTG. 13:40. T/I/O=TWC/13/271. Temp=SI. MIT-OA to 1200 psi *** FAILED ***. (Pre CTD). No AL, flowline, wellhouse, or scaffold. OA FL @ surface. Pumped a total of 8 bbls diesel down OA during MIT-OA(unable to reach test pressure) & LLRT. LLR= 1.7 gals/min @ 1100 psi. See log &Crystal data for additional information. 12/19/2015 ***JOB CONTINUED ON 12/20/15 WSR*** T/I/O=SSV/10/290. Temp=Sl. Bleed OAP <50 psi (Pre CTD). OA FL @ surface. Bled OAP to bleed tank from 290 psi to 160 psi in 2 hr @ reduced rate.(7.4 bbl return). Monitor 1 hr, OAP increased 110 psi. Final WHPs=SSV/10/270. 12/19/2015 SV, WV, SSV=C. MV=O. IA&OA=OTG. NOVP. 1500. ***JOB CONTINUED FROM 12/19/15 WSR*** MIT-OA to 1200 psi *** FAILED ***. (Pre CTD). Bled OA from 536 psi to 83 psi (1.0 bbls fluid)to slop tank in 13 mins. IAP went on a vac(-9 psi). Monitored for 30 mins. OAP increased 207 psi to 290 psi. MIT/LLRT tags hung. AFE sign already in place. Job Complete. Final WHPs=TWC/Vac/290. 12/20/2015 SV&WV= Unk (Unable to access). SSV=C. MV=O. IA& OA=OTG. 0230 hrs. • • North America-ALASKA-BP Page 1 Operation Summary Report Common Well Name:11-32 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/20/2015 End Date:12/29/2015 X3-0173J-C:(3,376,474.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00 r©64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/20/2015 18:00 - 18:30 0.50 MOB P PRE CHANGE OUT MCC BREAKER IN SCR ROOM PER AGREEMENT WITH NORDIC TO CONDUCT THIS OPERATION AT WELL COMPLETION. 18:30 - 19:30 1.00 MOB P PRE PJSM FOR MOVING RIG OFF OF DS 11-10. DISCUSSION AND VERIFICATIONS TAKING PLACE FOR MOVE: -VERIFY ALL TREE VALVES(MV,SSV,SV) ARE CLOSED FOR MOVE OFF WELL. -PHYSICAL BARRIERS,12"X 12"STOPS,WILL BE IN PLACE TO PREVENT THE RIG FROM ROLLING BACK TOWARDS TREE/WELLHEAD. -ESD WILL BE FUNCTION TESTED BEFORE MOVING THE RIG OFF THE WELLAND MANNED BY THE TOOLPUSHER OR NORDIC FIELD SUPERINTENDENT. -RADIO COMMUNICATION AND HAND SIGNALS WILL BE DISCUSSED IN THE PJSM AND VERIFIED FOR ALL INDIVIDUALS INVOLVED IN THE MOVE PRIOR TO MOVING THE RIG(SPOTTERS,ETC). -THE AGREED"COMMAND"TO STOP THE RIG MOVE WILL BE DISCUSSED AND UNDERSTOOD BY ALL. 19:30 - 20:30 1.00 MOB P PRE BACK OFF WELL AND MOVE RIG FROM 11-10AI TO 11-32A. 20:30 - 21:30 1.00 MOB P PRE PJSM FOR MOVING RIG ON TO DS 11-32A. DISCUSSION AND VERIFICATIONS TAKING PLACE FOR MOVING ONTO WELL: -VERIFY ALL TREE VALVES(MV,SSV,SV) ARE CLOSED FOR MOVE ON WELL. -PHYSICAL BARRIERS,12"X 12"STOPS,WILL BE IN PLACE TO PREVENT THE RIG FROM ROLLING BACK TOWARDS TREEMIELLHEAD. -ESD WILL BE FUNCTION TESTED BEFORE MOVING THE RIG OVER THE WELLAND MANNED BY THE TOOLPUSHER OR NORDIC FIELD SUPERINTENDENT. -RADIO COMMUNICATION AND HAND SIGNALS WILL BE DISCUSSED IN THE PJSM AND VERIFIED FOR ALL INDIVIDUALS INVOLVED IN THE MOVE PRIOR TO MOVING THE RIG(SPOTTERS,ETC). -THE AGREED"COMMAND"TO STOP THE RIG MOVE WILL BE DISCUSSED AND UNDERSTOOD BY ALL. -BP SUPERINTENDENT DAVE NEWLON ON LOCATION FOR PJSM AND MOVING OVER THE WELL DUE TO 290 PSI ON OA THAT CANNOT BE BLED OFF. 21:30 - 22:00 0.50 MOB P PRE MOVE RIG OVER WELLAND JACK DOWN RIG. RIG ACCEPTED AT 22:00. SECURE AND HEAT CELLAR PLACE BOARDS ACROSS CELLAR Printed 1/6/2016 5:48:43PM • • North America-ALASKA-BP Page 2 CA— . Operation Summary Report Common Well Name:11-32 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/20/2015 End Date:12/29/2015 X3-0173J-C:(3,376,474.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Tme:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00 664.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 00:00 2.00 MOB P PRE CYCLE TREE VALVES,STROKE SSV WITH SLB HYDRAULIC PANEL PAD OPERATOR ON LOCATION TO REMOVE LOCK ON WING VALVE OPEN SWAB,SSV,AND MASTER VALVE. ZERO PSI ON TUBING. CLOSE SWAB AND MASTER VALVE FOR LEAK TIGHT TEST. LEAK TIGHT TEST IS GOOD. REMOVE TREE CAP. 12/21/2015 00:00 - 06:00 6.00 MOB P PRE HOLD PJSM FOR REMOVING TREE CAP AND NIPPLING UP BOPE TREE VALVES CYCLED,VISUAL LEAK TIGHT TEST PER WELL PROGRAM GOOD-REMOVE TREE CAP,NO PRESSURE OBSERVED NIPPLE UP BOPE INSTALL LUBRICATOR OFFLOAD FRESH WATER TO THE RIG FOR BOP TESTING TAKE STACK MEASUREMETS GREASE/SERVICE HCRS -HOLD H2S RIG EVACUATION DRILL WITH AAR WITH NIGHT CREW -CONDUCT PRE-SPUD WITH DAY CREW AFTER MORNING PRE-TOUR MEETING 06:00 - 10:00 4.00 BOPSUR P PRE SLIGHT TRICKLE LEAK ON DOOR SEAL. CONDUCT INSPECTION ON DOOR SEALS TO CONFIRM CORRECT INSTALLATION,FIND PINCH ON ONE SEAL,REST ARE FINE. REPLACE THE ONE SEAL,RE-TIGHTEN ALL DOORS. (NOTE:EQUIPMENT MANUFACTURER SENT NEW TYPE OF DOOR SEAL FOR THEIR BOP DOORS-THESE SEALS HAVE BEEN USED WITH CDR RIG ON CONOCO SIDE WITH SOME HISTORICAL ISSUES WITH DIFFICULTY IN GETTING SEAL. THIS IS BEING LOOKED INTO BY NORDIC MANAGEMENT). -GREASE CREW VERIFIED STROKE ON SSV, ADJUSTMENT ON FUSIBLE CAP -TEST ALL AUDIBLE AND VISUAL ALARMS FOR BOP TEST -DISCUSS PRESSURE CROSSCHECKS AND CONTROL DURING BOP TEST 10:00 - 10:15 0.25 BOPSUR P PRE PUMP WATER THROUGH MGS,FLOW PATH THROUGH MGS IS VERIFIED CLEAR. Printed 1/6/2016 5:48:43PM • • North America-ALASKA-BP Page 340'5— . Operation Q► — Operation Summary Report Common Well Name:11-32 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/20/2015 End Date:12/29/2015 X3-0173J-C:(3,376,474.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA WWI:500292251200 Active datum:49:32 10/14/1994 00:00 @64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:15 - 19:00 8.75 BOPSUR P PRE FILL STACK AND ALL LINES,CONDUCT BODY TEST,TEST GOOD. -TEST BOP COMPONENTS WITH 2-3/8"AND 3-12"TEST JOINTS PER BP,NORDIC,AND AOGCC STANDARDS TO 250 LOW/3500 HIGH. FUNCTION COMPONENTS FROM DRILLER'S CONSOLE. CONDUCT DRAWDOWN TEST. FUNCTION ALL COMPONENTS FROM CTS REMOTE CONSOLE. AOGCC NOTIFIED OF BOP TEST ON SUNDAY DECEMBER 20,2015 AT 18:17 AOGCC INSPECTOR GUY COOK WAIVED WITNESS BY EMAIL ON SUNDAY DECEMBER 20,2015 AT 20:11 -HOLD PRE SPUD MEETING WITH ELLINGTON NIGHT CREWAFTER PTM 19:00 - 22:00 3.00 BOPSUR P PRE HOLD PJSM,DISPLACE DIESEL FROM COIL WITH FRESH WATER FOR PRESSURE TEST -TEST FROM KILL LINE TO INNER REEL IRON, INNER REEL VALVE,AND PACKOFFS;TEST FROM PUMP THROUGH RIG IRON TO INNER REEL VALVE TORQUE ALL TREE BOLTS WITH INJECTOR WEIGHT ON TREE 22:00 - 22:30 0.50 BOPSUR P PRE HOLD PJSM AND PULL BOP TEST PLUG-NO PROBLEMS 22:30 - 00:00 1.50 BOPSUR P PRE PJSM TO PULL TWC AND BRING DSM LUBRICATOR TO RIG FLOOR. VERIFY TREE MEASUREMENTS TO ENSURE PROPER ROD AND STROKE LENGTH. RIG UP LUBRICATOR. 12/22/2015 00:00 - 02:30 2.50 BOPSUR P PRE PULL TWC CONTINUE RIGGING UP DSM LUBRICATOR PT 250 PSI LOW/3500 PSI HIGH FOR 5 CHARTED MINUTES EACH-GOOD TEST PER CRITERIA FOR TEMPORARY PIPEWORK OPEN MASTER AND SWAB VALVES STROKE ROD IN AND ENGAGE TWC. TUBING PRESSURE=60 PSI OPEN WELL TO TIGER TANK,PRESSURE BLEEDS OFF IMMEDIATLY. SHUT IN FOR 10 MINS AND OPEN BACK UP TO CHECK FOR REPRESSURIZATION-NONE. PULL TWC TO SURFACE. CLOSE MASTER AND SWAB RIG DOWN DSM LUBRICATOR AND REMOVE FROM RIG -HOLD H2S/RIG EVACUATION DRILL WITH ELLINGTON'S CREW,NIGHTS Printed 1/6/2016 5:48:43PM • • • North America-ALASKA-BP Page 4 g14:3 Operation Summary Report Common Well Name:11-32 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/20/2015 End Date:12/29/2015 X3-0173J-C:(3,376,474.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00 @64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 05:30 3.00 RIGU P PRE HOLD PJSM,CUT COIL STAB ON INJECTOR AND PT 7-1/16"OTIS CONNECTION. BLOW BACK COIL WITH RIG AIR BLOW DOWN STACK CUT 100'OF COIL DRESS END OF COIL FOR EXTERNAL CONECTOR MU EXTERNAL SLIP TYPE CTC PULL TEST TO 42K BOOT ELINE PT CTC 250 PSI LOW/3500 PSI 05:30 - 07:15 1.75 STWHIP P WEXIT MU 3.80"WINDOW MILLING BHA ON BAKER OIL TOOLS STRAIGHT MOTOR AND DUMB IRON WORK STRING. STAB ON,PT OTS WHILE PREPARING TO RIH. 07:15 - 12:15 5.00 STWHIP P WEXIT RIH WITH BHA CIRCULATING 8.3 PPG KCL ON TRIP IN AT MIN RATE. NO ISSUES RUNNING DOWN. GET TO BOTTOM,SLOW RUNNING RATE. DRY TAG WHIPSTOCK AT 10,598' UNCORRECTED DEPTH. -PICK UP,BRING PUMPS ON AND DISPLACE WELL WITH WARM KCL AT 2.78 BPM,2100 PSI. IAAND OA PRESSURES BOTH ROSE AS WARM FLUID WAS CIRCULATED. BLEED IA FROM 925 PSI TO 25 PSI,BLEED OA FROM 660 PSI TO 0 PSI. -CHASE KCL WITH 9.45 PPG MUD SYSTEM AT 2.75 BPM,2520 PSI. RECORD SLOW PUMP RATES WHEN MUD IS ALL THE WAY AROUND. (1r��r 12:15 - 18:00 5.75 STWHIP P WEXIT MOVE DOWN,BRING RATE UP. FREE SPIN OF 2860 PSI AT 2.70 BPM. POSSIBLE 11-32PC MOTORWORK AT 10,593'UNCORRECTED DEPTH. PICK UP TO AVOID STALL,MOVE BACK DOWN SLOWLY. ENGAGE WHIPSTOCK,BEGIN MILLING FROM 10,593'AT 2.73 BPM,2915 PSI,UTILIZING SURFACE WEIGHT ON BIT INDICATOR AND TIME-MILLING. -CONSISTENT MOTOR WORK BUT PRETTY LOW DIFFERENTIAL PRESSURE AT 100-140 PSI. WOB VARIED FROM 1.3-6.4K ON SURFACE WEIGHT INDICATOR. SLACK OFF WEIGHT 23-24K. -MW IN 9.48 PPG,MW OUT 9.40 PPG 18:00 - 00:00 6.00 STWHIP P WEXIT CONTINUE MILLING PER DIRECTION FROM OCN AND BOT REP. DIFFERENTIAL MOTORWORK HAS BEEN PICKING UP SINCE 10,597'. SLACK OFF WEIGHT STAYING IN THE RANGE OF 22-23K. -CIRCULATING PRESSURE AT 2.73 BPM AT 3140 PSI,PREVIOUS FREE SPIN WAS AT 2860 PSI. WOB -SEE BOT REPORT FOR FULL MILLING OPERATIONAL PARAMETERS -DRILL TO 10600. MILL SHOULD BE EXITED. HAVE 300-400#MOTORWORK/FULL 7K WOB. NOT DRILLING AHEAD. -PICK UP TO VERIFY PARAMETERS. 2850#AT 2.73 BPM. Printed 1/6/2016 5:48:43PM • • S North America-ALASKA-BP Page 5 e3 Operation Summary Report Common Well Name:11-32 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/20/2015 End Date:12/29/2015 X3-0173J-C:(3,376,474.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/me:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00©64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/23/2015 00:00 - 02:30 2.50 STWHIP P WEXIT 2850#FREE SPIN AT 2.74 -MAKING NO HEAD WAY. PUMP SAMPLE UP. 30%CHERT PEBBLES -PUMP 15 BBL LO VIS PILL TO STIR UP. sTILL NO CHANGE. 02:30 - 03:30 1.00 STWHIP P WEXIT CALL ODE. DISCUSS OPTIONS PULL UP INTO TAILPIPE TO VERIFY WE CAN COME INTO TAIL. NO OVERPULLS, CIRC PRESSURE RAPIDLY CLIMBING LIKE WE ARE DRAGGING SOMETHING. RIH TO BOTTOM FOR FLOW CHECK HAD TWICE WERE CIRC PRESSURE JUMPED IN THE MIDDLE OF NO WERE. 03:30 - 04:06 0.60 STWHIP P WEXIT RIR TO ABOVE WHIPSTOCK 04:06 - 04:30 0.40 STWHIP P WEXIT START DYNAMIC FLOW CHECK. OUT RATE READING 0.06 HIGH. SHUT DOWN FOR PUMPS OFF FLOW CHECK. AFTER INITIAL BLEED DOWN. FLOW TO POSSUM BELLY. SHUT IN WELL PER STANDING ORDERS/ OPEN WELL UP TO A CLOSED CHOKE MONITOR WELL. CREEP OUT OF HOLE AND PUMP PIPE DISPLACEMENT.WHILE PRESSURE STABILIZE 04:30 - 06:00 1.50 STWHIP P WEXIT DISCUSS ANOMALY WITH WELL SUPERINTENDENT/WTL. DECISION IS TO MONITOR WELLBORE WHILE CONDUCTING CREW CHANGE. WELL IS NOT ON LOSSES, HOLE FULL WITH 9.45 PPG MUD SYSTEM. 06:00 - 14:00 8.00 STWHIP N DPRB WEXIT CONDUCT CREW CHANGEOUT,WSLS AND FIELD SUPERINTENDENT DISCUSS ALTERNATIVES. -UTILIZE INFORMATION FROM WELLS GROUP DATABASE,SOR AND GEO TEAM TO DETERMINE THAT THIS IS ANTICIPATED GAS POCKET OUTSIDE OF WELLBORE. -DEVELOPED PLAN FOR CIRCULATION. LINED UP THROUGH CHOKE AND CONDUCTED CIRCULATION TO CLEAN UP MUD. ONE-FOR-ONE RETURNS AND EQUALIZED MUD WEIGHT AFTER 170 BBLS. MONITOR FOR 30 MINUTES,NO PRESSURE AND NO FLOW AT FLOW CHECK. DISCUSS WITH TOWN,CONDUCT ONE MORE BOTTOMS UP THROUGH MGS,AGAIN NO PRESSURE ON CASING OR TUBING. NOTIFIED TOWN,RECEIVED PERMISSION TO OPEN UP TO WELLAND CONDUCT FLOW CHECK. FLOW CHECK ALL GOOD. 14:00 - 16:30 2.50 STWHIP N DPRB WEXIT POH CIRCULATING THROUGH MGS. NO ISSUES ON TRIP UP,MUD PROPERTIES AND FLOW RATES GOOD. FLOW CHECK AT SURFACE,ALL GOOD. -MW IN 9.45 PPG,MW OUT 9.41 PPG,NO LOSSES TO WELL -IA 0 PSI,OA INITIAL AT 338 PSI,FINAL 298 PSI Printed 1/6/2016 5:48:43PM TREE= 4-1/8"CIN FMCill r WELLHEAD FMC GEN 51 1 1 -32 SA NOTES:**'4-1/2"CHROME TBG`** ACTU TOR= BAKER C 2 KOT 1/2"X 3"ARM SPRINGS LOST 8/30/05'"* OKB.ELEV= 64.1° I BF.REV KOP= 2658' 2091' �4-112'CAMCO TRCF 4A SSSV NP,D=3.813" 20"COND, 112' Max Angle= 47 @ 5808''' LOCKED OUT 12/23/05 Datum MD 91.5#,li 40,= 10961'' Q Datum TVD= 8800'SSI D=19.124" GAS LFT MANDRELS 10-3/4"CSG,45.5#,NT-80 BTC,ID=9.950" —{ 3970' ' ST M) TVD DEV TYPE VLV LATCH PORT DATE 1 3884 3743 42 ICS-TM:D DMY BK 0 03/26/15 2 6401 5502 47 I C3-TMPD DMY BK 0 03/26/15 3 7222 6074 46 HES-TMPD DMY BK-2 0 11/06/96 L 4 8201 6758 45 HES-TMiD *DMY BK 0 01/12/06 _ 5 9179 7442 46 ITS-TMPD DMY BK-2 0 04/07/96 17-5/8"CSG,29.7#,NT-95 XO TO 13CR-80 NSCC F--1 9980" >< 6 10079 8105 35 HES-TMPD DMY BK-2 0 11/29/95 STA#4=DMY HAS EXTENDED PACKING Minimum ID = 3.813" c 2091' 4-1/2" CAMCO SSSV NIPPLE 10187' —7-518"X 4-1/2"BKR SABL-3 PKR W/KBH•22 ANCHOR SEAL ASSY,D=3.955" Iil 10248' H4-1/2"OTIS X NP,D=3.813" 4-1/2"TBG,12.6#,131CR-80 FOX, —{ 10259' \--1 10260' H4-1/2"WLEG,ID=4.00" .0152 bpf,D=3.958" 10244' Hama TT LOGGED 11/15/94 4-1/2"X 7-5/8"DELTA WHIPSTOCK — 10573' w/2 RA TAGS(8/25/15) • DUMP BALED CMT(08/25/15) H 10620' 4.�1�1�1�/4••4•4 10630' —7-5/8"POSISET PLUG(08/24/15) 1.111110.-041111111. PERFORATION SUMMARY REF LOG:LOG: WA/BHC/GR ON 10/25/94 ANGLE AT TOP PERF: 30°@ 10711' ' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ11.1 3-3/8" 6 10658-10664 C 05/31/14 3-3/8" 6 10658-10664 S 08/02/05 07/07/08 3-3/8" 6 10682-10688 S 08/02/05 07/07/08 2-7/8" 4 10710-10715 S 03/01/01 07/07/08 3-3/8" 6 10711-10726 C 12/20/08 3-3/8" 6 10732-10739 C 07/15/08II 3-3/8" 6 10756-10766 C 12/20/08 10783' HEST.TOG(07/07/08) 3-3/8" 6 10759-10765 S 07/30/95 07/07/08 1111111111 3-3/8" 6 10816-10836 S 07/07/95 07/07/08 111111111111111111111 2-1/2" 4 10824-10844 S 07/07/95 07/07/08 11111111111111111111 111111111111111111111 1111111111 .4.4.1.•.4.11 �� 4 1�� 1.11 1 10903' FISH-ELEMENT-6.0"& 1.1:1.1 a1.1:ta.1. PSTIFFENER RING-1.0"(03/19/07) BTD — 10903' 1.1.1.1.1.1.1.1.1.1• 1111111111111111111 7-5/8"CSG,29.7#,13CR-80 NSCD,D=6.875" ---111003' AIi1A1i1A1iA1•1A1•1i DATE REV BY CONIvENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/30/94 N-18E ORIGINAL COMPLETION 09/01/15 DU/JMD TREE C/0(08/06/15) WELL: 11-32 10/11/01 RN'KAK CORRECTIONS 09/01/15 CJNIJMD FULLED DSSSV RUG(08/11/15) PERMIT No: 1941310 04/02/15 JNFNJMD GLV C/O(03/26/15) 09/01/15 STF/JMD SET PLUG/CMT/WS(08/24-25/15) API No: 50-029-22512-00 04/17/15 PJC LNR/TBG-PRE RIG UPDATES SEC 33,T11 N,R15E,48'FNI-8 125'FEL 04/20/15 PJC ADD 7-5/8*CHROME CSG XO 03/27/15 JM3/PJG SET DSSSV RUG(TEMP BARIC) BP Exploration(Alaska) tiOF Thy, THE STATE Alaska Oil and Gas �_�� ofAL A sKA Conservation Commission }22 333 West Seventh Avenue ,�*,, GOVERNOR BILL WALKER Anchorage Alaska 99501-3572 ALAS Y' Main. 907 279 1433 Fax. 907 276 7542 pp14115i www.aogcc.alaska gov SC John McMullen Engineering Team Leader ( 3 BP Exploration (Alaska), Inc. ` ! �� 1. 1 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 11-32 Sundry Number: 315-446 Dear Mr. McMullen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair 41/ DATED this of August, 2015 Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMi.,0ION • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redd! p• Perforate New Pool 0 Repair Well 0 Re-enter Susp Well ❑ Other 0 2. Operator Name' BP Exploration(Alaska),Inc 4. Current Well Class: • 5. Permit to Drill Number: 194-131• 3. Address' P.O.Box 196612 Anchorage,AK Exploratory 0 Development RI ' 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22512-00-00 • 7, If perforating: 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Yes 0 No l� PBU 11.32RECEIVED Will planned perforations require a spacing exception? • p 9. Property Designation(Lease Number): 10. Field/Pools: J U L 2 2 2phi _VIS 028325&028322 ' PRUDHOE BAY,PRUDHOE OIL • ?/4/ 1 S 11. PRESENT WELL CONDITION SUMMARY AOG,CC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11003' • 8901' • 10903' 8813' 10783'(TOC) 10903'(2),Unknown(1) Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 34'-114' 34'-114' 1490 470 Surface 3936' 34'-3970' 3807' 5210 10 3/4" 34'- 2480 Intermediate Production 10956' 7-5/8" 32'-10988' 32'-8888' 8180/6890 5120/4790 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10658'-10766' 8600'-8694' 4-1/2",12.6# 13Cr80 10260' Packers and SSSV Type. 7-5/8"X 4-1/2"Baker SABL-3 Packer Packers and SSSV MD(ft)and ND(ft): 10187'/8195' 12 Attachments: Description Summary of Proposal 0 13 Well Class after proposed work: BOP Sketch Q Detailed Operations Program ❑ Exploratory 0 Stratigraphic 0 Development ®• Service 0 14 Estimated Date for Commencing Operations: 10/1/2015 • 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended EL ' 16 Verbal Approval: Date: WINJ 0 GINJ ❑ WAG 0 Abandoned 0 Commission Representative' Op Shutdown 0 GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Raese,J Kyle Email john.raese@bp.com Printed Name John M. Title Engineering Team Leader Signat - �`, / Phone +1 9075644711 Date 2/z..?.._ /r COMMISSION USE ONLY ..-- Conditions Conditions of approval Notify Commission so that a representative may witness Sundry Number: ` / 31S^41' e Plug Integrity 0 BOP Test C3- Mechanical Integrity Test ❑ Location Clearance 0 Other: Q0p ff5ii- ,-Ia 35-6or5 ; (/vtP5P i.-_.5 2455 h5' f1 1 Sys-,�.fqv Jr-cvtvetrr- s t a t lc, 25o p5 i AJlftr-na, to ph/5 placewi 2g"--1 t a.Pprovead pe. 20A-it-C -957, 1124; ') Spacing Exception Required? Yes 0 No Lii Subsequent Form Required: fa _407._ APPROVED BYTHE Approved by: P COMMISSIONER COMMISSION Date:g,VC-75 /4/17.3/7/5" /IS ORIGINAL #1711 1M---- -,.z z';1 Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval Attach in Duplicate RBDMS AUG 1 4 2015 To: Alaska Oil &Gas Conservation Commission From: Kyle Raese bp CTD Engineer Date: July 15, 2015 Re: 11-32 Sundry Approval Sundry approval is requested to plug the 11-32 casing perforations as part of the drilling and completion of the proposed 11-32A CTD sidetrack. History and current status: Well 11-32 was drilled in October 1994 with 4.5" 13Cr-80 tubing and perforations in the 7-5/8" 13Cr-80 casing. To date, this well has never been worked over or sidetracked. 11-32 has been shut-in since October 2014 for high watercut. Due to the lack of oil production this well has no remaining value and has been released for sidetrack. The CTD target has been planned to gain access to remaining Zone 1A - resources within the 11-10 pattern. Proposed plan: Approval is requested for a permit to drill a CTD sidetrack lateral from well 11-32 by the Nordic 2 Coiled Tubing Drilling rig on or around December 1, 2015. The 11-32A sidetrack will perform a single-string exit through the existing 7-5/8" casing. Kick-off will occur in Zone 2C and target Zone 1A reserves. The proposed sidetrack is a —2,420' horizontal Ivishak Zone 1A producer which will access targets north of DS 11. The lateral will be completed with a 3-1/2" x 3-1/4" x 2-7/8" 13-Chrome liner which will be cemented and perforated. This Sundry covers plugging the existing 11-32 perforations via the 11-32A liner cement job or liner top packer set post-rig (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. D / Q con cv/ . Prod✓cF0' 44.1 d off q ? ' , c y iles fc°wer, /, Tr f��� q4,1/ 74e 1457- c our 1 Ty,, �,��, rec v( 11A./c, 9//� 1 u reG / c 9 � ,^Y ay- a p/)► ire /007 forr 2,4irrov21� l'2 co✓P/7 /Z��� Pre-Rig Work(scheduled to begin October 1, 2015) Set 7-5/8" PosiSet plug. Dump bail cement. Set 4-1/2" x 7-5/8" Delta 1. E whipstock. 2. F NEL: Kill & load well. 3. F MIT-OA, MIT-IA & MIT-T. 4. V Pre-CTD tree work. Set TWC only if MIT-T fails. Rig Work(scheduled to begin December 1, 2015) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,455 psi). 2. Pull TWC and kill well (if necessary). 3. Mill 3.80"window and 10' of rathole. 4. Drill build: 4.25" OH, -620' (30 deg DLS planned). 5. Drill lateral: 4.25" OH, -1780' (12 deg DLS planned). 6. Run 3-1/2" x 3-1/4"x 2-7/8" 13Cr-80 liner leaving TOL at-10,220' MD. 7. Pump primary cement job: 40 bbls, 15.8 ppg Class G, TOC at-10,220' MD.* 8. Liner cleanout and RPM/GR/CCL log. 9. Perform liner lap test. 10. Perforate -500' liner based on log interpretation. 11. Freeze protect well to 2,500' TVDss. 