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184-195
STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMI ` WELL MPLETION OR RECOMPLETION REPO AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned )3 • Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 GINJ E] WINJ III WAG III WDSPL 111 No.of Completions: Development p Exploratory Cl Service El Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry _ BP Exploration(Alaska),Inc 6/1/2016 184-195• 316-177 3. Address: 7. Date Spudded: 15. API Number: P.O.Box 196612 Anchorage,AK 99519-6612 11/16/1984 50-029-21212-00-00 ' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 12/6/1984 PBU 11-12 • Surface: 136'FNL,107'FEL,Sec.33,T11 N,R15E,UM " 9 KB Ref