12. Set TWC; RDMO. Post-Rig Work 1. V Pull TWC. 2. S Set LTP* (if needed) and GLVs. 3. T Test separator. *Approved alternate plug placement per 20 AAC 25.112(i) Kyle Raese CTD Engineer 564-4629 CC: Well File Joe Lastufka 'TREE= FMC VVEACTUATOR = R C 1 1X3 2 SA2 KOT 1/2"X 3"•4-1/2"CHROME ARM SPRINGS LOST*** 8/30/05"' ACTUATOR= BKR C OKB.ELEV= 64.1' I [I BF.ELEV= KOP= 2658' Max Angle= 47"@ 5808' 20"CONDUCTOR, 117 Datum MD= 10961' 91.5#,1340, 2091' —{4-1/2"CAMCO TRCF-4A SSSV NP,D=3.813" Datum TVD= 8800'SS D=19.124' I LOCK®OUT 12/23/05 GAS LFT MANDRELS 10-3/4"CSG,45.5#,NT-80 BTC,ID=9.950" --I 3970' ST M) TVD DEV TYPE VLV LATCH PORT DATE 1 3884 3743 42 HES-TMPD DM' BK 0 03/26/15 2 6401 5502 47 I-FS-TMPD DW BK 0 03/26/15 3 7727 6074 46 HES-TMPD DM' BK-2 0 11/06/96 4 8201 6758 45 FES-TMPD 'DMY BK 0 01/12/06 5 9179 7442 46 I-ES-TMPD DMY BK-2 0 04/07/96 7-5/8"CSG,29.7#,NT-95 XO TO 13CR-80 NSCC 1—{ 9980' X 6 10079 8105 35 IES-TMPD DW BK-2 0 11/29/95 STA#4=DMY HAS EXTENDED PACKING Minimum ID = 3.813" @ 2091' 4-1/2" CAMCO SSSV NIPPLE4, ( 10187' 7-5/8"X 4-1/2"BKR SABL-3 PKR W/KBH-22 ANCHOR SEAL ASSY,ID=3.955" 10248' H4-1/2"OTIS X NP,D=3.813" 4-1/2"TBG,12.6#,131CR-80 FOX, - 10259' I--- 10260' H4-1/2"WLEG,D=4.00" .0152 bpf,ID=3.958" 10244' —1 ELMD TT LOGGED 11/15/94 PERFORATION SUMMARYilk n ? H FISH-2 KOT 1/2"X 3"ARM SPRINGS(08/30/05) REEF LOG: WA/BHC/GR ON 10/25/94 ANGLE AT TOP PERF: 30"@ 10711' t Note:Refer to Production DB for historical pert data SIZE SPF NTERVAL Opn/Sgz SHOT SQZ a 3-3/8" 6 10658-10664 0 05/31/14 • 3-3/8" 6 10658-10664 S 08/02/05 07/07/08 3-3/8" 6 10682-10688 S 08/02/05 07/07/08 2-78" 4 10710-10715 S 03/01/01 07/07/08 3-3/8" 6 10711-10726 0 12/20/08 3-3/8" 6 10732-10739 0 07/15/08 ' 3-3/8" 6 10756-10766 0 12/20/08 3-3/8" 6 10759-10765 S 07/30/95 07/07/08 1111111111 10783' 1—{EST.TOC(07/07/08) 3-3/8" 6 10816-10836 S 07/07/95 07/07/08 1111111111111/11111 2-1/2" 4 10824-10844 S 07/07/95 07/07/08 111111111111111111111 111111111111111111114 1111111111111111111 1:'�4.;111:1`1411111 1. X11 1N e♦. O. 10903' 1 FISH-ELEMENT-6.0"& PBTD --{ 10903' A:� ::Ai: STFFENER RING-1.0"(03/19/07) 11111111111111111111 11111111111111111111 • 111111111111111111111 7-5/8"CSG,29.7#,13CR-80 NSWID=6.875" H 11003' ' DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY UNT 10/30/94 N-18E ORIGINAL COMPLETION 06/03/14 GTW/JMC REPERF(05/31/14) WELL: '11-32 10/11/01 RWKAK CORRECTIONS 06/19/14 PJC PERF CORRECTION PERMIT No:'1941310 07/18/08 JA/JMD GLV C/O(07/14/08) 04/02/15 JMNJMD GLV C1O(03/26/15) API No: 50-029-22512-00 07/22/08 SRB/SV CMF SQZ(07/07/08) 04/17/15 PJC LNR/TBG-FRE RIG UPDATES SEC 33,T11 N,R15E,48'FTL&125'FEL 07/22/08 RRK/SV ADFERF(07/15/08) 04/20/15 PJC ADD 7-5/8"CHROME CSG XO 01/13/09 RRDISV ADPERF(12/20/08) BP Exploration(Alaska) TREE= 1 1 3 2 A TY NOTES:WELL ANGLE>70'@ •"' WB LHEAD= ON MAX DOGLEG:_ '*•i•4-1/2"CHROME 'ACTUATOR= BAKER PROPOSAL TBG : CSG... OKB.ELEV= 64.1' ] [1 BF.B-EV= KOP= 2658' Max Angle= 20"CONDUCTOR —"© Datum MD= 91.5#,1+40, 2091' 4-1/2"CAMCO TRCF-4A SSSV NP,D=3.813' LOCK®OUT 12/23/05 Datum TVD= 00'SS D=19.124" 88 HES GAS LFT MANDRELS 10-3/4"CSG,45.5#,NT-80 BTC,N3=9.950" H 3970' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3884 3743 42 TMPD DMY BK 0 03/26/15 2 6401 5502 47 TMPD DMY BK 0 03/26/15 3 7222 6074 46 TMPD DMY BK-2 0 11/06/96 4 8201 6758 45 TMPD `DMY BK 0 01/12/06 7-5/8"CSG,29.7#,NT-95 XO TO 13CR-80 NSCC —1 9980' x x 5 9179 7442 46 TMPD DMY BK-2 0 04/07/96 6 10079 8105 35 TMPD DMY BK-2 0 11/29/95 STA#4=DMY HAS EXTENDED PACKING Minimum ID = 2.377" a@ 3-3/16" X 2-7/8" LNR XO MI 10187' -17-5/8"X 4-1/2"BKR SABL-3 PKR W/KBI+22 ANCHOR SEAL ASSY,D=3.955" —10220 —13.70"BKR DEPLOY SLV,13=3.00' TOP OF 3-1/2"X 3-1/4"X 2-7/8"LNR(CMT'D) —1 —10220 \ ►' IN kl, —10240 —13-1/2"HES X NP,D=2.813" i 10248'1-14-1/2"OTIS X NP,D=3.813" � 4-1/2"TBG,12.6#,131CR-80 FOX, --1 10259' 'NPN i'.f I. I J BEHIND 10260'% I4-1/2'WLEG,D=4.00" CT LNR .0152 bpf,D=3.958" II. II t I. I I 10244' --1 E MD TT LOGGED 11/15/94 I;I; e•e ie. ee I`% I`I` I`I` I+I` II. II 3-1/2"LNR,_#,13CR- ii _STL, H —10560 i )' —� �'V *lb% —10560 3-1/2"X 3-3/16"XO,ID=2.786' II/ II .0087 bpf,It 2.992" I•i ,ISI• 11.14. ‘110‘7-5/8'X 4-1/2"DELTA WHPSTOCK(XX/XX/15) --I —10580 IN SI, ,I`I` IId II ♦♦ ••• w/RA TAGS '% I` FLOUT WNDOW(11-32A) -10580'- ' 7-5/8"CSG,29.7#,13CR-80 NSCC,13=6.875" —10660 �\,,V�� ♦N',- ESTMATED TOP OF CHV1 11(XX/XXX/15) —1 —10620 ♦% ♦�.� i i i i i �il,♦ •'♦, —11000 —13-3/16"X 2-7/8'XO,D=2.377" 7-5/8"POSISET PLUG(XX/XX/15) —1 —10630 H '`♦ '` `I�� �-•� r •.•,♦ •,y —12-7/8"RA PUP JOINT PERFORATION SUMMARY �♦• �• • REF LOG: ON XX/XX/15 ♦'►"• �'�- ANGLE AT TOP PERF: • rn t1]t•t t•1t1t f t' - •• �'� —2-7/8'RA A••.� A ♦ . Note:Refer to Roduction DB for historical perf data .�:�ttifA�:�:#.f.� •♦. %• PUP JOINT SCE SPF NTBZVAL Opn/Sqz SHOT SQZ `�♦• \�l1 3-1/4"LNR,6.6#,13CR-_TC1, —11000 ♦• .0079 bpf,ID=2.850" `�♦4♦� `♦%♦ `�• # PBTD — ` „tit.„ . . ♦�_ /fi N. 2-7/8'LNR, #,13CR-85 STL,.0058 bpf,D=2A41" —1 —13000 DATE REV BY COIJVU'ITS DATE REV BY COMMENTS FRUGHOEBAY INT 10/30/94 I4-18E ORIGINAL COMPLETION WELL: 11-32A XX/XX/15 CTD SIDETRACK(11-32A) PB2MTNo: 04/19/15 KJRI PJC BUILD PROPOSAL AR Pb: 50-029-22512-01 04/20/15 KIR/PJC REV 1-CTD PROPOSAL SEC 33,T11 N,R15E,48'FNL&125'Fa BP Exploration(Alaska) i 1 I 1 1 I 6'j 3 w 5 w limit • II QgQ O itl S SI ♦F /f 1 cf i m 10 F. �/ ,vat 1 .: I ♦ 1. 1 est ,:4 I = 40 • I I i. /1E21 m- t Ire Y 1 \\\\\\\\\\\\\\ 1 _ 1 74111 f'm I g x I 1 1 1 I • to I ,. „ I J O U I . ._ I n " i QI i I +. 1 2 O 1 1 I a 1 z - 1 3 ° I O 1 1 ! I I a Ii'I- A u I 1 °„ales ses a _ U it __7.\ R 1 cc U 2 I I i I \ O .1 1 J 43— 1 • �' ;� —/ w I mei �Z 1 LYI-''' in i 8-1 r= O z F, . 6.. 1 1 0 1 i ir _ .�o11 Yo \\ ala o° 1 y +� tit IL -1' U V \ �c. 1 o in t ,, i € =„ I i U F U• t9 f A i ` 1 e m I O I = / 1 1 u 2 $ I $ 1 �S 7 u I ;1 it 13 3 5 I J C i U 1 �1 e 1 1 „. 1 ', U 1 II Intl ■� I = set a. 1._ Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the Patricia or Steve / upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" / boxes are also checked, cross out that erroneous entry and initial it on both VVV copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Patricia or Steve work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then V check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change Jenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] _ Logs of various kinds [] Other COMMENTS' Scanned bY: Beved~C"~ianna)-Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • bp BP Exploration (Alaska) Inc.' Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 21, 2010 JAN 2 4 Z(fl ' Mr. Tom Maunder JA , 0 3 all Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 AncrImge Subject: Corrosion Inhibitor Treatments of GPB DS 11 t I-I.- 13 1 Dear Mr. Maunder, 1 1 °+ 3 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 11 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, Gerald Murphy, 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 -11 Date: 12/21/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement _ pumped cement date inhibitor sealant date ft bbls ft na gal 11 -01A 1921120 50029206440100 NA Sealed NA NA 6/25/2010 11 -02 1811280 50029206490000 NA Sealed NA NA 6/25/2010 11 -03A 1911520 50029206660100 NA Sealed NA NA 6/25/2010 11 -04A 1940230 50029204800100 NA Sealed NA NA 6/25/2010 11-05A 1961570 50029206700100 NA Sealed NA NA 6/25/2010 11 -06A 2042250 50029206740100 NA Sealed NA NA 6/25/2010 11 -07 1811770 50029206877000 NA Sealed NA NA 6/25/2010 11 -08 1842290 50029212450000 NA Sealed NA NA 6/27/2010 11 -09A 1961280 50029214020100 NA 25 NA 42.50 6/29/2010 11 -10 1851590 50029213940000 NA 5 NA 28.90 6/30/2010 11 -11 1851410 50029213820000 NA Sealed _ NA NA 6/27/2010 11 -12 1841950 50029212120000 NA Sealed NA NA 9/12/2010 11 -13A 1921100 50029212290100 NA Sealed NA NA 9/12/2010 11 -16 1860780 50029215817000 NA Sealed NA NA 6/27/2010 11 -17A 2020320 50029215980100 NA Sealed NA NA 6/27/2010 11 -18 1861120 50029216070000 NA Sealed NA NA 6/27/2010 11 -22A 1950870 50029220356000 NA 1 NA 9.35 7/1/2010 11 -23A 1940810 50029216100100 _ NA Sealed NA NA 7/1/2010 11 -24A 1932040 50029216230100 NA Sealed NA NA 6/26/2010 11 -25A 1990820 50029204880200 NA Sealed NA NA 6/26/2010 11 -26 1861340 50029216280000 NA 1.9 NA 5.10 6/28/2010 11 -27 1861480 50029216380000 NA 3.5 NA 11.90 6/28/2010 11 -28A 2000950 50029219580100 NA Sealed NA NA 6/28/2010 11 -29 1940250 50029224660000 NA _ 0.2 NA 1.70 6/28/2010 11 -31A 1961830 50029225090100 NA 1.4 NA 6.80 6/28/2010 c> 11-32 1941310 50029225120000 NA 6.7 NA 59.50 6/30/2010 11 -33 1940900 50029224900000 NA 0.5 NA 2.55 6/30/2010 11 -34 1941380 50029225160000 NA 0.5 NA 3.40 11/27/2009 11 -35 1940650 50029224760000 NA 0.6 NA 5.10 6/30/2010 11 -37 1961740 50029227160000 _ NA 4 NA 42.50 7/1/2010 11 -38A 1982160 50029227230100 NA 2.1 NA 22.10 6/28/2010 I I1 02/18/09 _^~~ Schlum~erg~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh !t N0.5089 Company: State of Alaska >'+y=:N,? ~ "~~ ,. ~~~;~ Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Inn rln~nr:nf:..n Hate nl n..~..., nn R-40 AWJI-00012 MEMORY GLS l 1 12!12/08 1 1 P2-35 AWL9-00010 BAKER IBP/CROSSFLOW DETERM - / 01/02/09 1 1 P2-20 AYTO-00004 PRODUCTION PROFILE _ ~ d ~ 02/05/09 1 1 4-10A/L-28 AYKP-00009 IBP/CROSSFLOW DETERMINATION CJ - 02/04/09 1 1 B-36 11999060 RST ~j/ 11/10/08 1 1 11-32 12071914 RST G ~ 11/30/08 1 1 C-23C AXOY-00006 MCNL ~ 12/11/08 1 1 L2-16 12071912 RST .. ~ 11/28/08 1 1 L2-32 12113026 RST ~~ ( '~ . '~- 12/07/08 1 1 L2-24 12113025 RST 12/06/08 1 1 ~GGr~JG NVI~I\V YYLGNLIC nCV CIPI pl .71171V 11YU AIVV nCl Unrvlrvl7 VItlC l.Vl'T CMI.I'1 1 V: BP Exploration (Alaska) Inc ",~ Petrotechnical Data Center L~ ~ ~ _~ ~t 900 E. Benson Blvd. Anchorage, Alaska 99508 ~()(i~~ Date Delivered: ~° R., .w~ '• _, , - . e Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ,t Anchorage, AK 99503-28 8 ATTN: Beth ~\ 1 ReceivedReceived by: I '--~ • • r ~ STATE OF ALASKA ,, ''J~~ ~~ ~ I ALA OIL AND GAS CONSERVATION COM~ION ~ ~~ REPORT OF SUNDRY WELL OPERATIONS E[~ ~~ <<- (' 2 ~ ~nn~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time~Et'ro~ G aSCOfiS. GOiiti'ti Change Approved Program ~ Operat. Shutdown ~ Perforate 0 ' Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 194-1310 - 3. Address: P.O. Box 196612 StratigraphlC ~" Service 6. API Number: Anchorage, AK 99519-6612 50-029-22512-00-00- 7. KB Elevation (ft): 9. Well Name and Number: 64.1 KB ~ PBU 11-32 - 8. Property Designation: 10. Field/Pool(s): , ADLO-028322 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11003 ~ feet Plugs (measured) 10700/10754 true vertical 8901.26 ~ feet Junk (measured) 10903' Effective Depth measured 10903 feet true vertical 8813.1 feet Casing Length Size MD TVD ~ Burst Collapse Conductor 82 20" 91.5# H-40 30 - 112 30 - 112 1490 470 Surface 3941 10-3/4" 45.5# L-80 29 - 3970 29 - 3807 5210 2480 Production 10975 7-5/8" 29.7# NT-95 28 - 11003 28 - 8901 8180 5120 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 28 - 10260 0 0 - Packers and SSSV (type and measured depth) 4-1/2" Baker SABL-3 Packer 10187 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): r L JAN A ~ X009 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: 26 1902 3982 366 Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development 1~- - Service lT Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas r WAG ~® GINJ ~ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre ~ Title Data Management Engineer Signature Phone 564-4944 Date 12/22/2008 iSi;~i ; Form 10-404 Revised 04/2006 ~_ ~~ Submit Original Only 11-32 194-1310 DGDF ATTA(_NMFNT i Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 11-32 11/15/94 PER 10,824. 10,844. 8,744.16 8,761.56 11-32 7/7/95 RPF 10,816. 10,836. 8,737.22 8,754.6 11-32 7/30/95 APF 10,759. 10,765. 8,687.73 8,692.94 11-32 3/1/01 APF 10,710. 10,715. 8,645.18 8,649.52 11-32 4/15101 BPS 10,754. 10,903. 8,683.39 8,813.1 11-32 8/2/05 APF 10,658. 10,664. 8,600.02 8,605.23 11-32 .8/2/05 APF 10,682. 10,688. 8,620.86 8,626.07 11-32 8/2/05 BPS 10,700. 10,700. 8,636.49 8,636.49 11-32 3/17/07 BPP 10,700. 10,700. 8,636.49 8,636.49 11-32 3/19/07 BPP 10,754. 10,903. 8,683.39 8,813.1 11-32 7/7/08 BPS 10,783. 10,844. 8,708.57 8,761.56 11-32 7/7/08 SQZ 8,390. 10,793. 6,890.66 8,717.25 11-32 7/15/08 APF 10,732. 10,739. 8,664.29 8,670.37 11-32 12/20/08 APF 10,711. 10,726. 8,646.05 8,659.08 11-32 12/20/08 APF 10,756. 10,766. 8,685.13 8,693.81 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 11-32 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 12/20/2008'"**WELL SHUT-IN ON ARRIVAL*** T/1/O 200/1200/500 RU ELINE FOR 3-3/8: HSD, 6 SPF, 60 DEGREE PHASE PERFORATIONS OF INTERVALS 10,756-10,766 FT AND 10,711- : 10 726 FT. TAGGED TD AT 10769.8 GUN 1: CCL STOP DEPTH:10748.9'. CCL TO TOP SHOT: 7.1' 'GUN 2: CCL STOP DEPTH:10698.8'. CCL TO TOP SHOT: 12.2' TIED IN TO BHC ACOUSTIC LOG DATED 25-OCT-94, CEMENT BOND LOG DATED 11-NOV-1994 ~ FINAL T/I/O = 250/1200/500 'WELL SHUT IN ON DEPARTURE ;'`''"JOB COMPLETE'"" FLUIDS PUMPED BBLS 1 diesel 1 Total STATE OF ALASKA ~ ~ ~- ~ ~ ~~ ~~~~~~~~~~ ~~Ol ALA OIL AND GAS CONSERVATION COMI~IO~JI~ ~ ~ ~~;~ REPORT OF SUNDRY WELL OPERATIONS ~r ,~. 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ S i ulate Othc~r~ ''^f~IRZE Performed: Alter Casing ~ pull Tubing ~ Perforate New Pool ~ Waiver ~'~ii~is Exten~on Change Approved Program ~ Operat. Shutdown ~ Perforate Q Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~' Exploratory ~ ~ 194-1310 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~I 6. API Number: Anchorage, AK 99519-6612 50-029-22512-00-00 7. KB Elevation (ft): 9. Well Name and Number: "~, 64.1 KB '~ PBU 11-32 8. Property Designation: 10. Field/Pool(s): ADLO-028322 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11003 feet Plugs (measured) 10700/10754 true vertical 8901.26 feet Junk (measured) 10903' Effective Depth measured 10903 feet true vertical 8813.1 feet Casing Length Size MD TVD Burst Collapse Conductor 82 20" 91.5# H-40 30 - 112 30 - 112 1490 470 Surface 3941 10-3/4" 45.5# L-80 29 - 3970 29 - 3807 5210 2480 Production 10975 7-5/8" 29.7# NT-95 28 - 11003 28 - 8901 8180 5120 Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 28 - 10260 0 0 - Packers and SSSV (type and measured depth) 4-1/2" Baker SABL-3 Packer 10187 0 _ _.__ _ 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): s~e~~~~ ~~~ ~ 208 ~~ e~ ~ .. uo 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: 34 .1851 4119 776 Subsequent to operation: 119 5824 13947 353 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~ Development Service I Daily Report of Well Operations X 16. Well Status after proposed work: OiI 'i Gas ~ WAG ~l, GINJ "' WINJ ~ WDSPL ~' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature ~ Phone 564-4944 Date 7/23/2008 C ~ Form 10-404 Revised 04/2006 ; ~ ~ n' n ~ _ .F V' 1~ ~ ~ ~ Submit Original Only ~ ~ e 5 v ,L.11 l 1 11-32 194-1310 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 11-32 11/15/94 PER _ 10,824. 10,844. 8,744.16 8,761.56 11-32 7/7/95 RPF 10,816. 10,836. 8,737.22 8,754.6 11-32 7/30/95 APF 10,759. 10,765. 8,687.73 8,692.94 11-32 3/1/01 APF 10,710. 10,715. 8,645.18 8,649.52 11-32 4/15/01 BPS 10,754. 10,903. 8,683.39 8,813.1 11-32 8/2/05 APF 10,658. 10,664. 8,600.02 8,605.23 11-32 8/2/05 APF 10,682. 10,688. 8,620.86 8,626.07 11-32 8/2/05 BPS _ 10,700. 10,700. 8,636.49 8,636.49 11-32 7/2/08 SQZ 0. 10,688. 0. 8,626.07 11-32 7/15/08 APF 10,732. 10,739. 8,664.29 8,670.37 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED 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 11-32 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ A TIVITYDATE SUMMARY 7/1/2008 CTU #6, Cement Squeeze; MIRU unit - Stand by for cement. Continued on 7/2/08 WSR ... 7/2/2008"°:CTU #6, Cement Squeeze; Continued from 7/1/08 WSR ... Conduct 'weekly BOPE test. Wait on cement test results. Load and kill well with 1 % ', 'KCL. Pre-squeeze injection = 4.5 bpm @ 500 psi WHP. RIH w/ 2.5" ', 'BDJSN. Performed cement saueeze per program. Pumped total of 96 bbls LARC cement. Well took first 30 bbls of cement behind pipe with minimal -WHP. An estimated total of 58 bbls cement was squeezed behind pipe. _ Achieved approx. 2300 psi delta at perfs. RIH contaminating to 10780' -ctmd. Squeeze broke down during ~iPan r,~~t while POOH through perfs at `10662' ctmd. POOH circulating and eventually lost all returns. Prep to re- squeeze. Flush well bore with KCL, injection rate 4 bpm @ 850 whp. 'Continued on 7/3/08 WSR ... 7/3/2008-CTU #6, Cement Squeeze; Continued from 7/2/08 WSR ... Continue ';jetting tbg and jewelry. Clean sump to flag at 10838. POH. Recover ball. ', '' MU/2.5" BDJSN. Stand by for cement and remaining fluids. Cement ', 'j parameters not met. Consult with town engineering. Clarify cement ', 'requirements. Cement to be re-blended and tested. CTU to RD and move on to another job while new cement blend is tested. **** Job Incomplete x*** __ __ .. 7/5/2008CTU #6, Re-Squeeze; MIRU - MU 2.5" BDJSN (1/2 ball) -RIH w/loading -well -Tag TD at 10796' ctm. Continued on 7/6/06 WSR ... 7/6/2008CTU #6, Re-Squeeze; Continued from 7/5/08 WSR ... Tag TD at 10796' - PU 10' paint RED flag at 10786' - PUH above perfs continue pumping do ::coil to cool sump w/ Batching cement -Load BS w/diesel - fix pump 47 bbl ARC; cement at 15.8 ppg -obtain 2162 (15 min) surface WHP - 26 bbls =cement behind pipe, -wash out to 10780 -Make two passes from - 10780 - TT at 10220. POOH C~3 80%. Started to lose circulation just after passing :.upper perf interval. Continue POOH chasing contaminate cemen o surface. FP well to 2500' while POOH. Well shut in, WHP bled from 500 psi ''to 0 psi. Call out more cement to be loaded. Let well sit for 7 hours. 'Perform in'ectivit test• 0.5 b m @ 1070 psi WHP, 1.0 bpm @ 1435 psi WHP. 1.5 bpm C~ 1720 psi WHP. Wait on cement test results. egin ;loading well with 1%KCL. RIH 2.5" BDN assy. Continued on 7/7/08 WSR ', • ~ 7/7/2008 CTU #6, Re- Squeeze; Continued from 7/6/08 WSR ... RIH and load well - Tag TD at 10793' ctm -Batch cement and load back side with diesel. Cool sump until cement ready. Mix /Pump /Displace 48.5 bbls 15.8 ppq LARC ''cement - est 7 bbls behind pipe on initial laving in of cement. Closed choke '':and pumped additional 2.3 bbls cement behind pipe to pet 600 psi pressure ''bump. Opened choke and layed in remaining cement. PUH to safe. '':Saueeze est total 38 bbls of cement to perfs. Hesitated and achieved a final ',squeeze pressure of 2350 psi WHP before thickeninig time ran out. RIH 'land contaminated cement to 10783' ctmd. Circulated and chase out at '80% holding 350 psi WHP. Maintained good 1 for 1 returns throughout. FP ''well to 2500' with 50/50 methanol. Left well shut in. RD CTU. *** Job Complete *** 7/13/2008."*"WELL SHUT IN ON ARRIVAL'`*` 'CURRENTLY RIGGING UP SLICKLINE UNIT. ''""CONY WSR ON 7/14/08'`"` 7/14/2008!:. *'* CONY FROM 7-13-08 WSR *** ''DRIFTED WITH 3-3/8" DUMMY PERF GUN, TEL, SAMPLE BAILER ''TAG TT AT 10,256' SLM (10,244' ELMD) °iTAG TD AT 10762' SLM (10,750' ELMD). RECOVERED CEMENT IN S- '`^BAILER. SET SS-CATCHER AT 6,453' SLM. ?:PULL BK-DGLV FROM STA #1 (3884' MD). 'PULL BK-DGLV FROM STA #2 (6401' MD). ''SET BK-OGLV IN STA #1 (3884' MD). 'SET BK-LGLV IN STA #2 (6401' MD). -PULL EMPTY SS-CATCHER SUB. "** LEFT WELL SHUT IN. TURNED OVER TO DSO *** 7/15/2008 """"WELL SHUT-IN ON ARRIVAL. T/I/0=600/***** PERFORATE 10732'-10739' WITH 3 3/8" HSD PJ HMX. CHARGE DATA:3406 PJ 6 SPF, 38.6" PENE, 0.45" EH, 22.7 GMS. CORRELATED TO PROD LOG 3-SEP-07. ;FINAL T/I/O = 500/500/500. WELL LEFT SHUT-IN. DSO NOTIFIED. ***JOB COMPLETE*'"' FLUIDS PUMPED BBLS 151 diesel 79 50/50 METH 327 1 %KCL 95 BIOZAN 50 CONTAM 48.5 CEMENT 750.5 Total os/zs1o~ ~GhlUmber~ge~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~;~~~~~p NQV ~ 7 2007 wou L.r. ~ 1 .,.. na~...:..r...., N0.4440 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay n~re al r.,~... rn 15-39A 11661174 MEMORY PROD PROFILE _ 09/23/07 W-42 11745235 MEM SBHPS/TEMP 09/14107 1 Z-07A NIA SBHP SURVEY - 09/14/07 1 A-04 11594519 SBHP SURVEY a - 08/26/07 1 Y-24 11630499 LDL 09/04107 1 L5-28A 11855810 PRODUCTION PROFILE - b 08/31/07 1 X-33 11849931 SBHP SURVEY S _ yc 08131/07 1 E-14A 11686784 LDL ^~ ~ 09/23107 1 01-15A 11855509 DDL ~ - old b 09/22/07 1 D-21 11626119 PRODUCTION PROFILE '~fa - 09/11/07 1 K-07D 11745234 MEM PROD PROFILE C _ 09106!07 1 11-32 11630498 PRODUCTION PROFILE ~ 'C. _ 09/03/07 1 L-01 11745233 MEM LDL a (~ ~ - ~ 09/04/07 1 07-30A 11661168 MEM STP & CORRELATION - 08/28/07 1 Z-28 11630500 INJECTION PROFILE ~_ 09105107 1 Z-16 N/A SBHPSIJEWELRY / 09113/07 1 14-26 11676959 LDL --/J 09/09/07 1 04-02A 11630504 LDL ~ 09/11/07 1 14-37 11695075 LDL 09/13/07 1 3-351E-36 11630502 PRODUCTION PROFILE 09109107 1 YLtHSt HI:RNVWLtUt9t Ktla1Y 1 FSY SItiNIN(a ANU-Kk.l UKNlN{fd•'O.,IVt GVPY tAGK tV: BP Exploration (Alaska) Inc. ~ i~ , ~~ J Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ , ~~'~° ~ ~ '~~1,(~~d Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ' Anchorage, AK 99503-26 ATTN: Beth Received by: :~ • Schlumberger NO. 4459 Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth $;~Ma> GC1 3 1 ZDD? Company: State of Alaska Alaska Oil & Gas Cons Gomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 " ~~ Field: P.Bay, Endicott, Aurora, Milne Pt.,LisburnE WII L D C J b# D CI e 0 og escnptlon ate BL o or D F-48 11846815 USIT 1'1 1-- ()~ 'I~ 10/12/07 1 G-19A 11890315 USIT i<-i"ì - U)'~ 09/30/07 1 NGI-13 11890313 USIT 'YI..{' t1-" Íf'-oGt/ 09/30/07 1 MPE-30A 11855817 USIT ~ól -Oll 10/01/07 1 - F-11 B 11649954 MCNL ;) cf-I- 10(.( "II: ,~...., -1' ') 03/22/07 1 1 W-12A 11418301 MCNL }'ì1f -/"ð'd ... 1 ~ç-::¡ '-I 09/10/06 1 1 11-27 11637127 RST j/¡(l" - IY7r it. ) ~"'-:}~ 06/05/07 1 1 02-22A 11216214 MCNL f.)tü - h~C>¡ 1f; JS~ .r'+ 10/02/06 1 1 01-16 11630486 RST J~ l'fr-QO'X ....j .c:;-'-:'-1-:8' 06/28/07 1 1 01-14 11801086 RST II'". ~".ì-- t"I'4-? tt ¡ K-:-' +'-i 07/07/07 1 1 L5-05 11767129 MCNL /, .... "":} -()~q * . "Cd 0 06117/07 1 1 D-21 11626119 RST 1'tr::::J -t'l~.;) .... I~xl 09/12/07 1 1 14-15 11221550 RST t'ir I - Ó'(jL( .,. I":::JJ 'Xc-J 03/07/06 1 1 D-18A 11695074 RST 0{)/- 1f)?J ¢. 1':'-.:'1 "7S 08/28/07 1 1 14-05A 11813055 RST I-e,::) -(10 I .. 1~1f ~ 06/11/07 1 1-23/0-15 11846802 RST ¡J~.('_ Lq(.('-I::1~ 11 ,< ~155 08/11/07 1 S-03 11223120 RST //¡(/ - /14,\ ¢ tfÇ"~(.1 06/13/06 1 1-09A1L-21 11849930 RST lo.~ - ().9G 11: ~S- + ~ 08/04/07 1 1 P2-19A 11649963 MCNL ')ö+- ()Id ~ 15'5~d 04/22/07 1 1 OWDW-NW 11211370 RST lJ T1' ,-, ~J~ :l15.,,)"9-1 02/28/06 1 1 K-01 11695073 RST l";f'~ - If) I ~ 1007-ò 08/27/07 1 1 11-32 11630498 RST D¡t.f- 131 *" /~5l.,.'1 09/03/07 1 1 3-25B/L-27 11630490 RST .;)ö~ - ~~ I ... . ,ç<:7_ 'X" 07/26/07 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 Gambell Street, Suite 400 """".g.. AK "''''''''¿ ATTN: Beth ~ Received by: G ,," Date Delivered: 1 0/23/07 . . 11-32 (PTD #1941310) Classified as Problem Well e e Sub.iect: 11-32 (PTD 4- I 94131 0) Classified as Prohlem Well From: "Reeycs, Donald F" <RccvcsDf@bp.com:> D~\tc: Wed. 28 Dec 2005 16:00:03 -0900 To: "Cooper, Kalrilla N" <Katrina.Coopcr([/~bp.com>, "GPB, FS2íCOTU Area Mgr" <GPBFS2TL@bp.com>, "Rossberg, R Steven" '<Steven. Rossberg(i.i)bp.com>, "NSU, ADW Well Operations Supervisor" <NSüADWWeI10perationsSupcrvisor~.l}hp.com>, "GPB, Wclls Opt Eng" <GPß\VcllsOptEng~~~;bp.col1l:>, "AOGCC Jim Rcgg (E-mail)..<~jim._ycgg(f/~admin.state.ak.us>. "AOGCC Winton Aubert (E-mail)..<\vinton__aubert@admin.statc.ak.us>. "NSU, ADW WI.. & Completion Supervisor" <!\Sl.iADWWL&ComplctionSupervisor@bp.com>, "GPB, FS2 DS Ops Lcad" <GPBFS2DSOpsLead«i~bp.com>. "GPB, Wells Opt Eng" <GPBWcllsOptEng@bp.com>, "GPB, Ops Mgr" <GPBOpsMgr@bp.com>. "Engel, Harry R" <Harry.Engel@bp.com> CC: "NSlJ, ADW "Veil Integrity Engineer" <NSUADWWclllntegrityEnginecr@bp.com>, "Wïnslow, Jack L." <Lyonsw@bp.com>, "~'Iolt, Ryan P (VECO)" <Ryan.Holt@bp.com> All, Well 11-32 (PTD #1941310) has been identified with IA pressure> 2000 psi and has been classified as a Problem well. TIO's on 12/27/05 were 600/2100/950 and the well failed a TIFL on 12/27/05. The plan forward is as follows: 1. SL: Run DGLV with extended packing in sta# 4 2. DHD: Re-TIFL A wellbore schematic is attached. Please call if you have any questions. «11-32.pdf» Thanks, Donald Reeves Well Integrity Engineer - Filling in for Anna Dube 907 -659-5102 907-659-5100 Pgr 1154 Content-Description: 11-32.pdf 1 Content-Type: application/octet-stream Content-Encoding: base64 <SCf ClS;') .A,~ p (~¡) ~ Þ1Jqf ,/ Z 5, 7 (,'21) I R z ~., JOk -fRc Cð 4Ct7- Z 45'"ï." ~f' ~ Z{'Dv 9/1(;0 oA qC;V 5vo r;-) ~c?11 '¿/?~/{)ç 1 of 1 12/30/2005 8:29 AM TREE = WB..LHEAD = A CTUA TOR = KB. B..EV = BF. ELEV = KOP= Max Angle = Datum MO = Datum TVD = FMC CrN BKRC 63' - 2658' 47 @ 5808' 10960' 8800' SS 110-314" CSG, 45,5#, NT-80, ID = 9,953" Minimum ID = 3.813" @ 2091' 4-1/2" CAMCO TRFC4A SSSV NIPPLE 4-1/2" TBG, 12.6#, i3-CR-80, 0.0152 bpf, ID = 3.958" 10260' PERFORA TION SUMMARY REF LOG: WA/BHC/GR ON 10/25/94 ANGLE AT TOP ÆRF: 30 @ 10658' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10658 - 10664 0 08/02/05 3-3/8" 6 10682 - 10688 0 08/02/05 2-7/8" 4 10710 - 10715 C 03/01/01 3-3/8" 6 10759 - 10765 C 07/30/95 3-3/8" 6 10816 - 10836 C 07/07/95 2-1/2" 4 10824 - 10844 C 07/07/95 I PBTD I 10903' I 7-5/8" CSG, 29.7#, NT-95, ID = 6.875" I 11003' DATE REV B 10/30/94 10/11/01 08/03/05 08/30/05 08/31/05 COMMENTS GINAl COM PlETlON CORRECTIONS & IBP GLV CIO SAFETY NOTE (FISH) DATE 11-32 SA-' NOTES: ***4-1/2" CHROME TBG*** ***2 KOT 1/2" X 3" ARM SPRINGS LOST 8/30/05*** . 2091' --{4-1/2" CAMCOTRCF-4A SSSV NIP, ID=3.813" I ST MO TVO 1 3884 3743 2 6401 5501 3 7222 6074 4 8201 6758 5 9179 7442 6 10079 8105 GAS LIFT MANORB..S OEV TYÆ VLV LATCH 42 HES- TMPD DMY BK-2 47 HES-TMPD DMY BK-2 46 HES- TMPD DMY BK-2 46 HES- TMPD DMY BKP 46 HES- TMPD DMY BK-2 35 HES-TMPD DMY BK-2 PORT DATE o 08/30/05 o 08/30/05 o 08/30/05 7-5/8" X 4-112" BKR SABL-3 PKR WI KBH-22 ANCHOR SEAL ASSY, ID = 4.00" 10248' --14-1/2" OTIS X NIP, ID = 3.813" I 10260' - 4-1/2" WLEG, 10 = 4.00" I 10244' H B..MD TT LOGGED 11/15/94 REV BY COMMENTS --{3" BAKER IBP (08/02/05) I -]3-3/8" BAKER IBP(04/15/01) I PRUDHOE BA Y UNIT WB..L: "11-32 ÆRMIT No: "1941310 API No: 50-029-22512-00 SEC 33, T11 N, Ri5E, 112.12' FB.. & 5198.49' FNL BP Exploration (Alaska) '\ STATE OF ALASKA ) AlA~..A Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS \ 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 64.1 KB 8. Property Designation: ADlO-028322 11. Present Well Condition Summary: Total Depth measured 11003 true vertical 8901.26 Effective Depth measured 10903 true vertical 8813.1 Casing Conductor Surface Production length 82 3941 10975 Size 20" 91.5# H-40 10-3/4" 45.5# l-80 7 -5/8" 29.7# NT -95 Perforation depth: Measured depth: 10658 - 10664 True Vertical depth: 8600.02 - 8605.23 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of logs and Surveys Run Daily Report of Well Operations Oil-Bbl 217 x Plug Perforations [2] Perforate New Pool D Perforate [2] 4. Current Well Class: Development[;t: Stratigraphic .D 1 .? 20 ". '-" D5 Stimu~ate D .', 9~r,~~'Q." WalverD Time Ext~nslon't~~r' Re-enter Suspended'W-~lItDC" 5. Permit to Drill Number: Exploratory Service 194-1310 6. API Number: 50-029-22512-00-00 9. Well Name and Number: 11-32 1 O. Field/Pool(s): PRUDHOE BAY Fieldl PRUDHOE Oil Pool feet feet Plugs (measured) Junk (measured) 10700, 10754 None feet feet MD 30 - 112 29 - 3970 28 - 11003 TVD 30 - 112 29 - 3807.45 28 - 8901.26 Burst 1490 5210 8180 Collapse 470 2480 5120 Ln ~'l D .,.11. 'i 2. 0 pr¡, SC1\~,'~N¿L): ,J I~:.·r I (\ .. ' " 10682 - 10688 8620.86 - 8626.07 4-1/2" 12.6# 13CR80 28 - 10260 4-1/2" Baker SABl-3 Packer 10187 RBDMS BFl SEP 1 3 2005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 1187 10317 900 SHUT-IN 600 15. Well Class after Droposed work: Exploratoryr Development R' 16. Well Status after proposed work: OilP' Gas r WAGr Tubing pressure 1400 2400 Service r WDSPl r GINJ r WINJ r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal .... L Signatu~. (?~AM Form 10-404 Revised 04/2004 Sundry Number or NIA if C.O. Exempt: NIA Title Data Mgmt Engr Phone 564-4424 Date 9/9/2005 "', .~" ~\NAL Submit Original Only } ) ) 11-32 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 8/2/2005 Run #1: 3 3/8" PJ HSD 3406 from 10682' to 10688' Run #2: 33/8" PJ HSD 3406 from 10658' to 10664' Run #3: 3" Baker IBP set @ 10700' 3" IBP has 1 3/4" f.n, 2 cover rubbers & 11' oal. Logs correlated to SLB Cement Bond Log dated 11-NOV-1994 Well pressures remained constant throughout job (WHP/IA/OA: 1400/1950/800 ) FLUIDS PUMPED BBLS 1 Diesel 1 TOTAL 1 r-32 (PTD#194131 0) Classified as Problem ,u""f ) s~.~j.e.ctf.···¡.l·....lr$.;Z.ii€~~~'i~].~~~;j<,l:ø)r,~~~§S'ì~ê~.;·..~S'Hr¿~î~ln.·.·Wel·l··..'.' Fr'111:....I'~d~1".S;~.·.:[9·~···.~tl..;·.5~4~r§22.@J~g.p?~?> . ~1)~~:Thl,h2$..Äu; ·2QQ5.4.o:.39:1$:"080~ .' . All, Well 11-32 (PTO #1941310) has been identified with IA pressure> 2000 psi and has been classified as a Problem well. TIO's on 08/25/05 were 1900/2380/0, the well is currently on-line. The plan forward is as follows: 1. SL: Run DGLV's 2. DHD: Re-TIFL A well bore schematic is attached. Please call if you have any questions. «11-32. pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com SCl\NNb~t!1 SFP ~} Content-Description: 11-32.pdf Content-Type: application/octet-stream Content-Encoding: base64 ¿LA D f7~ t I wf7; 5 Z ( 0 ps; ~ W-\{P 1Þf.(~ ût..- f'l(.t Cvú c¡ L ~ss~ ~~qet(: ~D ~1\11 1111()~ J:7\. 5.:P '2 3't.Df?~ J ~~ '.,p ;Vy~. 1 of 1 9/2/2005 9:38 AM TREE::: FMC WELLHEAD::: CIW ACTUATOR:::: BKH è KB ."·EiE\η·~"········ ·····""···.."'···"'····'''63: BF."'êL'Bl";"" '. KOP';""'" Max Angle ::: Óätüm MÔ ::: 'ÖätUn1iVO;"; . ) ~".",I,o'1,¡.:I",I.I:II",."I.>',,)F -, 2658' " '" IT ,''''1" 47 @ 5808' .... "'1Ó960" .... .. à¿OOiSS 110-3/4" CSG, 45.5#, NT-80, 10::: 9.95~'¡" -t 3970' ~ Minimum ID = 3.813" @ 2091' 4..1/2" CAMCO TRFC-4A SSSV NIPPLE 4-1/2" TBG, 12.6#, 13~CR~80, -1 1Ó260' I 0.0152 bpf, 10::: 3.958" ÆRFORA TION SUMMARY REF LOG: WA/BHC/GR ON 10/25/94 ANGLE AT TOP PERF: 30 @ 10658' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 10658 - 10664 0 08ï02/05 3-3/8" 6 10682 - 10688 0 08/02/05 2-7/8" 4 10710 - 10715 C 03/01/01 3-3/8" 6 10759 - 10765 C 07/30/95 3-3/8" 6 10816 - 10836 C 07/07/95 2-1/2" 4 1 0824 - 1 0844 C 07/07/95 I PBTD 1-1 10903' 17-5/8" CSG, 29.7#. NT-95, ID::: 6.875" 1-1 11003' DA TE REV BY COMMENTS 10/30/94 ORIGINAL COM PLETION 10/11/01 RN/KAK CORRECTIONS 08/03/05 GJBiTLH ADPERFS & IBP 11 -32 e L- SAFE1Y NOTES: ***4-1/2" CHROME TBG*** ) 2091' 1--14-1/2" CAMCO TRCF-4A SSSV NIP, ID::: 3.813" I ... ST MD 1 3884 2 6401 3 7222 4 8201 5 9179 6 10079 lVO 3743 5501 60'14 6758 7442 8105 GAS LlFr MANDRELS OEV TYPE VLV LATCH 42 HES-TMPD BK-2 47 HES-TMPD BK-2 46 HES-TMPD BK-2 46 HES- TMPD BKP 46 HES-TMPD BK-2 35 HES- TMPD BK-2 PORT DATE J k I 10187' 1- 7-5/8" X 4-1/2" BKR SABL-3 PKR W/ KBH-22 ANCHOR SEAl.. ASSY, 10 =: 4.00" I I l 10248' 1-l4-1/2" OTIS X NIP, 10 =: 3..,813" I I 10260' 1-14-1/2" WLEG, 10 =: 4.00" 1 L 10244' 1-1 E=L'v.1D TT LOGGED 11/15/94 I ---l 10700' 1-13" BAKER IBP (08/02/05) I ~~ DA TE REV BY COMMENTS 10754' 1-1.3-3/8" BAKER IBP(04/15/01)] I PRUDHOE BA Y UNIT WELL: 11-32 ÆRMIT No: 1941310 API No: 50-029-22512-00 SEC 33, T11 N, R15E, 112.12' FEL & 5198.49' FNL BP Exploration (Alaska) Bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P,O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 28, 2001 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: Pmdhoe-EOA, Pt. Mac, & Lisbume Well Work This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for February 26 - March 4, 2001' Well 03 -28 02-34A i5-41A 16-05Ai 13-27A 15-35 Work Planned REPERFORATION CT SET CIBP FOR GSO CTD SIDETRACK (NABORS CDR1) CTD SIDETRACK (NABORS 3S) CT ADD PERFORATION W/WORK PLATFORM ADD PERFORATION ADD PERFORATION 16-21 REPERFORATION S-101 ADD PERFORATION If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at raufpc @bp.com. :inauierce. lyl f~ ~ ~~ Technical Assistant, BPXA Alaska Drilling & Wells bp February 28, 2001 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: Pmdhoe~EOA, Pt. Mac, & Lisbume Well Work This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for Februm3, 26 -·March 4, 2001: Well 03 -28 02-34A 15-41A 16-05Ai 13-27A r..-:'.i:-'t~t:-32~ ~i ~. 15-35 16-21 S-101 Work Planned REPERFORATION CT SET CIBP FOR GSO CTD SIDETRACK (NABORS CDR1) CTD SIDETRACK (NABORS 3S) CT ADD PERFORATION W/WORK PLATFORM ADD PERFORATION ADD PERFORATION REPERFORATION ADD PERFORATION If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at raufpc @bp.com. ;ianu~erce. lYR' n f~ ~ Technical Assistant, BPXA Alaska Drilling & Wells IREC IVF_.D 0 1 2001 Alaska Oil ~ Gas Cons Anchorage' Commission STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Per/orate_ Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 63 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 48' FNL, 120' FEL, Sec. 33, T11 N, R15E, UM (asp's 707431, 5951673) 11-32 At top of productive interval 9. Permit number / approval number 36' FNL, 156' FEL, Sec. 28, T11 N, R15E, UM (asp's 707240, 5956962) 194-131 At effective depth 10. APl number 50-029-22512 At total depth 11. Field / Pool 5198' FNL, 112' FEL, Sec. 21, T1 1 N, R15E, UM (asp's 707280, 5957080) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 1 1003 feet Plugs (measured) IBP set @ 10754' MD on 4/15/2001. true vertical 8901 feet Effective depth: measured 10754 feet Junk (measured) true vertical 8683 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 1 15' 20" 260 Sx AS 115' 1 15' Surface 3907' 10-3/4" 131o Sx CS III & 375 Sx Class G 3970' 3808' Production 10925' 7-5/8" 650 Sx C~ass G 10988' 8888' Perforation depth: measured 10710'- 10715'; (Isolated below IBP 10759'- 10765'; 10816'- 10844'). true vertica18645' - 8650'; (Isolated below lPB 8688' - 8693'; 8737'-8762'). RECEIVED Tubing (size, grade, and measured depth) 4-112".12.6#.130R-80Tbg@10260'MD. M ,Y 0 3 Z001 Packers & SSSV (type & measured depth) 7-5/8" X 4-1/2" BAKER SABL-3 PACKER @ 10187' MD. Alaska Oil & Gas Co~s, Commission 4-1/2" CAMCO TRCF-4A SSSV @ 2091' MD. Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 512 1544 6312 397 Subsequent to operation 2395 3200 4788 370 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ._X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title: DS 11 Surveillance Engineer Date May 4, 2001 Dan Babcock Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · ORIGINAl SUBMIT IN DUPLICATE 11-32 DESCRIPTION OF WORK COMPLETED SET IBP FOR WATER SHUTOFF Date Event Summary 4/15/2001' MIRU wireline unit. PT'd equip to 2500 psi. RIH & set a 3-3/8" IBP for WSO @ 10754' MD to isolate the following perforations: 10759'- 10765' MD (Zone lB) Reference Log: Atlas BHC 10/25/1994. 10816'- 10844' MD (Zone 1 B) Confirmed IBP set & POOH. RD wireline unit. Placed well on production & obtained a representative welltest. Page 1 STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 63 feet 3. Address Explorato~ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 48' FNL, 120' FEL, Sec. 33, T11N, R15E, UM (asp's 707431, 5951673) 11-32 At top of productive interval 9. Permit number / approval number 36' FNL, 156' FEL, Sec. 28, T11N, R15E, UM (asp's 707240, 5956962) 194-131 At effective depth 10. APl number 50-029-22512 At total depth 11. Field / Pool 5198' FNL, 112' FEL, Sec. 21, T11 N, R15E, UM (asp's 707280, 5957080) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11003 feet Plugs (measured) Tagged PBTD @ 10826' MD on 11/18/2000. true vertical 8901 feet Effective depth: measured 10826 feet Junk (measured) true vertical 8746 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 115' 20" 26o Sx AS 115' 115' Surface 3907' 10-3/4" 131o Sx cs III & 375 Sx Class G 3970' 3808' Production 10925' 7-5/8" 65o Sx C~ass 6 10988' 8888' Perforation depth: measured 10710'- 10715'; 10759'- 10765'; 10816'- 10844'. true vertica18645' - 8650'; 8688'-8693'; 8737'-8762'.R ECEJYED Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR-80 Tbg @ 10260' MD.MAR 2. 1 2001 Packers & SSSV (type & measured depth) 7-5/8" X 4-1/2" BAKER SABL-3 PACKER @ 10187' MD. Alaska 0ii & Gas Cons. Commission 4-1/2" CAMCO TRCF-4A SSSV @ 2091' MD. Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 586 1830 7690 367 Subsequent to operation 1157 1861 7422 - 283 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title: DS 11 Surveillance Engineer Date ~,-I~-OI Dan Babcock Prepared by Paul Rauf 564-5799 ~_ SUBMIT IN DUPLICATE Form 10-404 Rev 06/15/88 · 11-32 DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 11/13/2000: 11/18/2000: 3/01/2001: RIH &tagged PBTD @ 10846' MD. Performed RST SIGMA C/O - 3 passes f/PBTD @ 10826' - 10550' MD. MIRU ELU. PT'd equipment to 3000 psi - passed. RIH w/perforating guns & shot 5' of add perforations f/: 10710'- 10715' MD (Zone 2A) Reference Log: Atlas BHC 10/25/1994. Used 2-7/8" carrier & all shots @ 4 SPF, 180° phasing, overbalanced press, & random orientation. POOH w/perf guns - ASF. RD ELU. Placed well BOL. Obtained a representative production test. Page 1 MAR 2 2001 Alaska Oil & Gas Cons. Commission Anchorage ON OR BEFORE W F' E R H 'i[T (.% Geo i og'i: ca i !5 A T A 6320 S U R V E Y °"P 'AC'GfR !2, i'1 ~ / / ,CB T C N L /,S R D..T.F L./'G R/S P PERF AO,3CC Ind'i'v'i'rluai \,,lei I 0050 .... i 10150-10927 ..~t:f~' 'i 0-i 50--- 10986 10150 .... 10815 PERF IREC ..4:. 10150---i08i8 'i !:~, S T V E, 'd:.- i 0150 '-- I 0986 'i L. 10688- I (1)88 'i USIT ~ 'i0050---108'72 'i Ar'e dr'y wa s 't:he Ar"e we'i I C O H H E N T :5 STATE OF ALASKA ALASKA . AND GAS CONSERVATION C(' ¢IlSSION REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 48' SNL, 125' WEL, Sec 33, T11 N, R15E, UM. At top of productive interval 36' SNL, 157' WEL, Sec 28, T11N, R15E, UM. At effective depth At total depth 81' NSL, 127' WEL, Sec 21, T11N, R15E, UM. Development Exploratory Stratigraphic Service X 6. Datum of eleva'tiOn(DF 6VKB) 63' RKB ~ J~ feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 11-32 9. Permit number/approval number 94-131 10. APl number 50 - 029-22512 11. Field/Pool Prudhoe Bay Oil Pool 5. Type of Well 12. Present well condition summary Total depth: measured true vertical 11003 feet 8901 feet Plugs(measured) PBTD Tagged @ 10855' MD (7/29/95). Effective depth: measured 10855 feet true vertical 8772 feet Junk(measured) Casing Length Size Cemented Conductor 115' 20" 260 Sx Arcticset Surface 3907' 10-3/4" 1310 Sx CS III & 375 Sx CIG Production 10925' 7-5/8" 650 Sx CIG Measured depth True vedicaldepthl 115' 115' 3970' 3808' 10988' 8888' Perforation depth: measured 10759 - 10765'; 10816 - 10844' true vertical 8688 - 8693" 8737 - 8762' Tubing (size, grade, and measured depth) 4-1/2", 12.6-¢¢, 13CR-80 Tbg @ 10260' MD. JAN O4 Alaska Oil & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 10187' MD; Camco TRCF-4A SSSV @ 2091' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation ,Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 80 212 278 -- 2469 3518 4072 Tubing Pressure 229 294 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended__ Service 17. I hereby certify that the foregoing is tru~.~id~co~ Fo r m'~l,,~!Rev 06/15/88 the best of my knowledge. Title Engineering Supervisor ,--, ~. · V'7 ITAIIZ) Date SUBMIT IN DUPLICATE 11-32 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 7/7/95 · MIRU & PT equipment. RIH w/perforating gun & shot 20' of add perforations as follows: Added perforations: 10816 - 10824' MD (Z1B) Reperforated: 10824 - 10836' MD (Zl) Used a 3-3/8" carrier & shot 6 spf at 60 degree phasing at underbalanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. 7/29/95 · RIH & tagged PBTD at 10855' MD. 7/30/95: MIRU & PT equipment. RIH w/perforating gun & shot 6' of add perforations as follows: Added perforations: 10759 - 10765' MD (Z1B) Used a 3-3/8" carrier & shot 6 spf at 180 degree phasing at balanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to production w/gaslift & obtained a valid welltest. STATE OF ALASKA ALASF DIL AND GAS CONSERVATION ( MMISSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 48' SNL, 125' WEL, Sec. 33, T11N, R15E, UM. At top of productive interval 36' SNL, 157' WEL, Sec. 28, T11N, R15E, UM. At effective depth At total depth 81'NSL, 127' WEL, Sec. 21, T11N, R15E, UM. 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 63 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 11-32 9. Permit number/approval number 94-131 10. APl number 50 - 029-22512 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured 11003 feet Plugs(measured) true vertical 8901 feet Effective depth: measured 10903 feet true vertical 8813 feet Junk(measured) Casing Length Size Cemented Conductor 115' 20" 260 sx Arcticset Surface 3907' 10-3/4" 1310 sx CS III & 375 sx G Production 10925' 7-5/8" 650 sx G Measured depth 115' 3970' 10988' True vertical depth 115' 3808' 8888' Perforation depth: measured 10824-10844' true vertical 8744-8762' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR-80, Fox Tbg @ 10260' MD. Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 10187' MD pit .& Gas Cons. Cornmissio · 'AnGh0m ~' 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 1190 1150 2493 Tubing Pressure 254 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Z, Fiorm 10_ 4 R~ev 06/15/88~--~- Title Engineering Supervisor k" R P r,n' 147 . IWP Date z~/'~/¢/--'~'- SUBMIT IN DUPLICATE 11-32 DESCRIPTION OF WORK COMPLETED ROPE PERFORATIONS & HYDRAULIC FRACTURE TREATMENT OF ZONE I I 1/6/94: RIH & tagged PBTD at 10905' MD. I 1/1 5/94: Shot Initial Perforations: 10824 - 10844' MD (Z1) Ref. Log: BHCA 10/25/94. Ran 2-1/2" carriers into position, then pumped 206 Mscf N2 & shot 4 spf at 180 degree phasing with 8100 psi on the well for ROPE perforations. POOH w/perf gun. Rigged down. 2/1 3~95: Performed a Hydraulic Fracture Treatment as follows: MI RU & PT equipment. Pumped the Fracture Treatment using 20/40 mesh proppant, through the open perforations (listed above). Pumped Datafrac: a) 250 bbls 20# Pre Pad Gel @ 25 bpm, followed by b) Shutdown. ISIP @ 1620. Resumed pumping Datafrac: c) 53 bbls 30# Crosslinked Gel @ 25 bpm, followed by d) 176 bbls 20# Flush, followed by e) Shutdown. Pumped Fracture Treatment: f) 20 bbls 30# Crosslinked Pad @ 20 bpm, followed by g) 143 bbls Crosslinked Slurry w/proppant concentrations @ 2 - 8 ppg, followed by h) 167 bbls 20# Gelled Flush, followed by i) Shutdown. Placed a total of 20,283 lbs of proppant into the formation. Rigged down. 2/1 5/95: RIH w/CT & jetted a proppant fill clean out from 10624' to 10877' MD. 2/21/95: RIH w/CT & jetted a proppant fill clean out from 10664' to 10880' MD. Placed the well on production w/gas lift & obtained a valid welltest. APR 1 Z 1995 Oii& Gas Cons. Commission Anchora ~' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C~vlMISSION WELL COMPLETION OR REOOMP LETION REPORT AND LOG 1. Status of Well Classi~on of Service Well OIL [] GAS [] SUS,C~ENDED [] /E~,auNEX::)NED [] SER~CE [] 2. Name of Operator ~i 7'I ~ ~ Permi/(Ni~l-~e2rs~22a~/ ARCO Alaska, Inc. I~.d~:r_~, ~.~ ~4Ao! 3. Address ~ r ~-.,~r/~~ B. I ,4. Location of well at sudace RECEIVE 48' SNL, 125' WEL, SEC. 33, T11N, R15E Prudhoe Bay Unit ; !i';;:;~'; i; ;";.7;:,i:";~ 10. Well Number At Top Producing Interval At Total Depth ; ~ MAR 1 4 ]995 11. Field and Pool 81' NSL, 127' WEL, SEC. 21, T11N, R15 ~ ~ ask~ 0il.& Gas Cons. Commission Prudhoe Bay FielcYPrudhoe Bay Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation ~l~'~'~,~l No. KBE = 63.2' ADL 28322 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 10/14/94 10/24/94 11/15/94I N/A feet MSLI One 17. Total Depth (MD+TVD) i18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 11003' MD/8901' TVD 10903' MD/8813' TVD YES [] NO [] 2091' feet MD 1900'(Approx.) 22. Type Electdc or Other Logs Run SONIO/NEU/DEN 23. CASING, lINER AND CEMENTING RECORD SE-I-I'ING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-f'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 35' 115' 30" 260 sx Arcticset (Approx.) 10-3/4" 45.5# NT-80 34' 3970' 13-1/2" 1310 sx CS 111/375 sx "G" 7-5/8" 29. 7# NT95/13CR 31' 10988' 9-7/8" 650 SX Class 'G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter 2-1/2" 4 spf 4-1/2", 13CR80 10260' 10188' MD TVD(ss) 10824'- 10844' 8680'-8697' 26. ACID, FRACTURE, CEMENT SQUEF'TF, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 2/21/95 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SlZE IGAS-OIL RATIO TEST PERIOD J~ I Flow Tubing Casing Pressure CALCULATED=1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (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 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ,~9. 30. GEOLOGIC MARKERS = ,-ORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Top Sadlerochit 10357' 8276' GOC ' 10742' 8609' Base Sadlerochit 10837' 8691' 31. LIST OF A'I-FACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ¢,~)1~ ~/ ~~4k,-... Title Drilling En_oineerSu~2ervisor Date ¢~'~/~"'(~'~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/ALI SHARED SERVICE WELL: DS 11-32 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: DAILY OPERATIONS PAGE: 1 ACCEPT: 10/14/94 03:00 SPUD: RELEASE: 10/29/94 06:30 OPERATION: DRLG RIG: NABORS 28E WO/C RIG: 10/15/94 ( 1) TD: 600'( 0) 10/16/94 (2) TD: 2775' (2175) DRILLING MW: 0.0 VIS: 0 MOVED RIG FROM DS 11-31 TO DS 11-32. NIPPLE UP DIVERTER. ACCEPT RIG @ 1500 HRS 10/14/94. RIGGED UP DIVERTER. TESTED DIVERTER. FUNCTION TEST DIVERTER AND ACCUMULATOR. CIRCULATED. FILLED DIVERTER AND CONDUCTOR HOLE. HOLE DISPLACED WITH WATER BASED MUD. MADE UP BHA #1. P/U BHA AND ORIENT MWD. TAGGED ICE @ 95'. DRILLED TO 600' DRILLING DRILLED TO 2775'. MW: 0.0 VIS: 0 10/17/94 ( 3) TD: 3990' (1215) 10/18/94 ( 4) TD: 3990' ( 0) CIRCULATED MW: 0.0 VIS: 0 DRILLED TO 2936'. POH TO 1700' AT TOP OF CHECK TRIP INTERVAL. RIH TO 2936'. DRILLED TO 3346'. CIRCULATED. POH. P/U RR BIT #2. RIH TO 3346'. P/U BIT #2RR AND RIH. DRILLED TO 3990'. CIRCULATED AT 3990'. OBTAINED CLEAN RETURNS. POH TO 850' RIH TO 3990' SLM NO CORRECTION, NO HOLE PROBLEMS. CIRCULATED AT 3996'. TESTING BOP MW: 0.0 VIS: 0 DROP SONGLE SHOT SURVEY AND PMP PILL. POH TO 228'_ PULLED BHA. BHA LAID OUT. RIGGED UP CASING HANDLING EQUIPMENT. RAN CASING TO 3970'. HANGER LANDED. CIRCULATED AT 3970' OBTAINED BOTTOMS UP. TEST CMT LINES. PMP 50 BBLS H20. MOX AND PMP 448 BBLS LEAD CMT AND DROP BTM PLUG. MIX AND PMP 77 BBLS TAIL CMT. DROP TOP PLUG. DISPLACE W/ 373 BBLS MUD. BMP PLUG, OK. FLOATS HELS OK. RECIPROCATED W/ FULL RETURNS THROUGHOUT JOB. RAN TOP JOB PIPE TO 90' DISPLACED W/ H20 AND PMP'D 51 BBLS TOP JOB CMT. GOOD RETURNS TO SURFACE. RIGGED DOWN DIVERTER. INSTALL SPLIT SPEEDHEAD AND TESTED. NIPPLE UP BOP STACK. TEST WELL CONTROL EQUIPMENT. TESTED BLIND RAMS, PIPE RAMS, CHOKE AND KILL LINE VALVES, FLOOR SAFETY VALVES AND CHOKE. TESTED ANNULAR. FUNCTION TESTED ACCUMULATOR. MAP, ] 4 '!99,5 Anchor~. ' WELL : DS 11-32 OPERATION: RIG : NABORS 28E PAGE: 2 10/19/94 ( 5) TD: 5500' (1510) 10/20/94 (6) TD: 7025' (1525) 10/21/94 ( 7) TD: 8202' (1177) DRILLING MW: 0.0 VIS: 0 INSTALLED WEAR BUSHING. MADE UP BHA #3. P/U MOTOR, MWD, AND ORIENT. RIH TO 1200'_ SERVICE BLOCK EQUIPMENT. LINE SLIPPED AND CUT. RIH TO 3882'. CIRCULATED. TESTED CASING VIA ANNULUS. DRILLED CEMENT TO 4000' CIRC BOTTOMS UP. PERFORMED LEAK OFF TEST. OBTAINED CLEAN RETURNS. DRILLED TO 5405'_ STARTED SCHEDULED WIPER TRIP. POH TO 3990' RIH TO 5405'. DRILLED TO 5500'. DRILLING MW: 0.0 VIS: 0 DRILLED TO 6757' ROP DROPPED FROM 120.0 FT/HR TO 30.0 FT/HR, BIT QUIT. CIRCULATED. POH TO 816'_ NO HOLE PROBLEMS ENCOUNTERED. PULLED BHA. SERVICE WEAR BUSHING. MADE UP BHA #4. RIH TO 6630'. BEGAN PRECAUTIONARY MEASURES. REAMED TO 6757'. DRILLED TO 7025'. DRILLING DRILLED TO 8202'. MW: 0.0 ViS: 0 10/22/94 ( 8) TD: 8960' ( 758) 10/23/94 (9) TD:10000' (1040) 10/24/94 (10) TD:10460' ( 460) 10/25/94 (11) TD:11003' ( 543) DRILLING MW: 0.0 VIS: 0 POH TO 6500'. RIH TO 8202' NO PROBLEMS ON WIPER TRIP. DRILLED TO 8439'_ ROP DROPPED FROM 80 FT/HR TO 40 FT/HR. BIT QUIT. CIRCULATED. OBTAINED BOTTOMS UP. POH TO 818'. PULLED BHA. BHA STOOD BACK.- SERVICED WEAR BUSHING. MADE UP BHA #5. RIH TO 8359'. BEGAN PRECAUTIONARY MEASURES. REAMED TO 8439'. DRILLED TO 8960'. DRILLING MW: 0.0 VIS: 0 DRILLED TO 9908' STARTED SCHEDULED WIPER TRIP; DUE TO FOOTAGE DRILLED. POH TO 8350'. RIH TO 9908' DRILLED TO 10000'. DRILLING MW: 0.0 VIS: 0 DRILLED TO 10345'. CIRCULATED. HOLE SWEPT WITH SLUG. POH TO 819'. PULLED BHA, CHANGED BIT. MADE UP BHA #6. SERVICED BLOCK LINE. LINE SLIPPED AND CUT. RIH TO 10345' CIRCULATED. DISPLACED HOLE WITH SPACERS AND 1% KCL DRILLING FLUID. INJECTED OLD MUD AND CLEANED PITS WHILE TRIPPING. HOLE DISPLACED WITH WATER BASED MUD. DRILLED TO 10460' RIG UP LOGGING EQUIP MW: 0.0 VIS: 0 DRILLED TO 11003' REACHED PLANNED END OF RUN - SECTION. CIRCULATED BOTTOMS UP. POH TO 9600'. PULLED TIGHT FRdM 10850 - 10429'. WORKED CLEAN. RIH TO 11003' NO DRAG OR FILL ON BOTTOM. CIRCULATED. HOLE SWEPT WITH SLUG. POH TO 818'. HOLE IN GOOD CONDITION. PULLED BHA. BHA LAID OUT. RIGGED UP LUBRICATOR. RIG UP LOGGING EQUIPMENT AND TOOLS WELL : DS 11-32 OPERATION: RIG : NABORS 28E PAGE: 3 10/26/94 (12) TD:ll003' ( 0) 10/27/94 (13) TD:ll003' ( 0) 10/28/94 (14) TD:ll003' ( 0) 10/29/94 (15) TD:l1003' ( 0) JARRED STUCK PIPE MW: 0.0 VIS: 0 RUN TRIPPLE COMBO (SONIC/NEUTRON/RESISTIVITY) LOGS TO WIRE LINE DEPTH OF 10988'. NO HOLE PROBLEMS. RIGGED DOWN LOGGING/BRAIDED CABLE EQUIPMENT. WORK COMPLETED, EQUIPMENT LAID OUT. REMOVED WEAR BUSHING. TEST WELL CONTROL EQUIPMENT. TESTED BOP STACK. PRESSURE TEST COMPLETED SUCCESSFULLY. COMMISSION/DECOMMISSION XMAS TREE/WELLHEAD/HANGER. INSTALLED WEAR BUSHING. MADE UP BHA #7. RIH TO 10647'_ GOT STUCK. HIT BRIDGE AND PIPE STUCK. JARRED STUCK PIPE @10647'. REAMED TO 10721'. GOT STUCK (PIPE MOVING). PIPE TORQUED UP WHILE REAMING AND STUCK. JARRED STUCK PIPE AT 10721'_ PIPE CAME FREE. REAMED TO 10788' GOT STUCK (PIPE MOVING). JARRED STUCK PIPE. SPOT SPT PILL AROUND BHA. CIRC MW: 0.0 VIS: 0 SLUMP, TORQUE & WORK PIPE. CAME FREE BUMPING DOWN. POOH. CHANGE BHA. CUT & SLIP LINE. RIH TO 10604' NO PROBLEMS. REAM F/12604-11003' PUMP LO/HI (36/120) VI~ SWEEP, CBU. FAIR AMOUNT OF SAND IN RETURNS WHILE REAMING. CIRCULATE & RECIPROCATE MW: 0.0 VIS: 0 SHORT TRIP F/ 11003 - 10030'. NO PROBLEMS. CBU, 12 BPM, 1500 PSI. SPOT 100 BBL LCM PILL ON BTM. POH 10 STANDS. PUMP DRY JOB. LAY DOWN 5" DP. LAY DOWN BHA. CHANGE RAMS TO 7 5/8". BODY TEST. RIG UP CSG TOOLS. RUN 7 5/8". MU CMT HEAD. BREAK CIRCULATION. GRADUALLY BRING RATE TO 10.5 BPM, 950 PSI. RUN TBG MW: 0.0 VIS: 0 CIRCULATE AND RECIPROCATE. BATCH MIX CMT. TEST LINES. CHECK FLOATS. TEST CSG. FLUSH LINES. LD CMT HEAD, CSG TOOLS AND LDG JT. INSTALL 7 5/8" PACKOFF. DAILY JAR SEMINAR. TEST PACKOFF. CHANGE RAMS. BODY TEST BOP. RIG UP TO RUN 4 1/2" TBG. RUN 4 1/2" TBG. RIG UP CAMCO. HOOK UP CL AND TEST. RUN 4 1/2" TBG. 'Anchor~ WELL : DS 11-32 OPERATION: RIG : NABORS 28E PAGE: 4 10/30/94 (16) TD: 11003' ( 0) RELEASE RIG MW: 0.0 VIS: 0 RAN TUBING TO 10260'. MAD UP HANGER AND TEST CONTROL LINES. HANGER LANDED. BPV INSTALLED. NIPPLE DOWN DIVERTER. RIGGED DOWN BOP STACK. WORK COMPLETED, EQUIPMENT LAID OUT. INSTALLED XMAS TREE. TESTED ADAPTER SPOOL, TREE AND CONTROL LINES. PRESSURE TESTED COMPLETED SUCCESSFULLY. RETRIEVED HANGER PLUG. RUN SINGLE COMPLETION. SETTING PACKER AT 10188'_ PACKER SER AT 10188'. TESTED TUBING, VIA STRING. TESTED PERMANENT PACKER, VIA ANNULUS. PRESSURE TEST COMPLETED SUCCESSFULLY. SHEARED RP VALVE IN TOP GLM AFTER TEST. CIRCULATED AT 3883'_ PUMPED 90 BBLS OF DIESEL AND LET U-TUBE FOR FREEZE PROTECTION. INSTALLED HANGER PLUG. EQPT WORK COMPLETED, RUNNING TOOL RETRIVED. SECURED WELL AND RELEASED RIG AT 1830 HRS ON 10/29/94. SIGNATURE: (drilling superintendent) DATE: RECEIVED MAR 1 4 199,5 Al~sk,3 Oil & Gas Cons. Commission Anchor~ · SPERRY-SUN DRILLING SERVICES PAGE ANCHORAGE ALASKA R CEIV E D 102494E PRUDHOE BAY DRILLING R PBU/ll-32 V 500292251200 MAR ~ 4 1995 JOB NUMBER: Ak~Z~'~40086 NORTH SLOPE KELLY BUSHING ET~5~ = 64.10 FT. COMPUTATION DATE: 10/26/94 A~$RA0JI&GasCons. Commis~ERATOR: ARCO ~L/~ INC Anchora ~', '!2 TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT". 0 .00 -64.10 0 0 N .00 E .00 .00N .00E .00 185 185.70 121.60 0 6 S 67.80 E .05 .06S .15E -.06 271 271.18 207.08 0 12 S 71.20 E .12 .14S .36E -.14 301 301.94 237.84 0 12 S 69.10 E .00 .17S .46E -.17 395 395.96 331.86 0 42 S 63.60 E .53 .49S 1.13E -.49 482 482.26 418.16 1 17 S 75.00 E .73 .98S 2.55E -.98 571 571.35 507.25 2 30 S 67.40 E 1.37 1.98S 5.32E -1.99 664 664.41 600.31 3 54 S 70.20 E 1.51 3.84S 10.18E -3.84 753 752.79 688.69 5 35 S 87.10 E 2.46 5.08S 17.34E -5.09 845 844.65 780.55 6 24 S 84.30 E .92 5.82S 26.96E -5.83 942 940.73 876.63 5 54 S 86.80 E .59 6.63S 37.28E -6.64 1037 1035.49 971.39 5 5 N 89.40 E .92 6.86S 46.40E -6.88 1131 1129.23 1065.13 3 24 N 79.40 E 1.97 6.30S 53.31E -6.32 1227 1224.62 1160.52 3 0 N 67.90 E .79 4.84S 58.42E -4.86 1322 1319.97 1255.87 3 12 N 68.60 E .21 2.93S 63.21E -2.95 1417 1415.07 1350.97 2 30 N 67.80 E .74 1.18S 67.61E -1.20 1513 1510.28 1446.18 1 47 N 56.20 E .86 .44N 70.78E .42 1609 1606.45 1542.35 1 47 N 35.80 E .66 2.51N 72.92E 2.48 1704 1701.57 1637.47 1 17 N .10 E 1.12 4.80N 73.79E 4.78 1800 1797.23 1733.13 0 54 N 15.90 W .52 6.61N 73.59E 6.58 1895 1892.32 1828.22 0 48 N 41.20 W .40 7.83N 72.95E 7.80 1989 1986.58 1922.48 0 48 N 42.50 W .00 8.81N 72.07E 8.78 2085 2082.17 2018.07 0 54 N 40.00 W .11 9.87N 71.14E 9.85 2180 2177.06 2112.96 1 17 N 39.10 W .42 11.28N 69.98E 11.26 2274 2271.97 2207.87 1 36 N 43.90 W .34 13.07N 68.38E 13.05 2370 2367.56 2303.46 2 17 N 16.30 W 1.20 15.88N 66.91E 15.85 2467 2464.04 2399.94 4 18 N 4.60 E 2.38 21.35N 66.66E 21.33 2562 2558.82 2494.72 6 35 N 7.60 E 2.43 30.33N 67.67E 30.31 2657 2653.39 2589.29 9 18 N 4.50 E 2.86 43.47N 69.00E 43.44 2752 2746.26 2682.16 12 11 N 4.60 E 3.07 61.04N 70.40E 61.02 2844 2836.01 2771.91 14 41 N 2.20 E 2.77 82.47N 71.64E 82.44 2944 2931.48 2867.38 17 6 N 1.00 E 2.44 109.65N 72.37E 109.63 3038 3021.43 2957.33 19 12 N 1.10 E 2.22 139.13N 72.92E 139.11 3133 3110.08 3045.98 22 23 N 2.70 E 3.43 172.79N 74.07E 172.76 IVll %IL V [I I,,1'1 I,, as SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 PRUDHOE BAY DRILLING PBU/ll-32 500292251200 NORTH SLOPE COMPUTATION DATE: 10/26/94 DATE OF SURVEY: 102494 MWD SURVEY JOB NUMBER: AK-MW-40086 KELLY BUSHING ELEV. = 64.10 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN COORDINATES VERT. DEPTH DEPTH DEPTH DG MN EAST/WEST SECTi COURSE DLS TOTAL DIRECTION RECTANGULAR DEGREES DG/100 NORTH / SOUTH 3323 3281.66 3217.56 27 30 3418 3364.73 3300.63 30 23 3513 3445.90 3381.79 32 24 3608 3525.75 3461.65 34 17 3703 3603.03 3538.93 36 30 N 1.80 E 2.42 253.04N N .30 W 3.24 298.98N N 1.90 W 2.28 348.51N N 1.30 W 2.02 401.05N N 1.90 W 2.35 455.95N 77.15E 77.71E 76.74E 75.28E 73.74E 253.02 298.96 348.49 401.02 455.92 3798 3678.41 3614.31 3900 3755.78 3691.68 3995 3826.67 3762.57 4092 3898.70 3834.60 4187 3968.99 3904.89 39 0 42 0 41 47 41 35 42 24 N 2.60 W 2.66 514.26N N 1.20 W 3.08 580.30N N .60 W .47 643.90N N .20 E .59 708.08N N 1.00 W 1.20 771.36N 71.44E 69.27E 68.27E 68.05E 67.60E 514.24 580.28 643.88 708.06 771.34 4282 4038.84 3974.74 44 0 4378 4107.33 4043.23 44 24 4473 4174.44 4110.34 45'30 4567 4240.40 4176.30 46 12 4662 4306.02 4241.92 46 24 N 1.30 W 1.68 836.94N N 2.90 E 3.09 903.49N N 2.60 W 4.26 970.40N N 2.90 W .77 1038.28N N 2.60 W .31 1106.86N 66.28E 67.22E 67.37E 64.10E 60.81E 836.92 903 .47 970.38 1038.26 1106.84 4757 4371.34 4307.24 46 42 4854 4437.37 4373.27 46 35 4950 4504.00 4439.90 46 17 5045 4569.41 4505.31 46 47 5140 4634.49 4570.39 46 47 N 4.00 W 1.12 1175.69N N 4.30 W .25 1245.47N N 3.60 W .61 1315.38N N 5.70 W 1.69 1384.20N N 6.20 W .38 1453.12N 56.84E 51.78E 46.95E 41.35E 34.16E 1175.68 1245.45 1315.37 1384.18 1453.11 5236 4699.78 4635.68 46 42 5331 4764.98 4700.88 46 35 5427 4831.13 4767.03 46 17 5521 4896.58 4832.48 46 12 5616 4961.88 4897.78 46 0 N 5.90 W .25 1522.15N N 5.60 W .25 1590.87N N 5.60 W .31 1660.11N N 6.10 W .40 1728.13N N 4.70 W 1.09 1795.68N 26.85E 19.93E 13.14E 6.17E .22W 1522.14 1590.86 1660.11 1728.12 1795.68 5711 5027.73 4963.63 46 47 5808 5094.00 5029.90 46 54 5903 5159.19 5095.09 46 47 5996 5223.06 5158.96 46 42 6092 5288.77 5224.67 46 47 N 3.80 W 1.08 1864.64N N 3.60 W .18 1935.18N N 3.10 W .40 2004.60N N 1.50 W 1.25 2072.44N N 3.30 W 1.37 2142.22N 5.34W 9.90W 13 . 96W 16.69W 19 . 62W 1864.64 1935.18 2004 .61 2072 .44 2142.23 6187 5353.76 5289.66 6283 5420.11 5356.01 6378 5485.97 5421.87 6474 5551.43 5487.33 6569 5617.60 5553.50 46 45 46 46 45 35 54 35 35 3O N 2.00 W 1.02 2211.11N N 2.00 W .73 2280.37N N 3.30 W 1.23 2349.10N N 2.90 W .31 2418.22N N 2.00 W 1.34 2486.80N 22.81W 25.22W 28.41W 32.15W 35.09W 2211.12 2280.38 2349.11 2418.23 2486.81 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 PRUDHOE BAY DRILLING PBU/ll-32 500292251200 NORTH SLOPE COMPUTATION DATE: 10/26/94 DATE OF SURVEY: 102494 MWD SURVEY JOB NIIMBER: AK-MW-40086 KELLY BUSHING ELEV. = 64.10 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL COORDINATES VERT. DEPTH DEPTH DEPTH EAST/WEST SECT:. COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR DEGREES DG/100 NORTH/SOUTH 6665 5684.60 5620.50 6759 5750.57 5686.47 6854 5816.68 5752.58 6952 5884.82 5820.72 7046 5950.54 5886.44 45 45 46 45 45 30 42 5 42 24 N 2.70 W .52 2554.91N N 3.30 W .50 2622.18N N 5.00 W 1.35 2690.22N N 7.10 W 1.59 2760.13N N 2.90 W 3.21 2826.82N 37.89W 41.41W 46.35W 53.76W 59.60W 2554.92 2622.20 2690.23 2760.15 2826.84 7139 6015.98 5951.88 7236 6083.88 6019.78 7330 6149.55 6085.45 7422 6213.80 6149.70 7516 6280.05 6215.95 45 45 45 45 45 42 35 35 17 12 N 3.60 W .62 2893.43N N 4.00 W .31 2962.74N N 2.00 W 1.52 3029.69N N 1.30 W .64 3094.93N N .60 W .54 3161.75N 63 .38W 67.99W 71.50W 73.38W 74.48W 2893.45 2962.76 3029.71 3094.95 3161.77 7615 6349.93 6285.83 7711 6416.43 6352.33 7808 6484.01 6419.91 7904 6551.58 6487.48 7997 6615.50 6551.40 45 46 45 46 46 47 0 24 0 12 N 4.30 W 2.71 3232.75N N 2.70 W 1.22 3301.24N N 4.00 W 1.14 3370.37N N 1.00 W 2.30 3439.53N N 2.70 W 1.35 3505.90N 77.53W 81.72W 85.76W 88.77W 90.92W 3232.78 3301.27 3370.40 3439.56 3505.93 8095 6683.64 6619.54 8188 6748.73 6684.63 8284 6816.18 6752.08 8363 6871.84 6807.74 8444 6928.70 6864.60 45 45 45 45 45 47 30 5 35 24 N 4.50 W 1.38 3576.32N N 3.30 W .98 3642.74N N 3.40 W .42 3710.79N N 3.30 W .64 3767.04N N .60 W 2.39 3824.85N 95.35W 99.88W 103.86W 107.15W 109.12W 3576.35 3642.78 3710.82 3767.08 3824.88 8538 6995.06 8634 7062.40 8727 7127.22 8823 7193.91 8919 7260.72 6930.96 6998.29 7063.12 7129.81 7196 62 45 45 46 46 46 17 12 0 5 0 N .60 W .11 3892.02N N .40 W .18 3959.94N N .40 W .86 4026.14N N 1.20 W .61 4095.31N N 1.70 W .39 4164.59N 109.83W 110.42W 110.88W 111.85W 113.60W 3892.05 3959.98 4026.17 4095.35 4164.63 9010 7324.22 9106 7391.20 9199 7456.14 9295 7523.27 9388 7588.47 7260 12 7327.10 7392 04 7459.17 7524 37 45 45 45 45 45 42 42 42 35 30 N 1.50 W .36 4229.98N N 1.90 W .30 4298.59N N 2.19 W .22 4365.09N N 2.20 W .11 4433.71N N 2.40 W .19 4500.12N 115 117 119 122 125 .43W .46W · 84W .47W .14W 4230.01 4298.63 4365.13 4433.75 4500.16 9486 7656.95 9573 7718.09 9671 7788.66 9765 7857.58 9861 7930.90 7592 85 7653.99 7724 56 7793.48 7866 80 45 45 43 41 39 17 17 12 30 0 N 2.20 W .25 4569.51N N 3.10 W .74 4631.23N N .20 E 3.16 4699.92N N .60 E 1.85 4762.74N N 2.20 E 2.82 4824.78N 127. 92W 130.78W 132 . 56W 132.12W 130 . 63W 4569.55 4631.27 4699.96 4762.79 4824.82 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 PRUDHOE BAY DRILLING PBU/ll-32 500292251200 NORTH SLOPE COMPUTATION DATE: 10/26/94 DATE OF SURVEY: 102494 MWD SURVEY JOB NUMBER: AK-MW-40086 KELLY BUSHING ELEV. = 64.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB - SEA COURS MEASD VERTICAL VERTICAL INCLN COORDINATES VERT. DEPTH DEPTH DEPTH DG MN EAST/WEST SECT'. COURSE DLS TOTAL DIRECTION RECTANGULAR DEGREES DG/100 NORTH/SOUTH 9957 8006.37 7942.27 37 30 N 4.80 E 2.29 4884.15N 127.02W 4884.19 10048 8079.71 8015.61 35 24 N 8.90 E 3.53 4937.91N 120.61W 4937.95 10143 8158.14 8094.04 32 47 N 12.20 E 3.37 4990.10N 110.94W 4990.14 10240 8240.49 8176.39 32 5 N 12.00 E .73 5041.30N 99.96W 5041.33 10333 8319.48 8255.38 31 12 N 14.80 E 1.86 5088.65N 88.70W 5088.68 10429 8401.66 8337.56 30 23 N 16.50 E 1.24 5135.82N 75.49W 5135.84 10524 8484.15 8420.05 30 6 N 16.90 E .38 5181.90N 61.67W 5181.92 10617 8565.03 8500.93 29 47 N 15.50 E .81 5226.65N 48.67W 5226.66 10713 8648.11 8584.01 29 42 N 14.30 E .63 5272.53N 36.46W 5272.54 10810 8731.86 8667.76 29 47 N 13.40 E .47 5319.01N 25.00W 5319.01 10905 8814.80 8750.70 28 47 N 14.30 E 1.15 5364.20N 13.86W 5364.20 10928 8835.33 8771.23 28 30 N 14.70 E 1.52 5375.06N ll.05W 5375.06 11003 8900.99 8836.89 27 30 N 16.00 E 1.58 5408.72N 1.82W 5408.72 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5408.72 FEET AT NORTH 0 DEG. 1 MIN. WEST AT MD = 11003 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 359.98 DEG. RECEIVED MAR 1 4 1995 .Oil.& Gas Cons. Commission ~chora" SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 PRUDHOE BAY DRILLING PBU/ll-32 500292251200 NORTH SLOPE COMPUTATION DATE: 10/26/94 DATE OF SURVEY: 102494 JOB NUMBER: AK-MW-40086 KELLY BUSHING ELEV. = 64.10 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL VERTICAL DEPTH DEPTH DEPTH CORRECTION TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE 0 .00 -64.10 .00 N .00 E .00 1000 998.10 934.00 6.90 S 43.06 E 1.90 2000 1997.09 1932.99 8.91 N 71.97 E 2.91 3000 2984.81 2920.71 126.38 N 72.67 E 15.19 4000 3829.66 3765.56 646.58 N 68.25 E 170.34 1.90 1.02 12.28 155.14 5000 4538.03 4473.93 1350.94 N 44.67 E 461.97 6000 5225.16 5161.06 2074.67 N 16.75 W 774.84 7000 5918.25 5854.15 2794.09 N 57.35 W 1081.75 8000 6617.51 6553.41 3508.00 N 91.02 W 1382.49 9000 7316.70 7252.60 4222.28 N 115.23 W 1683.30 291.64 312.87 306.91 300.74 300.81 10000 8040.56 7976.46 4909.78 N 124.45 W 1959.44 11000 8898.33 8834.23 5407.39 N 2.20 W 2101.67 11003 8900.99 8836.89 5408.72 N 1.82 W 2102.01 276.14 142.23 .34 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES PAGE ANCHORAGE ALASKA PRUDHOE BAY DRILLING R E~E~VED DATE OF SURVEY: 102494 PBU/ll-32 500292251200 MAR 1 4 1995 JOB NUMBER: AK-MW-40086 NORTH SLOPE lO/26/.~,~ska0il&GasCons. Commissiong~ KELLY BUSHING ELEV. = 64.10 FT. COMPUTATION DATE: Anchora ~ OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL VERTICAL -- DEPTH DEPTH DEPTH CORRECTION TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE 0 .00 -64.10 64 64.10 .00 164 164.10 100.00 264 264.10 200.00 364 364.10 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .05 S .12 E .00 .00 .13 S .34 E .00 .00 .32 S .78 E .00 .00 464 464.10 400.00 564 564.10 500.00 664 664.10 600.00 764 764.10 700.00 865 864.10 800.00 .87 S 2.15 E 1.86 S 5.03 E 3.83 S 10.16 E 5.14 S 18.45 E 6.04 S 29.13 E .01 .07 .22 .59 1.17 .01 .05 .16 .37 .58 965 964.10 900.00 1066 1064.10 1000.00 1166 1164.10 1100.00 1266 1264.10 1200.00 1366 1364.10 1300.00 6.77 S 39.69 E 6.83 S 48.95 E 5.92 S 55.35 E 4.06 S 60.34 E 2.04 S 65.47 E 1.73 2.16 2.38 2.52 2.67 .56 .43 .22 .14 .15 1466 1464.10 1400.00 1566 1564.10 1500.00 1666 1664.10 1600.00 1766 1764.10 1700.00 1867 1864.10 1800.00 .36 S 69.52 E 1.43 N 72.13 E 3.95 N 73.79 E 6.11 N 73.73 E 7.53 N 73.21 E 2.77 2.82 2.87 2.89 2.90 .10 .05 .05 .02 .01 1967 1964.10 1900.00 2067 2064.10 2000.00 2167 2164.10 2100.00 2267 2264.10 2200.00 2367 2364.10 2300.00 8.58 N 72.28 E 9.66 N 71.32 E 11.05 N 70.16 E 12.91 N 68.53 E 15.74 N 66.95 E 2.91 2.92 2.94 2.97 3.03 .01 .01 .02 .03 .06 2467 2464.10 2400.00 2567 2564.10 2500.00 2668 2664.10 2600.00 2770 2764.10 2700.00 2873 2864.10 2800.00 21.35 N 66.66 E 30.97 N 67.75 E 45.27 N 69.15 E 64.89 N 70.71 E 89.83 N 71.92 E 3 .20 3 .69 4.73 6.66 9.75 .18 .49 1.04 1.93 3 .09 2978 2964.10 2900.00 3084 3064.10 3000.00 3192 3164.10 3100.00 3303 3264.10 3200.00 3417 3364.10 3300.00 119.68 N 72.55 E 14.13 4.38 154.65 N 73.33 E 20.08 5.96 196.03 N 75.09 E 28.34 8.25 243.91 N 76.86 E 39.25 10.91 298.63 N 77.71 E 53.26 14.01 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 7 PRUDHOE BAY DRILLING PBU/ll-32 500292251200 NORTH SLOPE COMPUTATION DATE: 10/26/94 DATE OF SURVEY: 102494 JOB NUMBER: AK-MW-40086 KELLY BUSHING ELEV. = 64.10 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL VERTICAL DEPTH DEPTH DEPTH CORRECTION 3534 3464.10 3400.00 3655 3564.10 3500.00 3780 3664.10 3600.00 3911 3764.10 3700.00 4046 3864.10 3800.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE 360.06 N 76.36 E 70.65 427.34 N 74.67 E 91.20 502.69 N 71.97 E 116.47 587.79 N 69.12 E 147.84 677.34 N 67.97 E 182.08 17.39 20.55 25.27 31.37 34.24 4180 3964.10 3900.00 4318 4064.10 4000.00 4458 4164.10 4100.00 4602 4264.10 4200.00 4747 4364.10 4300.00 4892 4464.10 4400.00 5038 4564.10 4500.00 5184 4664.10 4600.00 5329 4764.10 4700.00 5474 4864.10 4800.00 5619 4964.10 4900.00 5764 5064.10 5000.00 5910 5164.10 5100.00 6056 5264.10 5200.00 6202 5364.10 5300.00 6346 5464.10 5400.00 6492 5564.10 5500.00 6635 5664.10 5600.00 6778 5764.10 5700.00 6922 5864.10 5800.00 7065 5964.10 5900.00 7208 6064.10 6000.00 7351 6164.10 6100.00 7493 6264.10 6200.00 7636 6364.10 6300.00 7779 6464.10 6400.00 7922 6564.10 6500.00 8067 6664.10 6600.00 8210 6764.10 6700.00 8352 6864.10 6800.00 766.90 N 67.68 E 861.39 N 66.07 E 959.93 N 67.75 E 1062.96 N 62.86 E 1168.03 N 57.38 E 1273.65 N 49.66 E 1378.57 N 41.91 E 1484.47 N 30.77 E 1589.94 N 20.02 E 1694.44 N 9.75 E 216 . 253 . 294. 338 · 383 . 428 . 473 . 520. 565. 610. 1797.97 N .41 W 655. 1903.29 N 7.89 W 700. 2009.83 N 14.25 W 746. 2116.00 N 18.12 W 792. 2222.04 N 23.19 W 838. 2326.01 N 27.08 W 882. 2431.60 N 32.83 W 928. 2534.08 N 36.91 W 971. 2636.03 N 42.21 W 1014. 2739.06 N 51.13 W 1058. 2840.56 N 60.30 W 1101. 2942.58 N 66.58 W 1144. 3044.54 N 72.01 W 1187. 3145.69 N 74.32 W 1229. 3247.29 N 78.63 W 1272. 3350.23 N 84.36 W 1315. 3452.49 N 89.00 W 1358. 3556.29 N 93.77 W 1403. 3658.36 N 100.78 W 1446. 3759.15 N 106.70 W 1488. 32 93 35 02 18 83 99 07 8O 81 11 55 8O 71 55 87 41 66 57 44 24 24 17 43 07 71 84 O6 13 23 34.24 37.61 40.43 43.67 45.16 45.65 45.16 46.08 45.74 45.00 44.30 45.43 46.25 45.91 45.85 44.31 45.54 43.25 42.91 43.87 42.80 43.00 42.93 42.26 42.64 43.64 43.13 44.23 43.07 42.10 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PRUDHOE BAY DRILLING PBU/ll-32 500292251200 NORTH SLOPE COMPUTATION DATE: 10/26/94 DATE OF SURVEY: 102494 JOB NUMBER: AK-MW-40086 KELLY BUSHING ELEV. = 64.10 OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL VERTICAL DEPTH DEPTH DEPTH CORRECTION TOTAL RECTANG~ COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE 8494 6964.10 6900.00 3860.73 N 109.50 W 1530.82 8637 7064.10 7000.00 3961.66 N 110.43 W 1572.91 8780 7164.10 7100.00 4064.34 N 111.20 W 1616.24 8924 7264.10 7200.00 4168.09 N 113.71 W 1660.36 9067 7364.10 7300.00 4270.83 N 116.54 W 1703.77 42.59 42.08 43.33 44.12 43.40 9211 7464.10 7400.00 4373.24 N 120.15 W 1746.95 9354 7564.10 7500.00 4475.34 N 124.10 W 1789.92 9496 7664.10 7600.00 4576.73 N 128.20 W 1832.38 9637 7764.10 7700.00 4676.56 N 132.39 W 1873.75 9773 7864.10 7800.00 4768.46 N 132.05 W 1909.59 43.18 42.97 42.46 41.37 35.84 9903 7964.10 7900.00 4851.58 N 129.54 W 1939.66 10029 8064.10 8000.00 4926.82 N 122.23 W 1965.04 10150 8164.10 8100.00 4993.85 N 110.13 W 1986.06 10268 8264.10 8200.00 5055.78 N 96.88 W 2004.44 10385 8364.10 8300.00 5114.67 N 81.74 W 2021.48 30.07 25.38 21.02 18.37 17.04 10501 8464.10 8400.00 5170.78 N 65.05 W 2037.35 10616 8564.10 8500.00 5226.13 N 48.81 W 2052.80 10732 8664.10 8600.00 5281.37 N 34.20 W 2067.97 10847 8764.10 8700.00 5336.95 N 20.72 W 2083.17 10961 8864.10 8800.00 5390.14 N 7.09 W 2097.26 15.87 15.45 15.17 15.20 14.09 11003 8900.99 8836.89 5408.72 N 1.82 W 2102.01 4.75 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS PAGE FT. 8/24/95 NO. 9660 GeoQuest 500 W. International Airport Road ~ Company: Alaska Oil & Gas Cons Corem Anchorage, AK 99518-1199 ~ ~ Attn: Larry Grant A'rTN: Sherrie / _~/ , x "~'"~'~ \ 3001 Porcupine Drive Anchorage, AK 99501 I/ Field: Prudhoe Bay Floppy Wel Job # Log Description Date BL RF Sepia DIR MWD Disk ID.S. 15-33 " 95250 DUAL BURSTTDT-P 950623 1 D.S. 5-36 q l '7 C~' PROD PROFILE .. 950731 "1 i " O.S. 7-33~ ~ ~DUAL BURST TDT-P 950729 1 1 D.S. 11-27 I C~G 950730 1 1 D.S. 11-32 ~ ~ '~ ~ PERFRECORD 950730 1 1 D.S. 12-01 ~.~ ~% PRODLOG 950728 1 I ,., D.S. 12-12~{ ~ ~ GAS LI~ SURVEY 950727 1 1 D.S. 12-28 ~ ~ ~ ~ J PROD pROFILE 950725 1 1 D.S. 12-29 ~ O ~ PROD PROFILE 950725 1 1 D.S. 13-3 ~ ~~ PROD PROFILE 950731 I 1 ~D.s. 15-1~-~ 4>O [~ DUAL BURSTTDT-P 950726 1 1 D.S 15-13 ~ t ~% DUAL BURST TDT-P 950727 I 1 D.S. 15-25 ' ~ ~ ~ DUAL BURSTTDT-P 950725 1 1 D.S. 17-20 ~ II ~ ~PERFRECORD 950730 I 1 D.S. 18-02A ~ ~ ~ ~ PERFRECORD 950726 I 1 D.S. 18-02A ¥ ~ ~~ PROD FLUID SAMPLER 950722 I I Alaska Oil & Gas Cons. C°rn/7715Sion Si G NED: DATE: Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'I'TN: Sherrie NO. 9596 Company: 7/27/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk !D,s. 2-13A ~,:-~, ............ ~:."~: PRODUCTION PROFILE 950701 I 1 D.S. 2-34 ~il t L{ C[ DUAL BURST TDT-P 950702 I 1 D,S. 5-10A ~'~ ~ ~ PRODUC~ONPROFILE 950703 1 , 1 D.S. 6-17 ~ ~ '~ PRODUC~ONPROFILE 950706 I ' 1 D.S. 7-13A q ~ t ~ DUAL BURST TDT-P 950704 I ,' 1 ~ D.S, 7-16 ~' ~ I ~ ~ ~NJEC~ON PROFILE 950704 - 1 I ~ D.S. 7-33 ~ ~' ~ ~ INJEC~ON PROFILE 950702 I ', 1 D.S. 7-33 STA~C PRESSURE SURVEY 95 07 02 I 1 D.S. 7-34 ~ ~ ~ ~ TDT-P BORAX .. 95 07 02 I 1 D.S. 7-34 ~MPERAmRE SURVEY 9 5 07 02 I 1 D.S. 11-31 ~[ ~ ~ PERFO~NGRECORD 950707 I 1 D.S. 11-32 ~ Ct t ~ '~ PERFO~NG RECORD 950707 I ' 1 D.s. 14-3 7'? ~~_ ~NF~TA~LE SR~OGE PLUG 9S070S I 1 D.S. 18-18A 47 TDT-P 950707 I SIGNED Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9183 Company: 1/10/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar D.S. 3-7 "7 ~.~--6 _~_~Z~ STATIC BH PRESS SURVEY (12-11-94) I 1 D.S. 3-14~'"~ ~ ~.-~ TUBG CUTTER RECORD (12-11-94) I 1 D.S. 3-14 l I - ~) ~)' ~'~ STATIC BH PRESS SURVEY (12-11-94) I 1 D.S. 4-27 ~'~--~ ~ STATIC BH PRESS SURVEY (12-14-94) I 1 O.S. 4-28 ~ ~)~ ;;:Z~:~ STATIC BH PRESS SURVEY (12-14-94) I 1 D.S. 4-44 ' ,~ I~ ~ (~-ij'~) DUAL BURST TDT-P (12-13-94) I 1 D.S. 4-45 c~/~_ (~,~ L~ DUAL BURST TDT-P (12-12-94) I 1 D.S. 5-16A C~ L~ ..~ { _-~ TUBG PUNCHER & POGLM SETTING RECORD (12-13-94) I 1 D.S. 9-32 ~'-~-~'-----.J J~7.~ INJEC PROFILE (12-12-94) / I 1 D.S. 11-32 ~ ~//-"/,~1 STATIC BE PRESS SURVEY (12-12-94) J' I 1 D.S. 15-40 ~ L~...- \'~ PDC (12-11-94) I 1 D.S. 3-13 -7 ~-1-- ~3'~ ~, STATIC PRESS SURVEY (12-19-94) I 1 su.w D.S. 4-20 . INJEC PROFILE (12-14-94) I 1 D.S. 5-33 '~, 1'~ b (0~2 PERF RECORD (12-19-94) I 1 D.S. 11-30~,~6 '~7 STATIC PRESS SURVEY (12-16-94) I 1 D.S. 12-27 ~ '-(~5 INJEC PROFILE (12-21~-94) I 1 D.S. 15-23 -" I PROD LOG (CT E-LINE) (12-19-94) I 1 D.S. 16-21 ~ ~'~ ~ ~ INFLATABLE BRIDGE PLUG SET RECORD (12-20-94) I '1~ I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ANNULAR INJECTION DATA ENTRY SCREEN Asset .EOA ........................................... Legal Desc ....................................................................................................................... Research Rig Name ..................................................... · ....................................................................................................................... Ca r~:act, ed..c,Q l~..~e~ L~;o..~I3.G.C.C..~p...3.;.1.7..~ 9.7. ......... Inj Well Name .:[..1.r.,32_.....; ............................... Permit Start ....... :[./..:1..~.~.~ ...... Permit End.....l.2~.3..1.J..9..&... Sur Csg Dep .3.9.ZD .............. · ............................................................. Cumulative Data Daily Data DS 11-34 11/10/94 DS 11-34 11/11/94 DS 11-34 11/12/94 DS 11-34 11/13/94 110 DS 11-34 11/14/94 320 DS 11-34 11/15/94 200 DS 11-34 11/16/94 DS 11-34 11/17/94 216 DS 11-34 11/19/94 440 i' 3,180 __ from DEAP computer records GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9134 Company: 12/5/94 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar PWDW 3-1 -'~ (~ ~ :STATIC BHP SURVEY (11-15-94) 1 = 1 D.S. 3-7 7~'" ~0 ~--__~ ~PERF RECORD (11-20-94) I 1 D.S. 3-10 ? ~-O~-! ~INJEC PROFILE (11-17-94) I 1 D.S. 3-32A ~;~/~' ~ ~7~-d~,~- ~r =PROD PROFILE (11-14-94) 1 1 D.S. 4-19 ~ - O ~-I DUAL BURST TDT-P (11-21-94) I 1 D.S. 7-19 ~-'-~-~ 7 CNL ((11-13-94) I 1 D.S. 9-21 ~ ~ ~--//~. O LEAK DETECTION (11-11-94) I 1 D.S. 9-21 ~ ~-'-~ .-- ? ~. O TUBG PATCH RECORD (11-22-94) I 1 D.S. 9-47 .~ O ," ,/'~ PROD PROFILE (11-15-94) I 1 D.S. 9-49 ~', '~ ?-~-'t.~ ~ PROD PROFILE (11-14-94) I 1 D.S. 11-31~ ~,.c~..,--.{'2_7 R.O.P.E. PERF RECORD (11-14-94) I 1 D.S. 11-32 ~/~ ~.~ ~7/--/,~..]. R.O.P.E. PERF RECORD (11-15-94) I 1 D.S. 15-41 '~;2_~-' ~ GR-CCL (11-11-94) 1 1 D.S. 16-21 ~.~/7_~ LEAK DETECTION (11-22-94) I 1 D.S. 17-7 ~-/~d~ LEAK DETECTION (11-16-94) 1 1 D.S. 17-13 . ~ ~/? ~ LEAK DETECTION (11-16-94) 1 1 SIGNED' · Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9115 Company: 1 1/1 6/94 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar D.S. 11-32 -!'~- / USIT (11-11-94) I 1 D.S. 11-31 (~ //,~._7 CBT (11-9-94) 1 1 D.S. 11-31 "' USlT (11-9-94) I I , SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: Enclosed, please find the data as described below: Tapes/Diskettes: 1 DIFL/AC/CN/ TAPE/LIS Date: RE: 8 November 1994 Transmittal of Data ECC #: 6294.00 Sent by: HAND CARRY Data: LDWG 11-32 ~~0 NORTH SLOPE, AK Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Or FAX to (907) 563-7803 Received by v:~~~_j ~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: ARCO 11-32 PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Date: RE: Prints/Films: 1 SSVD FINAL BL Run # 1 1 SSVD FINAL. RF Run # 1 1 DIFL/GR/SP FINAL BL Run # 1 1 DIFL/GR/SP FINAL RF Run # 1 1 CN/GR FINAL BL Run # 1 ! CN/GR FINAI. RF Run # 1 1 BHC/AL/GR FINAL BL Run # 1 1 BHC/AL/GR FINAL RF Run # 1 1 November 1994 Transmittal of Data ECC #: 6294.00 Sent by: MAIL Data: LDWG P~±ease sign and return to: Atlas Wireline-E~r~i-se~ 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson ~ Or FAX tq (907) 563-7803 Received by: ._~_~'-~,~/~// / Date D I=! I I_1_ I INJ (~ ARCO Alaska, Inc. AOGCC, Larry Grant PO Box 100360 Anchorage, AK 99510-0360 October 26, 1994 Re: Survey Data- Well 11-32 Dear Mr. Grant, Enclosed are two hard copies of the MWD survey on well 11-32. Please call me at 563-3256 if you have any questions. Sincerely, Region Assistant Enclosure. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: David Johns ~I~~, Chairman--h'-',~ Blair Wondzell, ~ P. I. Supervisor ~[=~ er~'-~ FROM: Bobby Fost SUBJECT: Petroleum Inspector DATE: FILE NO: October 18, 1994 AFRIJRBD.doc BOPE Test - Nabors 28E ARCO - PBU - DS11-32 PTD # 94-131 Prudhoe Bay Field Tuesday, October 18, 1994; I traveled this date to ARCO's DS11-32 being drilled by Nabors rig 28E and witnessed the initial BOPE test. As the attached AOGCC BOPE Test Report shows there was one failure. The bottom flange on the BOP leaked. It was tightened and retested OK. The rig was clean and all the equipment seemed to be in good working order. The location was clean and there was good access to all areas of the rig. There was a "TOP JOB", consisting of 225 sacks of Perma- Frost cementl done on this surface pipe. Summary: I witnessed the BOPE test on Nabors 28E - test time 3 hours - 1 failure. Attachment: AFRIJRBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drig Contractor: Operator: Well Name: Casing Size: 10 3/4 Test: Initial X Workover: NABORS Rig No. 28E PTD # ARCO Rep.: DS 11-32 Rig Rep.: Set @ 4,412 Location: Sec. Weekly Other DATE: 10/18/94 94-131 Rig Ph.# 659-4863 JOHN RALL MIKE DOWNEY 33 T. 11N R. 15E Meridian UM MISC. INSPECTIONS: Quan. Location Gen.: OK Well Sign OK 1 Housekeeping: OK (Gen) Dri. Rig OK 1 Reserve Pit N lA I BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F 1 300,/'3,000 P I 500/5,000 P I 500/5,000 P I 500/5,000 P 3 500/5,000 P 2 500/5,000 P 3 500/5,000 P N/A ~ MUD SYSTEM: Visual Alarm Trip Tank YES OK Pit Level Indicators YES OK Flow Indicator YES OK Meth Gas Detector YES OK H2S Gas Detector YES OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP ¸ : Test Pressure P/F 500/5,000 P 500/5,000 P 500/5,000 b 500/5,000 P CHOKE MANIFOLD: No. Valves 18 No. Flanges Manual Chokes 2 Hydraulic Chokes I Test Pressure P/F 500/5,000 P 48 500/5,000 P P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: 8 ~, 2000 3,000 IP P minutes 22 sec. minutes 31 sec. YES Remote: YES Psig. Number of Failures: I ,Test Time: 3.0 Hours. Number of valves tested 26 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. !. Supervisor at 279-1433 REMARKS: Failure: The flange between the bottom pipe rams and the well head leaked - tightened and retested OK Distribution: orig-Weli File c - Oper./Rig c - Database c- Tdp Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Wrtnessed By: BOBBY D. FOSTER FI-O21L (Rev. 7119) AFRIJRBD.XLS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: 'David J~ DATE: Chairmar,~--~-~ THRU: FILE NO: Blair Wondzeil, P. I. Supervisor FROM' Bobby Foste~~ SUBJECT: Petroleum Inspector October 14, 1994 EFRIJNBD.doc Diverter Inspection and Test ARCO - PBU - DS 11- 32 PTD # 94-131 Prudhoe Bay Field Friday, October 14, 1994:. I traveled this date to Nabors 28E on ARCO's DS 11-32 and inspected the diverter system for correct installation and witnessed the accumulator test and valve function. As the attached AOGCC Diverter inspection Report shows the diverter was installed properly and the system functioned properly. Summary: I inspected the diverter system on Nabors 28E and found it in good working order. ' Attachment: EFRIJNBD.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Operation: Development Ddg Contractor: NABORS Rig No. 28E PTD # Operator: ARCO Oper. Rep.: Well Name: DS 11-32 Rig Rep.: Location: Sec. 33 T. 11N R. 15E Merdian UMIAT Date: 10/14/94 × Exploratory: 94-131 Rig Ph. # 659-4863 JOHN RALL MIKE DOWNEY MISC. INSPECTIONS: Location Gen.: OK Well Sign: NO Housekeeping: OK (Gen.) Ddg. Rig: OK Reserve Pit: NA Flare Pit: NA DIVERTER SYSTEM INSPECTION: Diverter Size: 20 in. Divert VaNe(s) Full Opening: YES VaNe(s) Auto & Simultaneous: YES Vent Line(s) Size: 16 in. 'Vent Line(s) Length: 70 ft. Line(s) Bifurcated: NA Line(s) Down Wind: YES Line(s) Anchored: YES Tums Targeted / Long Radius: NA ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: 3000 1700 min. 24 min. 36 2000 MUD SYSTEM INSPECTION: Light Tdp Tank: OK Mud Pits: OK Flow Monitor: OK Alarm OK OK OK Alarm OK OK GAS DETECTORS: Light Methane OK Hydrogen Sulfide: OK psig psig sec, sec. psig Existing Wellhouse ~ 16" Hydraulically Operated Tie Do~p / Full Opening Knife VaNe ~' Tie Down Atmosphere V _L_ ,~, ~ ~ I ~ 28E Rig and Sub Base ~ 16" Vent Line / ~, I \ 20" Annular Preventer Prevailing Wind Direction Existing Wellhouse Non Compliance Items 0 Repair Items Within Remarks: GOOD TEST 0 Day (s) And contact the Inspector @ 659-3607 Distribution orig. - Well File c - OpedRep c- Database c - Trip Rpt File c- Inspector AOGCC REP.: EFRIJNBD.XLS ALASKA OIL AND GAS CONSERVATION COMMISSION October 11, 1994 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Terry Jordan Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Unit DS 11-32 ARCO Alaska, Inc. Permit No: 94-131 Sur. Loc. 48'SNL, 125'WEL, Sec. 33, TllN, R15E, UM Btmhole Loc. ll2'SNL, 80'WEL, Sec. 21, TllN, R15E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~~a~r~E~O--~---' ~ION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl, Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.OO5 la. Type of work Drill [] Redrilll"lllb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 64.5 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. 0. Box 196612, Anchora(Te. Alaska 99519-6612 ADL 28322 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 48' SNL, 125' WEL, SEC. 33, T11N, R15E Prudhoe Bay Unit At top of productive interval 8. Well number Number I'NSL, 107' WEL, SEC. 21, T11N, R15E 11-32 U-630610 At total depth 9. Approximate spud date Amount 112' SNL, 80' WEL, SEC. 21, T11N, R15E 10/10/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(MD~,dTVD) property line ADL 28325-5168' feet No close approach feet 2560 11031' MD/8879' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (~,e 20 ^AC 25.035 (e)(2)) Kickoff depth 400 feet Maximum hole angle 46 o Maximum surface 3330 psig At total depth (TVD) ~800'/4~90 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 35' 35' 115' 115' 260 sx Arcticset (Approx.) 13-1/2" 10-3/4" 45.5# NT8OLHE B TC 3954' 34' 34' 3988' 3820' 1310 sx CS #!/375 sx "G"/250 sx CS II 9-7/8" 7-5/8" 29.7# NT95HS NSCC 10086' 33' 33' 10119' 8005' 9- 7/8" 7-5/8" 29. 7# 13CR80 NS CC 912' 10119' 8005' 11031' 88 79' 650 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ,r_-) _ ',,1~/ Surface ~-;.EEF~' [~D Intermediate Production C)C'i~ - ~ 'i~i'~i"-'i Liner Perforation depth: measured ,, ,-~,-,- (iii & Gas, Con';,. Commi:;sion true vertical Anchor:_ :? 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l~ Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify.that th.~:, f(~,,regoing is true and correct to the best of my knowledge Signed ,~,1/~. / [\/~,,.~x~.. . ~:'~ ':!,'! ~'"/ ·. . /\~ ~r~,~.".-'-' .... . Title Drilling7 Engineer Supervisor Date i , ",; ~ ~ Commission Use Only ~;'~"-/').~// 150'0~-- '~'" 'Z-'2-'"~"'//2--I..~' '"//-'- for other requirements Conditions of approval Samples required [] Yes [] No Mud log required~¢es [~ No Hydrogen sulfide measures [] Yes J~ No Directional survey required J~ Yes [] No Required working pressure for DOPE []2M; 1-13M; ]~L5M; F-I10M; ['-]15M; Other: d¢igll'la.! Signee By by order of Approved by Oavid W. Johnston Commissioner tne commission Date /~-"//~ Form 10-401 Rev. 12-1-85 Submit in triplicate I Well Name: IDS 11-32 I Well Plan Summary I Type of Well (producer or Injector)' I PRODUCER J ISurface Location: Target Location' Bottom Hole Location' 48' FNL, 125' FEL, SEC 33, T11N, R15E 1' FSL, 107' FEL, SEC 21, T11N, R15E 112' FNL, 80' FEL, SEC 21, T11N, R15E IAFE Number:14J0273 ! IEstimated Start 110/10/94 IDate' IRig: [ Nabors #28E IOperating days to 115 complete: !uD. 111,031' I ITVD' 18,879' I I KBE' J64.5' IWeil Design (conventional, slimhole, etc.): FormatiOn Markers: Slimhole Longstring Formation Tops MD TVD (KB) Comments SV3/T-5 3,909' 3,765' K-15 5,492' 4,865' Top Ugnu 6,788' 5,765' Top of Cretaceous Injection Interval Base Ugnu 8,227' 6,765' Bottm of Cretaceous Injection Interval K-10 8,911' 7,240' K-5 9,659' 7,765' LCU/Sag/Shublik 10,419' 8,350' Sag River is expected to be truncated TSAD 10,419' 8,350' Zone 3 10,528' 8,444' Zone 2A/Romeo 10,754' 8,640' Target 10,801' 8,681' PGOC BSAD 10,881' 8,750' TD 11,031' 8,879' 150' md below BSAD Casincl/Tubing Proqram: Hole csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg MD/TVD MD/TVD O.D. 30" 20" 91.5# H-40 Weld 80' 35' 115'/11 5' 13-1/2" 10-3/4" 45.5# NTSOLHE BTC 3,954' 34' 3,988'/3,820' 9-7/8" 7-5/8" 29.7# NT95HS NSCC 10,086' 33' 10,119' / 8,005' 9-7/8" 7-5/8" 29.7# 13CR80 NSCC 912' 10,119'/ 11,031' / 8,005' 8,879' TBG 4-1/2" 12.6# 13CR80 FOX 10,287' 32' 10,319'/ 8,235' Logging Program: Open Hole Logs- SURFACE INTERMEDIATE PRODUCTION Cased Hole Lo~Is' RECEIVED None . ~:,,u4 N/A .,,~..'.',.,~ ~ ,~ clas Cons. Commission Triple Combo (Sor~ic/Iqeutron/Resistivity) from TD to 200' ~d Anchor; ~ above TSAD (~ 10,219' md). GR to surface I Post-Rig Oement Evaluation (either USIT/OBT or PNL/Borax/ , I VHH DS 11-32 Well Plan Date Revised' 9/27/94 Page 2 Mud Program: Special design considerations I1% KCI mud will be used to drill the Sadlerochit. The chlorides should stay in the 5,000 - 10,000 ppm range. Surface Mud Properties' I Spud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5-9.2 200-350 30-60 30-60 40-80 9-1 0 15-25 Production Mud Properties- I Fresh LSND (above TSAD) Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel ~tel Loss 9.2-9.9 25-50 8-13 3-10 7-15 9.5-10 6-10 Production Mud Properties- I1% KCI (below TSAD) Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.7-9.9 25-50 8-13 3-10 7-15 9.5-10 <7 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: !KOP: I® ! Maximum Hole Angle- 46.0° Angle Through Target: 30.0° Close Approach Well' No ne No wells will be secured as part of any drilling close approaches. Disposal: Cuttings Handling- CC2A Fluid Handling- Haul to CC2A Annular Injection: The following wells can currently be used for injection purposes at DS 11. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED VOL (BBLS) (BBLS) EEA DS 11-29 5,158 35,000 1/1/94-12/31/94 BDA DS .11-36 3,595 35,000 1/1/94-12/31/94 BDA DS 11-35 7,466 35,000 1/1/94-12/31/94 BDA DS 11-30 15,153 35,000 1/1/94-12/31/94 EEA DS 11-33 4,046 35,000 1/1/94-12/31/94 RECEIVED OCT - 6 '199~i 0il & (,as Con,:. Commission VHH DS 11-32 Well Plan Page 3 Date Revised' 9/27/94 . , o , , , . . o 10. Operations Summary MIRU drilling rig. N/U diverter and function test same. Drill 13-1/2" hole to surface casing point at 3,988' md using Sperry Sun's directional MWD. Run and cement 10-3/4" 45.5 ppf NT80 BTC surface casing. Nipple up BOPE and function test same to 5,000/250 psi. PU 9-7/8" BHA and RIH. Test casing to 3,000 psi for 30 minutes. Drill 10' of new hole and perform a leak off test. Drill 9-7/8" hole to TD at 11,031' md using Sperry Sun's directional MWD. Total depth is based on drilling 150' md after reaching the BSAD (+ 10,881' md). At + 10,320' md (or approximately 100' above TSAD), perform an openhole mud changeout to a 1% KCI mud system. At TD, log using Atlas wireline's Triple Combo (Neutron/Sonic/Resistivity) from 200' md above TSAD to total depth (back-up will be drill pipe conveyed logs which should be on stand-by). Perform a conditioning trip after wireline logs. Run and cement 7-5/8" 29.7 ppf NT95 & 13CR80 NSCC production casing. Run Chrome casing from TD to 300' above the TSAD. Bump the plug with filtered seawater. Test production casing to 3,500 psi for 30 minutes. P/U the tubing tail, a 7-5/8" x 4-1/2" production packer, assorted GLM's, and SCSSV, and RIH on 4-1/2" 12.6 ppf 13CR80 FOX tubing. The tubing tail will contain an 'X' nipple which will be the only nipple in the tubing. Place the tubing tail 100' above the TSAD. Set the production packer and test tubing integrity. N/D BOP's, N/U the production tree and test the same. Freeze-protect the tubing and production annulus with diesel through the shear valve located in the top GLM station. Freeze-protect the 10-3/4" X 7-5/8" annulus by bullheading 50/50 methanol. Release the Rig. VHH DS 11-32 Well Plan Page 5 Date Revised: 9/27/94 Surface Casing Cement Program Cement Supplier- BJ Services CASING SIZE: 10-3/4" CIRC. TEMP 40°F SPACER: 50 bbls fresh water ahead of lead slurry. LEAD CEMENT TYPE: Coldset II! ADDITIVES: FP-6L: 1 ghs WEIGHT: 12.2 ppg YIELD: 1.92 ft3/sx APPROXIMATE SACKS: 1310 sx (448 bbls) MIX WATER: 10.5 gps THICKENING TIME: >4hrs@40°F TAIL CEMENT TYPE: CLASS G ADDITIVES: A-7: 2%; FP-6L: 1 ghs WEIGHT' 15.8 ppg YIELD:1.15 ft3/sx APPROXIMATE SACKS: 375 sx (77 bbls) MIX WATER: 5.0 gps THICKENING TIME: >3.5 hrs @ 40° F TOP JOB CEMENT TYPE: Coldset II WEIGHT: 15.0 ppg APPROXIMATE SACKS: 250 YIELD:1.15 ft3/sx CENTRALIZER PLACEMENT: 1. Run one (1) bow type centralizer per joint for the 1st 15 joints. 2. Place the centralizers in the middle of each joint with a stop collar. CEMENT VOLUME: 1. Lead slurry to surface with 100% excess. 2. Tail slurry volume - 375 sx. 3. Top job volume - 250 sx. MIX WATER: 3.7 gps ., VHH DS 11-32 Well Plan Page 8 Date Revised: 9/27/94 Production Casing Cement Pro'gram Cement Supplier- BJ Services CASING SIZE: 7-5/8" CIRC. TEMP 130°F SPACERS: 20 bbls 2% KCI fresh water 70 bbls MCS-4 Spacer mixed with 2% KCI (weighted one ppg over current MW) LEAD CEMENT TYPE: Class G ADDITIVES' A-2' 3%, WEIGHT: 11.0 ppg FL-52: 0.4%, YIELD: 3.31 ft3/sx APPROXIMATE SACKS: 250 sx ( 147 bbls) FLUID LOSS' 150-250 cc CD-32: 0.5%, FP-6L: 1 ghs MIX WATER: 20.9 gps THICKENING TIME: >5 hrs @ 130°F FREE WATER: 0.0 cc TAIL CEMENT TYPE' ADDITIVES: Class G FL33: 0.3%, FP-12L: 1 ghs, CD32: 0.6%, A9' 2.0%, Gel 0.25%, S-400: 0.2% WEIGHT: 15.7 ppg YIELD' 1.19 ft3/sx APPROXIMATE SACKS' 400 sx ( 85 bbls) FLUID LOSS: <50 cc @ 130° F BA86-L: 175 ghs, A-2' 0.1% MIX WATER' 5.2 gps THICKENING TIME' 2.5 to 3 hfs FREE WATER: 0.0 cc CENTRALIZER PLACEMENT' 1. Two 9-5/8" x 7-3/4" turbolators per joint from TD to 300' md above TSAD. (TSAD@_10,419' md) Estimated Interval: 10,119' to 11,031' md - _+46 turbolators needed. 2. One 9-5/8" x 7-3/4" centralizer per joint (one Piece, straight blade) from 300' md below Cretaceous to 300' md above Cretaceous. Estimated Interval: 6,488' to 8,527' md - _+51 centralizers needed. CEMENT VOLUME' 1. Lead Slurry to 300' md above the top of Cretaceous (top of Cretaceous @ 6,788' mC) with 30% excess. 2. Tail Slurry to 1,000' md above Top of TSAD (TSAD@-+10,419' md) with 30% excess. ' ', (;:~;; {';orig. (;0rrlr~i-2sioP, /',', ';.,!!!jr- .~ VHH DS 11-32 Well Plan Date Revised' 9/27/94 Page 11 Prudhoe Bay Drilling. Prudhoe Bay Unit Drillsite 1 1 AS-BUILT 11-32 Wp7 9/30/94 l 1,08 ~m HALLIBURTON V]~RTICAL V]]~W SCA/~E 500 ft. / DMSION T'v-D REF: ~FELLHEAI) ~RTIC~ SECTION ~F: ~~ 0,00' ~ 0 MB TIE IN 0.00'~ 400 MD KOP / START DF BUILD ~ 1.00'/100 Ft 8.00'~ 600 MD 4.00'~ 800 MD 6.00'~ 1000MD END DF BUILD 6.00'~ llOOMD START DFCURVEe 1.O0'/IDO7% 4.00'~ 1300MD 2.00'~ 1500MD 0,00'~ 1700MD END DF CURVE 0.00'~ 1867MD BASE PERMAFROST O.OO'~ 2303 MD START DF BUILD ~ 2.OD'/lDO F% 4.00' ~ 2503 MD B DO' ~ 2703 MD START DF CURVE R 3.00'/100 F~ 13.99' R 8903 MD 19.99' ~ 3103 MD 85.99' ~ 3303 MD 31.99' ~ 3503 MD 37.99' ~ 3703 MD .00' ~ D 1685 46.00' ~ 5498 MD K-15 8616 3649 HORIZONTAL VIE~ (TRUE NORTH) SCALE 500 ft./ DMSION SURVEY REF: WELLHEAD 46,00' ~ 6788 MD TOP OF CRETACEDUS INJECTION 3.16, 7823 570 - ~240 - 3'W. 00' 6764 - 557,00' 5765 - 35' ,00' __ 4865 - 3f .00' __ -- 3/4 ~ 00, ~ 3988 M~ 3820 TVD [ 3807 3 00' 3686 09' 3528 ' ~ 23' 3359 - '157.4l' 3086 - ~57.87' ~699 -1.00' 500 0 500 46,00' ~ 8827 MO BOTTOM OF CRETACEOUS INJECTION 4140 4409 467~4727 4844 ~514251495163 53055328 5335 ~3675395 5398 -500 0 500 1000 1500 2000 2500 3000 VERTICAL S~CTION PLANE: 0.~8 46.00' R 8911 MD K-10 46,00' e 9886 MD START DF CURVE ~ 2,50'/100 F~ 44.70' ~ 9486 MD 43,91' ~ 9659 MD K-5 43,65' ~ 9740 MD END DF CURVE 43,65' ~ 9915 MD START OF CURVE ~ 8.50'/100 f% ~hubUk/ T~AD-I~h~k/ Zone 4~-Z~u 5440 7 5/8 in 00~ e L%031 MD, R 1/031 MD 3500 4000 4500 5000 5500 GO00 CRITICAL POINT DATA MD Inc Azl. TVD N/$ E/W TIE IN 0 O,OO' 90.00' 0 0 N 0 E KDP / START 400 O,OO' 90.00' 400 0 N 0 E DF BUILD ~ l. O0'/lO0 ~ END DF BUILD 1000 6.00' 90,00' 999 DN 31 E START DF 1100 6.00' 90.00' 1098 0N 42 E CURVE ~ 1.00'/100 ~ END DFCURVE 1700 0.00' 0.00' 1697 0N 73E BASE 1867 0,00' O,OO' 1865 ON 73E PERMAFROST START DF BUILD 2303 0,00' 0,00' 8300 ON 73 E ~ 8.00'/100 ~TART OF 27038.00' 0.00' 8699 88 N 73 E CURVE ~ 3.OD'/lO0 F~ T-5 390944.19' 357,03' 3765 . 549N 51 E END DFCURVE 397046,00' 357,00' 3807 592N 48E K-15 549~46.00' 357.00' 4865 1685N 9 W TOP DF 678846.00' 357.00' 5765 8616N 58 ~ CRETACEOUS INJECTION BDTTOM OF 888746.00' 357.00' 6764 3650N 112W CRETACEDUS INJECTION K-10 891146,00' 357.00' 7240 4141N 138W START OF 988646,00' 357,00' 7500 4411N 158~ CURVE ~ 2.50'/100 F% K-5 965943.91' 9.88' 7764 4673 N 136W END OF CURVE 9740 43.65' 12.80' 7823 4728N 125W START OF 9915 43.65' 12,80' 7949 4845N 99 W CURVE ~ 2.50'/100 F~ LCU-Ivl~h~k/ 1041931.06' 13.87' 8349 5143N 29 W S~g River/ Shub[Ik/ TSAD-Iv~shak/ Zone 4B-Zulu Zone 4A - 1043330.71' 13.92' 8361 5150N 27 W X-Ray END DF CURVE 1046130.00' 14.00' 8386 5164N 24 W Zone 3 1058830.00' 14.00' 8443 5196N 15 W Zone 8 /EC 1058530.00' 14.00' 8493 58C4N 8 W Zone 88 - 1063630,00' 14.00' 8537 5848N 8 W T~ngo Zone 8A - 1075430,00' 14.00' 8639 5305N 1E E Romeo T~rget / PGOC 1080130,00' 14,00' 8680 5388N 18 E Zone lB - 1081430.00' 14.00' 8691 5335N 19 E Lower Romeo PDWC / DDWC / lOBB130,00' 14,00' 8749 5367N 27 E Top HD/T / ~SAD - K~vlk RAZOR 8000 10939 30.00' 14,00' 8799 5395N 34 E K~v~k S~nd 10945 30,00' 14,00' 8804 5398N 35 E ITergetName TVD NS EW Grid X Grid Y J 1 1 T~roet 8681 5388 N 18 E 707300 5957000 CASING PDINT DATA OD MD Inc Az; TVD 10 3/4 In 3988 46.00' 357.00' 3820 605 N 48 E 7 5/8 In 11031 30,00' 14,OD' 8879 5440 N 45 E PROPOSED Bt{L TV'D 8879.40 MD 11031.08 VS 5440.08 N/S 5439.89 N E/~ 45.41 E D=%e Plo%%ed , 9/30/_94~ Crea~ed By i~ Checked By Approved By D~e , ~]' ~ WELL PERMIT CHECKLIST FIELD & POOL ~~'~ COMPANY INIT CLASS WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev~ redrll [] serv [] /~~ ON/OFF SHORE ~f[~ ADMINISTRATION 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ....... N ENGINEERING REMARKS APPR 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg..~~ 17. CMT vol adequate to tie-in long string to surf csg . . . 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~~3 psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... 29. Is presence of ~2S gas probable ............. Y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y ~ 32. Seismic analysis 9f shallow gas zones .......... Y/N 33. Seabed condition survey (if off-shore) ......... / N 34. Contact name/phone for weekly progress reports . . . / Y N [exploratory only] GEOLOGY: ENGINEERING: COMMI SS ION: E~w~ ~o/,, l ~ JDH ~'~ RAP Comments/Instructions: HOW/lo - A:~FORMS~cheklist rev (33/94 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 simp!ify 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. ARCO ALASKA INC D.S. 11 - 32 ~~/~/~/ PRUDHOE BAY NOV 10 1994 AJaska Oil & Gas Cons, Anchorage Run 1' 25 - October - 1994 DIFLIACICNIGR 0150 ATLAS Atlas Wireline Services 10986 Tape Subfil~ 2 i's type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: 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 3RD STRING PRODUCTION STRING RUN 1 6294.00 BRAD ESARY SEE REMARKS REMARKS: OPEN HOLE D.S. 11 - 32 500292251200 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 04-NOV-94 RUN 2 RUN 3 33 liN 15E 48 125 64.50 29.30 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 10.750 3970.0 9.875 11003.0 DIFL/AC/CN/GR. CIRCULATION STOPPED AT 2330, 24-OCT-94. LOGS WITNESSED BY: J. CARLILE & R. BURNO NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, BOREHOLE CAORRECTION = 9.875", CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CORRECTED FOR BOREHOLE SIZE (9.875"). THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. THE DEPTH SHIFTED RT & DI CURVES ARE INCLUDED IN A TRAILING FILE AFTER RAW DATA AS PER CLIENT'S REQUEST. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10150.0 10920.0 BCS 10150.0 10957.0 DIL 10150.0 10986.0 2435 10150.0 10927.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 10151.5 10154.0 10159.0 10171.5 10171.5 10172.0 10172.0 10215.5 10216.5 10221.0 10221.5 10222.0 10224.0 10225.5 10226.5 10242.5 10242.5 10243.0 10243.0 10257.0 10256.5 10257.5 10258.5 10258.5 10270.5 10270.5 10270.0 10271.0 10273.0 10273.0 10273.5 10297.0 10305.0 10305.5 10306.5 10315.0 10325.0 10325.5 10327.0 10327.5 10343.0 10350.0 10350.0 10352.5 10356.5 10358.5 10359.0 10364.0 10364.0 10366.0 10366.0 10366.0 10382.5 10383.0 10383.0 10390.0 10389.5 10399.5 10399.5 10399.5 10406.5 10406.5 all runs merged; ......... EQUIVALENT UNSHIFTED DEPTH DT LL8 ILD NPHI 10151.5 10154.0 10158.5 10216.0 10217.0 10220.5 10221.5 10222.0 10172.0 10224.0 10243.0 10257.0 10270.0 10270.5 10273.0 10297.5 10306.5 10315.5 10325.5 10326.5 10328.0 10329.0 10344.5 10352.5 10357.5 10358.5 10359.0 10365.5 10382.5 10382.0 10399.5 10399.5 no case 10414.0 10414.5 10417.5 10419.5 10433.5 10443.5 10444.0 10444.5 10453.0 10460.0 10468.0 10470.5 10471.0 10474.5 10476.0 10484.5 10524.0 10524.5 10531.5 10534.0 10554.5 10596.0 10598.5 10599.0 10600.0 10601.0 10603.0 10604.5 10610.5 10611.0 10620.5 10624.0 10624.5 10625.0 10626.0 10626.5 10628.0 10631.5 10632.0 10635.5 10636.0 10637.0 10638.0 10645.5 10646.0 10648.0 10648.5 10658.0 10659.5 10660.0 10662.0 10665.5 10666.0 10668.0 10672.0 10675.0 10676.0 10680.5 10681.0 10682.0 10414.0 10418.0 10445.0 10453.5 10474.0 10534.5 10554.0 10600.5 10627.0 10628.5 10646.0 10648.5 10665.5 10668.0 10417.5 10444.0 10460.0 10471.0 10524.0 10554.0 10601.0 10620.0 10626.0 10628.5 10632.5 10645.5 10648.5 10666.0 10669.0 10672.5 10414.5 10432.5 10442.5 10469.5 10475.0 10524.5 10531.5 10595.5 10598.0 10599.0 10600.0 10603.5 10605.0 10612.0 10612.5 10625.0 10625.5 10626.5 10628.0 10634.5 10635.0 10638.0 10639.0 10657.0 10658.5 10659.5 10661.5 10666.5 10675.0 10676.0 10679.0 10680.0 10417.5 10419.0 10444.0 10467.0 10484.0 10554.0 10601.0 10631.0 10665.5 10672.0 10680.0 10683.5 10685.0 10687.0 10687.5 10690.0 10691.0 10691.5 10697.0 10703.5 10704.5 10705.0 10705.5 10709.5 10710.0 10724.5 10727.0 10728.5 10730.0 10730.5 10734.0 10737.5 10739.5 10740.5 10743.5 10749.5 10750.0 10758.5 10759.0 10765.5 10768.0 10770.0 10771.0 10772.0 10787.0 10795.0 10795.5 10801.5 10802.0 10804.0 10806.0 10806.5 10808.0 10815.0 10824.0 10826.5 10831.5 10833.0 10839.0 10840.0 10843.5 10845.0 10846.5 10847.0 10855.0 10859.0 10863.0 10864.0 10864.5 10880.0 10884.5 10686.0 10689.0 10697.0 10702.5 10730.5 10794.5 10801.5 10803.5 10806.0 10814.5 10833.0 10884.5 10683.5 10687.5 10705.0 10730.0 10795.0 10801.5 10806.5 10824.0 10832.0 10840.0 10859.0 10691.0 10692.0 10703.5 10704.0 10705.0 10709.0 10710.0 10724.0 10726.5 10729.0 10734.5 10737.5 10739.5 10740.0 10749.0 10750.5 10758.0 10765.5 10770.0 10770.5 10771.0 10801.5 10807.0 10808.0 10809.5 10838.0 10842.0 10845.0 10846.0 10861.5 10862.5 10863.5 10683.0 10685.0 10688.0 10696.5 10705.5 10730.0 10744.0 10759.0 10768.5 10787.5 10795.5 10827.5 10845.0 10855.0 10859.0 10880.5 10885.5 10889.5 10890.0 10893.0 10894.0 10894.5 10897.0 10905.0 10905.5 10906.0 10914.5 10917.0 10918.0 10946.5 10952.0 $ MERGED DATA SOURCE PBU TOOL CODE GR BCS DIL 2435 $ REMARKS: 10904.0 10897.0 10888.5 10889.5 10893.0 10894.0 10906.5 10907.0 10916.5 10917.5 10945.0 10951.0 10886.0 10894.5 10915.0 RUN NO. PASS NO. MERGE TOP 1 4 10150.0 1 4 10150.0 1 4 10150.0 1 4 10150.0 EDITED MAIN PASS. MTEM, TEND, & TENS WERE SHIFTED WITH LL8. ILM & SP WERE SHIFTED WITH ILD. FUCT & NUCT WERE SHIFTED WITH NPHI. MERGE BASE 10920.0 10957.0 10986.0 10927.0 CN WN FN COUN STAT ??MATCH1. OUT ?MATCH2. OUT ??MATCH3. OUT ?MATCH 4. OUT : ARCO ALASKA INC. : D.S. 11-32 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units 1 GR BCS 68 2 DT BC$ 68 3 TEND BCS 68 4 TENS BCS 68 5 LL8 DIL 68 GAPI US/F LB LB OHM}4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 67 465 06 6 4 4 84 653 71 5 4 4 20 789 90 0 4 4 20 789 90 0 4 4 50 746 76 1 6 ILM DIL 68 1 7 ILD DIL 68 1 8 SP DIL 68 1 9 MTEM DIL 68 10 NPHI 2435 68 1 11 FUCT 2435 68 1 12 NUCT 2435 68 i * DATA RECORD (TYPE# 0) Total Data Records: 91 OHMM 4 OHMM 4 MV 4 DEGF 4 PU-S 4 CPS 4 CPS 4 994 BYTES * 48 4 50 746 76 4 50 746 76 4 50 746 76 4 50 746 76 4 98 211 23 4 98 211 23 4 98 211 23 Tape File Start Depth = 11007.000000 Tape File End Depth = 10143.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 22478 datums Tape Subfile: 2 370 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 4 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10143.0 10931.0 AC 10143.0 10968.0 DIFL 10143.0 10997.0 2435 10143.0 10938.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP GR CN PCM KNJT KNJT AC DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT BHC-ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): 25-OCT-94 FSYS REV. J001 VER. 1.1 2330 24-OCT-94 749 25-OCT-94 11003.0 10989.0 10150.0 10986.0 1500.0 TOOL NUMBER 3974XA 3967XA 2806XA 1309XA 2435XA 3506XA 3923NA 3923NA 1609EA/1603MA 1503XA 9.875 3970.0 .0 1% KCL POLYMER 9.70 56.0 9.1 5.6 152.7 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 11-32 : PRUDHOE BAY : NORTH SLOPE : ALASKA .640 .270 .940 .000 1.310 .000 THERMAL SANDSTONE .00 9.875 1.5 60.0 152.7 60.0 .0 60.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 2 AC AC 68 1 US/F 3 CHT AC 68 1 LB 4 TTEN AC 68 1 LB 5 SPD AC 68 1 F/MN 6 RFOC DIFL 68 1 OHMM 7 RILM DIFL 68 1 OHMM 8 RILD DIFL 68 1 OHMM 9 CILD DIFL 68 1 MM/~O 10 VILD DIFL 68 1 MV 11 VILM DIFL 68 1 MV 12 SP DIFL 68 1 MV 13 TEMP DIFL 68 1 DEGF 14 CNC 2435 68 1 PU-S 15 CNCF 2435 68 1 PU-S 16 CN 2435 68 1 PU-L 17 LSN 2435 68 1 CPS 18 SSN 2435 68 1 CPS 4 4 06 969 49 6 4 4 48 852 89 1 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 34 704 23 6 4 4 04 522 10 6 4 4 04 522 10 6 4 4 53 419 67 0 4 4 40 467 34 0 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 72 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 266 Tape File Start Depth = 11007.000000 Tape File End Depth = 10143.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 65684 datums Tape Subfile: 3 346 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 5 .2500 VENDOR TOOL CODE START DEPTH GR 10343.0 AC 10343.0 DIFL 10343.0 2435 10343.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 10931.0 10968.0 10997.0 10938.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP GR CN PCM KNJT KNJT AC DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT BHC-ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 25-OCT-94 FSYS REV. J001 VER. 1.1 2330 24-OCT-94 829 25-OCT-94 11003.0 10989.0 10150.0 10986.0 1500.0 TOOL NUMBER 3974XA 3967XA 2806XA 1309XA 2435XA 3506XA 3923NA 3923NA 1609EA/1603MA 1503XA 9.875 3970.0 .0 1% KCL POLYMER 9.70 56.0 9.1 5.6 152.7 .640 60.0 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 11-32 : PRUDHOE BAY : NORTH SLOPE : ALASKA .270 .940 .000 1.310 .000 THERMAL SANDSTONE .00 9.875 1.5 152.7 60.0 .0 60.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 2 AC AC 68 1 US/F 3 CHT AC 68 1 LB 4 TTEN AC 68 1 LB 5 SPD AC 68 1 F/MN 6 RFOC DIFL 68 1 OHMM 7 RILM DIFL 68 1 OHMM 8 RILD DIFL 68 1 OHMM 9 CILD DIFL 68 1 MMHO 10 VILD DIFL 68 1 MV 11 VILM DIFL 68 1 MV 12 SP DIFL 68 1 MV 13 TEMP DIFL 68 1 DEGF 14 CNC ' 2435 68 1 PU-S 15 CNCF 2435 68 1 PU-S 16 CN 2435 68 1 PU-L 17 LSN 2435 68 1 CPS 18 SSN 2435 68 1 CPS 4 4 06 969 49 6 4 4 48 852 89 1 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 34 704 23 6 4 4 04 522 10 6 4 4 04 522 10 6 4 4 53 419 67 0 4 4 40 467 34 0 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 72 * DATA RECORD (TYPE~ 0) Total Data Records: 205 994 BYTES * Tape File Start Depth = 11007.000000 Tape File End Depth = 10343.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 72962 datums Tape Subfile: 4 283 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 5 is type: LIS THE CURVES RT & DI HAVE BEEN DEPTH SHIFTED. THE SAME SHIFTS WERE APPLIED AS THOSE USED FOR ILD, ILM, & SP CURVES IN THE EDITED MAIN PASS FILE. THIS FILE IS INCLUDED IN THIS FORMAT PER BP EXPLORATION REQUEST. * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 RT DIL 68 1 OHMM 2 DI DIL 68 1 IN * DATA RECORD (TYPE# 0) Total Data Records: 21 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 50 746 76 1 4 50 746 76 1 1014 BYTES * Tape File Start Depth = 11007.000000 Tape File End Depth = 10143.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 70872 datums Tape Subfile: 5 26 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS 94/11/ 4 01 **** REEL TRAILER **** 94/11/ 7 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 7 NOV 94 2:59p Elapsed execution time = 10.22 seconds. SYSTEM RETURN CODE = 0 * ALASKA COMPUTING CENTER * * * ....... SCHLUMiBERGER * ............................ RECEIVED OCT 1 5 1998 ~Ja~ka Oil & Gas Cons. Commission Anchorage COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 1i -32 FIELD NAME : PRUDAFOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292251200 REFERENCE NO : 98497 MICROFILME?) LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: **** REEL HEADER **** SERVICE NAMiE : EDIT DATE · 98/10/ 5 ORIGIN : FLIC REEL NA~E : 98497 CONTINUATION # : PREVIOUS REEL : COI~ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 11-32, API# 50-029-22512-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/10/ 5 ORIGIN : FLIC TAPE NAME : 98497 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 11-32, API# 50-029-22512-00 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS WELL NA~E: D. S. 11-32 API ~ER: 500292251200 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 5-0CT-98 JOB NUMBER: 98497 LOGGING ENGINEER: C.A. Yon OPERATOR WITNESS: Worthington SURFACE LOCATION SECTION: 33 TOWNSHIP: 1 iN RANGE: 15E FNL : 48 FSL: FEL: 125 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 64.50 DERRICK FLOOR: GROUND LEVEL: 29.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 875 7. 625 11003.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MF~SURBD DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUFiBER : PASS NUMBER: DATE LOGGED: 25-0CT-94 LOGGING COMPANY: ATLAS .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH CNTG 88888.0 88888.0 88888.0 10809.5 10809.5 10804.0 10804.0 10804.0 10795.5 10795.5 10795.5 10768.0 10768.0 10768.0 10730.5 10730.5 10730.5 10704.5 10705.5 10696.5 10697.0 10697.0 10687.0 10687.0 10687.0 10670.0 10670.0 10670.0 10666.0 10665.5 10665.0 10665.5 10651.5 10652.5 10652.5 10647.5 10648.0 10648.0 10645.5 10645.5 10645.5 10642.0 10642.5 10642.5 10629.5 10630.0 10630.0 10626.0 10626.5 10626.5 10620.0 10620.5 10620.5 10600.0 10601.0 10601.0 100.0 101.0 101.0 $ REMARKS: CONTAINED HEREIN IS THE CNTG DATA ACQUIRED ON ARCO ALASKA, INC. WELL D.S. 11-32 ON 13-MAY-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CNTG PASS #1 GRCH TO THE BASELINE GAM~A RAY PROVIDED BY THE CLIENT (GR.BCS) ; AND CNTG PASS #1 NPHI TO GR.BCS. ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 98/10/ 5 MAXREC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMF2~T: O. 5000 FILE SUF~W_ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10811.0 10584.0 CNTG 10824.0 10584.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASUR3Ft) DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTG PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB ArdF~ SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUFIB SAMP ELEM CODE (HEX) DEPT FT 1160734 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 1160734 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 1160734 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 1160734 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTG 1160734 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 1160734 O0 000 O0 0 1 1 1 4 68 0000000000 E1VRACNTG 1160734 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT~ CPS 1160734 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 1160734 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 1160734 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 1160734 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 1160734 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 1160734 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 1160734 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 1160734 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTG V 1160734 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1160734 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10920.500 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG N-RAT. CNTG -999.250 CRAT. CNTG -999.250 EiVRA. CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 CCL.CNTG GR.BCS -999.250 DEPT. 10500.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 EArRA. CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 CCL.CNTG GR.BCS 22.776 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: **** FILE HEADER **** FILE NA~E : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUN~ER: 2 DEPTH INCREMENT: 0.5000 FILE SUA~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10811.0 10588.0 CNTG 10824.0 10588.0 $ CURVE SHIFT DATA - PASS TO PASS (MEAS~ DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 10809.0 10804.5 10803.0 10802.5 10795.5 10788.0 10772.5 10768.0 10760.5 10757.5 10754.5 10746.5 10744.0 10741.5 10730.0 10718.0 10708.5 10703.0 10696.5 10689.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. 88888.0 88888.0 10809.0 10804.0 10803.0 10802.5 10795.5 10789.0 10773.0 10768.0 10761.0 10757.5 10755.0 10746.5 10743.5 10741.5 10730.5 10718.0 10709.0 10702.0 10697.0 10689.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: 10687.5 10687.0 10685.5 10685.5 10671.5 10671.5 10669.5 10669.5 10666.5 10665.5 10665.0 10665.5 10663.0 10662.5 10648.0 10648.0 10648.0 10646.0 10645.5 10637.5 10637.5 10626.0 10627.0 10626.5 10619.0 10620.5 10600.5 10601.0 10600.0 10601.0 100.0 100.5 101.0 $ REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #2 GRCH TO PASS #1 GRCH; AND PASS #2 NPHI TO PASS #1 NPHI. ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 i LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1160734 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 1160734 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 1160734 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 1160734 O0 000 O0 0 2 1 1 4 68 0000000000 N-RAT CNTG 1160734 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 1160734 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 1160734 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 1160734 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 1160734 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 1160734 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 1160734 O0 000 O0 0 2 1 1 4 68 0000000000 ClVEC CNTG CPS 1160734 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNTG CPS 1160734 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTG GAPI 1160734 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 1160734 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTG V 1160734 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10824.000 NPHI.CNTG 27.854 ENPH. CNTG 32.215 CPHI.CNTG NRAT. CNTG 3.247 CRAT. CNTG 2.931 ENRA. CNTG 4.885 NCNT. CNTG FCNT. CNTG 689.578 CNTC. CNTG 1975.427 CFTC. CNTG 691.020 CNEC. CNTG CFEC. CNTG 559.110 GRCH. CNTG -999.250 TENS. CNTG 3524.000 CCL.CNTG DEPT. 10588.500 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA. CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 18.588 TENS. CNTG -999.250 CCL.CNTG 27.647 2119.019 2731.522 -0.028 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: **** FILE HEADER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUM~ER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUF~VARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10811.0 10588.0 CNTG 10824.0 10588.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NTrFIBER: 1 BASELINE DEPTH 88888.0 10819.0 10817.0 10814.5 10804.5 10802.0 10800.5 10793.5 10788.5 10781.0 10777.0 10776.5 10770.0 10765.0 10758.0 10754.0 10744.0 10743.5 10730.5 10708.0 10706.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. 88887.5 88889.0 10804.0 10802.0 10788.5 10780.5 10777.0 10769.5 10766.0 10755.0 10743.5 10730.5 10706.5 10820.0 10817.5 10812.5 10804.5 10801.5 10793.5 10776.5 10765.0 10758.0 10743.5 10709.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: 10703.0 10702.0 10697.0 10697.5 10696.5 10697.0 10689.5 10689.5 10687.0 10687.0 10674.5 10675.5 10669.5 10669.5 10666.0 10665.5 10665.0 10665.5 10662.5 10662.5 10654.5 10655.0 10652.5 10653.0 10648.0 10648.0 10648.5 10640.5 10640.5 10637.0 10638.0 10634.0 10634.0 10631.0 10631.5 10628.0 10628.5 10625.5 10626.5 10600.5 10601.5 10599.5 10601.0 100.0 101.5 101.0 $ RE~LARJfS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #3 GRCH TO PASS #1 GRCH; AND PASS #3 NPHI TO PASS #1 NPHI. ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: 10 TYPE REPR CODE VALUE 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~IE SERV UNIT SERVICE API API API API FILE NUFiB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1160734 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 1160734 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1160734 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1160734 O0 000 O0 0 3 1 1 4 68 0000000000 ATRAT CNTG 1160734 O0 000 O0 0 3 1 1 4 68 0000000000 CRATCNTG 1160734 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 1160734 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 1160734 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTG CPS 1160734 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 1160734 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1160734 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 1160734 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 1160734 O0 000 O0 0 3 1 t 4 68 0000000000 GRCH CNTG GAPI 1160734 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 1160734 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTG V 1160734 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10825.000 NPHI.CNTG 27.926 ENPH. CNTG 32.476 CPHI.CNTG NRAT. CNTG 3.036 CRAT. CNTG 2.935 ENRA.CNTG 4.911 NCNT. CNTG FCNT. CNTG 700.791 CNTC. CNTG 1929.800 CFTC. CNTG 710.630 CNEC. CNTG CFEC. CNTG 554.577 GRCH. CATTG -999.250 TENS. CNTG 3479.000 CCL.CNTG DEPT. 10589.000 NPHI.CNTG 9.199 ENPH. CNTG NRAT. CNTG 1.764 CRAT. CNTG 1.686 ENRA.CNTG FCNT. CNTG 1757.478 CNTC. CNTG 3016.400 CFTC. CNTG CFEC. CNTG 1110.018 GRCH. CNTG -999.250 TElVS. CNTG 14.320 CPHI.CNTG 2.838 NCNT. CNTG 1816.569 CNEC. CNTG 3440. 000 CCL. CNTG 25. 505 2052. 463 2723. 773 -0. 027 10.793 3188.912 3150.752 -0.048 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: 11 **** FILE TRAILER **** FILE NA~E : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE · 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFZBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, CNTG REMARKS: THE ARITHFiETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: 12 TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APIAPI API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) O0 000 O0 0 4 1 1 4 68 0000000000 DEPT FT 1160734 NPHI CNAV PU-S 1160734 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1160734 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 1160734 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1160734 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNAV PU-S 1160734 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNAV 1160734 O0 000 O0 0 4 1 1 4 68 0000000000 NCNTCNAV CPS 1160734 O0 000 O0 0 4 1 1 4 68 0000000000 FCNTCNAV CPS 1160734 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1160734 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1160734 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNAV CPS 1160734 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNAV CPS 1160734 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 1160734 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10824.000 NPHI. CNAV 26.796 NRAT. CNAV 3.071 CPHI.CNAV CRAT. CNAV 2.872 ENPH. CNAV 31.480 ENRA. CNAV 4.811 NCNT. CNAV FCNT. CNAV 685.275 CNTC. CNAV 1965.497 CFTC. CNAV 699.387 CNEC. CNAV CFEC. CNAV 573.800 GRCH. CNTG -999.250 26. 940 2059.180 2757. 462 DEPT. 10585.000 NPHI.CNAV -999.250 NRAT. CNAV -999.250 CPHI.CNAV -999.250 CRAT. CNAV -999.250 ENPH. CNAV -999.250 ENRA. CNAV -999.250 NCNT. CNAV -999.250 FCNT. CNAV -999.250 CNTC. CNAV -999.250 CFTC. CNAV -999.250 CNEC. CNAV -999.250 CFEC. CNAV -999.250 GRCH. CNTG 14.489 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: 13 **** FILE TRAILER **** FILE NAM~ : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01COI DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIM~ER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10876.5 10581.0 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIFiE LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL CALIPER GR GAPmLA RAY CNTG COMP. NEUTRON $ BOREHOLE AND CASING DATA 13 -MAY-98 8C0 - 609 1038 13-MAY-98 10855.0 10828.0 10600.0 10828.0 1800.0 NO TOOL NUMBER ........... SGT-L LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: 14 OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE T~PERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 9. 875 11003.0 Crude NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REFLARKS: This log was depth referenced to an ATLAS BHC log, dated 25-0ct-1994 All depth correlation material provided by co. rep. Logging Program: Logged in a Sandstone matrix. Logging interval is (PBTD) 10828'. Logging Procedure: Pass #1 @ 1800 ft/hr when 279 BBL away-250 psi WHP Pass #2 @ 1800 ft/hr when 285 BBL away-300 psi WHP Pass #3 @ 1800 ft/hr when 295 BBL away-300 psi WHP Total Pumped: 313 BBLS of Crude w/10 BBLS Diesel cap. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1160734 O0 000 O0 0 5 i 1 4 68 0000000000 NPHI PSl PU 1160734 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH PS1 PU 1160734 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH PS1 PU 1160734 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PSl 1160734 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1160734 O0 000 O0 0 5 1 1 4 68 0000000000 ENRA PS1 1160734 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC PS1 CPS 1160734 O0 000 O0 0 $ 1 1 4 68 0000000000 CNEC PS1 CPS 1160734 O0 000 O0 0 5 1 1 4 68 0000000000 RCEF PS1 CPS 1160734 O0 000 O0 0 5 1 1 4 68 0000000000 RCENPSl CPS 1160734 O0 000 O0 0 5 1 1 4 68 0000000000 RCNTPS1 CPS 1160734 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1160734 O0 000 O0 0 $ 1 1 4 68 0000000000 CNTC PS1 CPS 1160734 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1160734 O0 000 O0 0 5 1 1 4 68 0000000000 NPOR PS1 PU 1160734 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1160734 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1160734 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PSl V 1160734 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: 16 DEPT. 10876.500 NPHI.PS1 TArRA. PS1 4. 792 RTNR. PS1 CNEC. PS1 2819. 045 RCEF. PS1 RCFT. PS1 376. 809 CNTC. PS1 GR.PS1 44.193 TENS. PSi DEPT. 10581.000 NPHI.PS1 TNRA. PS1 1. 693 RTNR. PS1 CNEC. PS1 3191. 979 RCEF. PS1 RCFT. PSl 1613. 964 CNTC. PS1 GR. PS1 15. 228 TENS. PSl 61.780 ENPH. PS1 5.000 ENRA.PS1 503.221 RCEN. PS1 1819.897 CFTC. PSi 1816.000 CCL. PS1 9.277 ENPH. PS1 1.892 ENRA. PS1 943.530 RCEN. PS1 2918.310 CFTC. PSI 3414.000 CCL. PS1 39.715 TNPH. PS1 5.593 CFEC. PS1 2575.992 RCNT. PS1 387.651 NPOR.PS1 -0.009 16. 594 TNPH. PS1 3.130 CFEC. PS1 2837. 974 RCNT. PS1 1716. 909 NPOR. PS1 -999.250 66.188 504.042 1917.423 66.188 11.307 1019.885 2889.315 12.737 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION : O01CO1 DATE · 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 2 DEPTH INCREMENT: 0.5000 FILE SUF~4ARY VENDOR TOOL CODE START DEPTH CNTG 10842.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: STOP DEPTH 10585.5 13-MAY-98 8C0- 609 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: 17 TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 1038 13-MAY-98 10855.0 10828.0 10600.0 10828.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL CALIPER GR GAM~A RAY CNTG COMP. NEUTRON $ TOOL NUMBER CAL- Y SGT-L CNT-G BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 9. 875 11003.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Crude NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: This log was depth referenced to an ATLAS BHC log, dated 25-0ct-1994 Ail depth correlation material provided by co. rep. Logging Program: Logged in a Sandstone matrix. LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: 18 Logging interval is (PBTD) 10828'. Logging Procedure: Pass #1 @ 1800 ft/hr when 279 BBL away-250 psi WHP Pass #2 ® 1800 ft/hr when 285 BBL away-300 psi WHP Pass #3 @ 1800 ft/hr when 295 BBL away-300 psi WHP Total Pumped: 313 BBLS of Crude w/10 BBLS Diesel cap. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 TN-RA PS2 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 RTAFR PS2 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 ENRA PS2 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS2 CPS 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 RCEF PS2 CPS 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 RCENPS2 CPS 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 RCNT PS2 CPS 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: 19 NA~E SERV UNIT SERVICE API API API API FILE NUFIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) RCFT PS2 CPS 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS2 PU 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1160734 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 10842.000 NPHI.PS2 30.334 ENPH. PS2 36.565 TNPH. PS2 TNRA.PS2 3.067 RTNR.PS2 3.200 ENRA.PS2 5.305 CFEC. PS2 CNEC. PS2 2674.029 RCEF. PS2 503.221 RCEN. PS2 2443.479 RCNT. PS2 RCFT. PS2 630.040 CNTC. PS2 1944.156 CFTC. PS2 648.169 NPOR.PS2 GR.PS2 93.910 TENS.PS2 2322.000 CCL.PS2 -0.028 DEPT. 10585.000 NPHI.PS2 8.054 ENPH. PS2 14.390 TNPH. PS2 TNRA.PS2 1.587 RTNR.PS2 1.676 E1VRA.PS2 2.848 CFEC. PS2 CNEC. PS2 3172.744 RCEF. PS2 1134.345 RCEN. PS2 2991.781 RCNT. PS2 RCFT. PS2 2035.962 CNTC.PS2 3084.022 CFTC. PS2 1987.435 NPOR.PS2 GR.PS2 19.998 TENS.PS2 3418.000 CCL. PS2 -999.250 29.789 504.042 2048.341 29.789 9.382 1114.188 3425.839 8.303 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: 20 FILE HEADER FILE NUM~ER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREM~dVT: 0.5000 FILE VENDOR TOOL CODE START DEPTH CNTG 10851.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL CALIPER GR GAM~A RAY CNTG COMP. NEUTRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLH~ (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH .......... 10585.5 13 -MAY-98 8C0 - 609 1038 13-MAY-98 10855.0 10828.0 10600.0 10828.0 1800.0 NO TOOL NUMBER CAL-Y SGT-L CNT-G 9. 875 11003.0 Crude EPITHERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: 21 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: This log was depth referenced to an ATLAS BHC log, dated 25-0ct-1994 All depth correlation material provided byco. rep. Logging Program: Logged in a Sandstone matrix. Logging interval is (PBTD) 10828'. Logging Procedure: Pass #1 @ 1800 ft/hr when 279 BBL away-250 psi WHP Pass #2 @ 1800 ft/hr when 285 BBL away-300 psi WHP Pass #3 @ 1800 ft/hr when 295 BBL away-300 psi WHP Total Pumped: 313 BBLS of Crude w/lO BBLS Diesel cap. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: 22 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APIAPI API API FILE NUF~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 7 1 1 4 68 0000000000 DEPT FT 1160734 NPHI PS3 PU 1160734 O0 000 O0 0 7 1 1 4 68 0000000000 ElVPH PS3 PU 1160734 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PS3 PU 1160734 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1160734 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 1160734 O0 000 O0 0 7 1 1 4 68 0000000000 ENRA PS3 1160734 O0 000 O0 0 7 1 1 4 68 0000000000 CFEC PS3 CPS 1160734 O0 000 O0 0 7 1 1 4 68 0000000000 CNEC PS3 CPS 1160734 O0 000 O0 0 7 1 1 4 68 0000000000 RCEF PS3 CPS 1160734 O0 000 O0 0 7 1 1 4 68 0000000000 RCENPS3 CPS 1160734 O0 000 O0 0 7 1 1 4 68 0000000000 RCNTPS3 CPS 1160734 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1160734 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1160734 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1160734 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PS3 PU 1160734 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1160734 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1160734 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1160734 O0 000 O0 0 7 1 1 4 68 0000000000 * * DA TA * * DEPT. 10851.000 NPHI.PS3 30.334 ENPH. PS3 64.428 TNPH. PS3 TNRA.PS3 3.067 RTNR.PS3 3.200 ENRA.PS3 7.469 CFEC. PS3 CNEC. PS3 2819.045 RCEF. PS3 376.809 RCEN. PS3 2575.992 RCNT. PS3 RCFT. PS3 630.040 CNTC. PS3 1944.156 CFTC. PS3 648.169 NPOR.PS3 GR.PS3 49.717 TENS. PS3 2103.000 CCL.PS3 -0.028 29.789 377.423 2048.341 29.789 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .007 SERVICE · FLIC VERSION . O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 14:37 PAGE: 23 **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE : 98/10/ 5 ORIGIN : FLIC TAPE NA~E : 98497 CONTINUATION # : 1 PREVIOUS TAPE : CO~ : ARCO ALASKA INC., PRUDHOE BAY, D.S. 11-32, API# 50-029-22512-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/10/ 5 ORIGIN : FLIC REEL NAM~ : 98497 CONTINUATION # : PREVIOUS REEL : CO~_2VT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 11-32, API# 50-029-22512-00 BP Exploration Alaska Inc Well: 11-32 Field: PRUDHOE BAY UNIT North Slope, Alaska, USA Report Production Array Log Analysis Prepared For : BP Exploration Alaska Inc Logging Date : 18th August, 2014 Report Date : 29th August, 2014 Submitted by: Waqar Khan Phone: +1(281)575-5051 10200 Bellaire Blvd, Houston, Texas-77072 Email: waqar.khan2@halliburton.com HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA, CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OF WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM. ANY USER OF SUCH DATA, INTERPRETATIONS, CONVERSIONS OF RECOMMENDATIONS AGREES THAT HALLIBURTON IS NOT RESPONSIBLE EXCEPT WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT, FOR ANY LOSS, DAMAGES, OR EXPENSES RESULTING FROM THE USE THEREOF BP Exploration Alaska Production Array Log Analysis 1 TABLE OF CONTENTS 1.0 EXECUTIVE SUMMARY ............................................................................................................................. 2 2.0 BACKGROUND AND OBJECTIVES .......................................................................................................... 3 3.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT ............................................................ 4 4.0 PRODUCTION LOG PROCESSING ........................................................................................................... 7 4.1 FLOWING SURVEY ...................................................................................................................................... 9 4.2 SHUT-IN SURVEY ...................................................................................................................................... 23 BP Exploration Alaska Production Array Log Analysis 2 1.0 EXECUTIVE SUMMARY Production logging was done in Well 11-32 on August 18th, 2014 in flowing conditions with the objective of identifying a potential WSO opportunity. In order to accurately quantify the flow of water, an array production logging suite was run. The flowing PL analysis showed the oil production to be coming from 1st and 3rd set of perforations (10651’ – 10667’ & 10732’ – 10740’), with the 1st perforation accounting for 90% of the oil production. The bottom two sets of perforations (10732’ – 10740’ & 10758’ – 10767’) accounted for 9% of the total water production and can be candidates for water shut off treatment to reduce the water flow rate by roughly 1000 STB/D. During the shut in passes, a cross flow was observed between 3 rd set of perforations (10732’ – 10740’) and (10651 – 10667’). Though the rates were quite low and weren’t enough to overcome threshold of the spinners, the cross flow was evident on the temperature profile. Based on the well test data during logging, the well is in a stable condition. Station measurements are consistent and overlay with passes. There are minor indications of crossflow below spinner resolution from the bottom to top perforatioin. The analysis presents a potential WSO opportunity in the bottom perforation zone. The estimated flow rates at surface condition while flowing from each of the perforations is given in the table below: Perforations Water Rate Oil Rate Gas Rate From, ft To, ft STB/D % STB/D % Mscf/D % 10651.5 10667.5 0 0.00 173 90.10 0 0.00 10705.5 10727 10918 91.08 0 0.00 5054 100.00 10732 10739.5 845 7.05 19 9.90 0 0.00 10758 10766.5 224 1.87 0 0.00 0 0.00 11987 192 5054 BP Exploration Alaska Production Array Log Analysis 3 2.0 BACKGROUND AND OBJECTIVES The objective for running the PL was to identity an opportunity for water shut off treatment. BP Exploration Alaska Production Array Log Analysis 4 3.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT Well 11-32 is completed with 75/8” production casing across which the production log was run. The wellbore schematic is presented in the Figure 1. The tool string diagram used for the PL logged is presented in Figure 2. The tool string consisted of the following production logging sensors: Gamma Ray - Casing Collar Locator – Pressure - Resistance Array Tool – Gas holdup – Caliper – Radioactive Density –Capacitance Water Holdup – Inline Spinner – Temperature – Caged Fullbore Spinner. The data quality is summarized below TOOL USAGE LOG DESCRIPTION LOG QUALITY REMARKS WELL BORE PARAMETERS QP Well bore pressure Good TEMP Well bore temperature Good FLUID TYPE FDR Radioactive density tool uses radioactive source and detector to measure density and is a center sample device Good Used quantitatively. CWH Uses capacitance to measure the differences between hydrocarbons and water Good Used qualitatively in the interpretation. Surface calibration applied RAT Resistivity Array Tool Good Used quantitatively. GHT Gas HoldUp Tool Good Used qualitatively in the interpretation. Surface Calibration Applied. Likely off depth with passes due to tool offset of GHT versus density. FLUID VELOCITY CFB Caged Fullbore Spinner Good ILS Inline Spinner Good SAT Spinner Array Tool Good . BP Exploration Alaska Production Array Log Analysis 5 Figure 1: Wellbore Schematic BP Exploration Alaska Production Array Log Analysis 6 Figure 2: PL Toolstring BP Exploration Alaska Production Array Log Analysis 7 4.0 PRODUCTION LOG PROCESSING The production log data from the flowing were processed using the PLATO software. The software uses a global probabilistic method for the production log analysis. In this method, known as the Maximum Likelihood method, a well flow model is compared to all available data and improved, by optimization, until the best possible match with the data is obtained. By using this method the result is the most likely interpretation. A comparison between the model and the data is shown in this report and allows the analyst or the reader to determine validity of the answer obtained. Potential sources of discrepancies include tool measurement errors, conflicts between the parameters or conditions that make the underlying empirical models (such as flow regimes) less applicable. The flow regimes were determined, directly from the flow rates and holdups, according to the Taitel- Dukler analytic model. The profile factors, to calculate the true fluid velocity from the apparent velocity, were based on the Reynolds numbers. Solution gas in oil was derived from the correlations (Vasquez-Beggs or Øistein- Glaso). The analysis was performed in six steps: The data preparation to filter the data, compute gradients and error estimates. The calibration of the array tools and full-bore flow meter. The computation of the layered holdup and layered flow-rates. The profile determination to identify the potential producing and/or injecting zones. The computation of the flow rates by global optimization. The computation of surface productions and reporting. BP Exploration Alaska Production Array Log Analysis 8 The water density and viscosity were calculated using a salinity of 20000 ppm. The Craft & Hawkins correlation was used. The oil density and viscosity were calculated using an oil gravity of 25.7 API. The Vasquez & Beggs correlation was used to calculate the solution gas. Viscosity was calculated using the Beggs & Robinson correlation. The Pc and Tc parameters were calculated using the Brown et al. correlation. The gas viscosity was calculated using the Lee Gonzales Eakin correlation. The following gas parameters were used: GasType Miscellaneous SPGG UNITY .700 GP-CO2 UNITY 0 GP-H2S UNITY 0 GP-Nitrogen UNITY 0 Utilizing the above fluid information, measured down hole oil density, temperature & pressure, the following fluid properties were calculated at well conditions: feet Twf Pwf Bwater water water Boil oil oil Rsb Bgas gas gas °F psi UNITY g/cc cP UNITY g/cc cP ft3/bbl UNITY g/cc cP 10353.00 166 2816 1.02 1.01 .427 1.04 .839 4.29 398 .00577 .127 .0181 10399.00 166 2828 1.02 1.01 .426 1.04 .839 4.28 400 .00575 .128 .0182 10445.00 166 2841 1.02 1.01 .426 1.04 .839 4.28 402 .00572 .128 .0182 10491.00 166 2853 1.02 1.01 .426 1.04 .839 4.28 404 .00570 .129 .0182 10537.00 167 2866 1.02 1.01 .426 1.04 .839 4.28 406 .00568 .129 .0183 10583.00 167 2878 1.02 1.01 .426 1.04 .839 4.28 408 .00566 .130 .0183 10629.00 167 2891 1.02 1.01 .426 1.04 .839 4.28 410 .00563 .130 .0183 10675.00 167 2902 1.02 1.01 .426 1.04 .839 4.28 411 .00561 .131 .0183 10721.00 167 2913 1.02 1.01 .425 1.04 .839 4.27 413 .00560 .131 .0184 10767.00 174 2919 1.02 1.01 .405 1.05 .836 4.07 408 .00569 .129 .0184 To estimate the flow rates, the caliper log recorded during the UP passes was used to estimate the nominal ID throughout the log. Tool information The following capacitance tool characteristics were used HydroWater Hz 26671 (Surface Calibration) HydroHyd Hz 32865 (Surface Calibration) The following gas holdup tool characteristics were used GasHoldupWater Hz 38427 (Surface Calibration) GasHoldupGas Hz 16455 (Surface Calibration) BP Exploration Alaska Production Array Log Analysis 9 4.1 FLOWING SURVEY The raw data from the flowing survey are presented in the Figures 3 to 8. Figure 3 has the data from conventional production logging sensors. Figure 4 has the same data that was presented in Figure 3 with the addition of the station measurements. To generate this plot, Emeraude software was used which allows overlay of the station measurements and the logging passes in the same track. Plato can only plot the station measurement against time. For the interpretation, all the passes have been used. The response from the Resistance Array Tool is presented in Figure 5. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values. Only the active sensors were used in the interpretation. Figure 6 shows only the active RAT sensors along with the station measurements. The response from the Spinner Array Tool is presented in Figure 7. Both the fullbore and the inline spinner are showing a good response. Figure 8 shows the station measurements. An advantage of running the array spinners along with the center based velocity spinners is seen in Figure 8. Across the bottom perforation, center based spinners do not pick up any production in the station measurements but the array spinners are showing flow coming from the bottom perforation. From the raw data it is clear that most of the production is coming from the 2nd perforation from the top. From the spinner response, the velocity profile was estimated using the slopes calculated from the spinner calibration (Figures 10 and 11). Velocity is highest across the 2nd perforation from the top, indicating this zone as the main contributor. The calibrated RAT response is presented in Figure 12.. The estimated SAT velocities and the RAT holdups are used to calculate the flow profile presented in the Figure 13. The final flow profile, after the global optimization, along with the comparison of the measured and theoretical tool values are presented in Figure 14. The production rates at surface conditions estimated from the production log analysis are presented in Figure 15 and are summarized in the table below: feet Profile Q-Water- STP Qp-Water- STP Q-Oil- STP Qp-Oil- STP Q-Gas- STP Qp-Gas- STP BFPD BFPD BFPD BFPD MCFD MCFD 10651.50 10667.50 Produce 11987 0 192 173 5054 0 10705.50 10727.00 Produce 11987 10918 19.0 0 5054 5054 10732.00 10739.50 Produce 1069 845 19.0 19.0 0 0 10758.00 10766.50 Produce 224 224 0 0 0 0 BP Exploration Alaska Production Array Log Analysis 10 Raw Data - The figure below summarizes the input data recorded at the well site. - Each pass is shown with a fixed predefined color. Figure 3: Input data from the conventional production logging sensors BP Exploration Alaska Production Array Log Analysis 11 Figure 4: Input data from the conventional production logging sensors along with the station measurements. BP Exploration Alaska Production Array Log Analysis 12 The figure below shows the RAT input data. The first track shows the RAT rotation curves for each pass. The next tracks show the RAT data: A curve for each pass for each of the 12 probes. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values and were not used in the interpretation. Figure 5: Input data from the Resistance Array Tool (RAT) BP Exploration Alaska Production Array Log Analysis 13 Figure 6: Input data from the Resistance Array Tool (RAT) showing just the active sensors along with station measurements BP Exploration Alaska Production Array Log Analysis 14 The figure below shows the SAT input data. The first track shows the SAT rotation curves for each pass. The next track shows the linespeed for each pass. The remaining tracks show the array spinner data: A curve for each pass for each of the 6 array spinners and for the fullbore spinner (ASpinner07). Figure 7: Input data from the Spinner Array Tool (SAT) and conventional spinners. BP Exploration Alaska Production Array Log Analysis 15 Figure 8: Input data from the Spinner Array Tool (SAT) and conventional spinners along with the station measurements. BP Exploration Alaska Production Array Log Analysis 16 Pre- Processing Figure 9: All the passes have been used in the interpretation BP Exploration Alaska Production Array Log Analysis 17 Calibration of Spinner Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and measured Array Tool responses. Track 2: Line-speed for each pass. Track 3: 'Unwrapped' rotation curve for each pass. Track 4: Normalized layered velocity profile. This profile is optimized by comparing the measured and theoretical SAT response for each pass of each spinner. Tracks 5-10: Measured and theoretical SAT responses for each spinner. Track 11: Measured and theoretical responses for the full-bore spinner. Track 12: Measured and theoretical responses for the inline spinner. Below are the results from the calibration of the SAT data. The determination of this calibration is a layered velocity profile. Figure 10: Velocity profile from SAT data BP Exploration Alaska Production Array Log Analysis 18 The image below displays cross plots for the Inline spinner. The estimated slopes are used for converting the spinner response to flow velocities. Figure 11: Spinner cross plot BP Exploration Alaska Production Array Log Analysis 19 Calibration of Resistance Array Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and the measured RAT responses. Track 2: 'Unwrapped' rotation curve for each pass. Track 3: Normalized layered RAT profile. This profile is optimized by comparing the measured and theoretical RAT response for each pass for each probe. Tracks 4-9: Measured and theoretical RAT responses for each probe. Below are the results from the calibration of the RAT data. The determination of this calibration is a layered resistivity profile. To obtain this profile, calibrations for water/ hydrocarbon were entered for each probe. Figure 12: Calibrated RAT response. BP Exploration Alaska Production Array Log Analysis 20 Holdup and Velocity Profile: Shown on the image below from left to right: Track 3: Layered velocity profile. Track 4: Layered water holdup profile. Track 5: Layered oil holdup profile. Track 6: Layered gas holdup profile Track 7: Total holdup. Track 8: Cumulative flow rates Track 9: Density of fluid Track 10: Apparent Velocity from Fullbore Spinner Track 11: Apparent Velocity from Inline Spinner Figure 13: Holdup and velocity profile BP Exploration Alaska Production Array Log Analysis 21 Flow Profile The quantitative production rates were determined by comparing the well flow model with all available data. The figure below is provided to verify the agreement of the flow model with the data. In this figure the data is represented by the blue curves, while the calculated tool values are shown in red. The uncertainty interval is represented as a gray band around the data. The uncertainty interval corresponds to one standard deviation. The small fluctuations around the data are to be expected, since the tools have intrinsic errors. Large sustained discrepancies indicate problems with the data, conflicts between parameters or conditions that make the underlying empirical models less applicable. To the right of the figure the flow regimes are shown. Within the transition zones several regimes can exists intermittently. Figure 14: Flow profile at reservoir conditions BP Exploration Alaska Production Array Log Analysis 22 The production rates at surface conditions are presented in the figure below: Figure 15: Flow profile at surface conditions BP Exploration Alaska Production Array Log Analysis 23 4.2 SHUT-IN SURVEY The raw data from the flowing survey are presented in the Figures 16-21. For the interpretation, all the passes except for the DOWN 60 have been used, owing to the spike in DOWN 60. Spinner 5 on the array tool did not behave properly, and has been ignored in the interpretation. Figure 21 shows the spinner data with stationary measurements. Based on the stationary measurements, either there is no cross flow, or cross flow is too small to be overcome the threshold of the spinners. Figure 24 shows the temperature profile during the shut-in pass. Track 1 shows the temperature profile for all the shut in passes, whereas track 2 has the temperature profile for all the down passes during shut in along with the 1st down pass during flowing conditions. Across the bottom perforation, temperature appears to be decreasing from the flowing temperature, indicating no fluid coming from the bottom, and, wellbore approaching geothermal gradient, but across the 2nd perforation from the bottom, the trend is reversed and a heating effect is seen, indicating the influx of fluid cause heating of the wellbore. Another deflection is observed across the top perforation, highlighting cross flow between the 2nd perforation from the bottom and the top perforation. BP Exploration Alaska Production Array Log Analysis 24 Raw Data - The figure below summarizes the input data recorded at the well site. - Each pass is shown with a fixed predefined color. Figure 16: Input data from the conventional production logging sensors BP Exploration Alaska Production Array Log Analysis 25 Figure 17: Input data from the conventional production logging sensors along with the station measurements. BP Exploration Alaska Production Array Log Analysis 26 The figure below shows the RAT input data. The first track shows the RAT rotation curves for each pass. The next tracks show the RAT data: A curve for each pass for each of the 12 probes. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values and were not used in the interpretation. Figure 18: Input data from the Resistance Array Tool (RAT) BP Exploration Alaska Production Array Log Analysis 27 Figure 19: Input data from the Resistance Array Tool (RAT) showing just the active sensors along with station measurements BP Exploration Alaska Production Array Log Analysis 28 The figure below shows the SAT input data. The first track shows the SAT rotation curves for each pass. The next track shows the linespeed for each pass. The remaining tracks show the array spinner data: A curve for each pass for each of the 6 array spinners and for the fullbore spinner (ASpinner07). Figure 20: Input data from the Spinner Array Tool (SAT) and conventional spinners. BP Exploration Alaska Production Array Log Analysis 29 Figure 21: Input data from the Spinner Array Tool (SAT) and conventional spinners along with the station measurements. BP Exploration Alaska Production Array Log Analysis 30 Pre- Processing Figure 22: Passes showing a consistent response have been used in for averaging out the measurements. BP Exploration Alaska Production Array Log Analysis 31 Calibration of Spinner Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and measured Array Tool responses. Track 2: Line-speed for each pass. Track 3: 'Unwrapped' rotation curve for each pass. Track 4: Normalized layered velocity profile. This profile is optimized by comparing the measured and theoretical SAT response for each pass of each spinner. Tracks 5-10: Measured and theoretical SAT responses for each spinner. Track 11: Measured and theoretical responses for the full-bore spinner. Track 12: Measured and theoretical responses for the inline spinner. Below are the results from the calibration of the SAT data. The determination of this calibration is a layered velocity profile. Figure 23: Velocity profile from SAT data. BP Exploration Alaska Production Array Log Analysis 32 Figure 24: Temperature profile indicating cross flow happening between 2nd perforation from bottom and top perforation. Temperature profile from 1st down pass during flowing conditions Heating effect is seen, reversal in trend Deflection in temperature BP Exploration Alaska Production Array Log Analysis 33 The image below displays cross plots for the Inline spinner. The estimated slopes are used for converting the spinner response to flow velocities. Figure 25: Spinner cross plot BP Exploration Alaska Production Array Log Analysis 34 Calibration of Resistance Array Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and the measured RAT responses. Track 2: 'Unwrapped' rotation curve for each pass. Track 3: Normalized layered RAT profile. This profile is optimized by comparing the measured and theoretical RAT response for each pass for each probe. Tracks 4-9: Measured and theoretical RAT responses for each probe. Below are the results from the calibration of the RAT data. The determination of this calibration is a layered resistivity profile. To obtain this profile, calibrations for water/ hydrocarbon were entered for each probe. Figure 26: Calibrated RAT response BP Exploration Alaska Production Array Log Analysis 35 Holdup and Velocity Profile: Shown on the image below from left to right: Track 3: Layered velocity profile. Track 4: Layered water holdup profile. Track 5: Layered oil holdup profile. Track 6: Layered gas holdup profile Track 7: Total holdup. Track 8: Cumulative flow rates Track 9: Density of fluid Track 10: Apparent Velocity from Fullbore Spinner Track 11: Apparent Velocity from Inline Spinner Figure 27: Holdup and velocity profile BP Exploration Alaska Production Array Log Analysis 36 Shut-In Profile The quantitative production rates were determined by comparing the well flow model with all available data. The figure below is provided to verify the agreement of the flow model with the data. In this figure the data is represented by the blue curves, while the calculated tool values are shown in red. The uncertainty interval is represented as a gray band around the data. The uncertainty interval corresponds to one standard deviation. The small fluctuations around the data are to be expected, since the tools have intrinsic errors. Large sustained discrepancies indicate problems with the data, conflicts between parameters or conditions that make the underlying empirical models less applicable. To the right of the figure the flow regimes are shown. Within the transition zones several regimes can exists intermittently. Figure 28: Flow profile at reservoir conditions BP Exploration Alaska Production Array Log Analysis 37 The production rates at surface conditions are presented in the figure below: Figure 29: Flow profile at surface conditions
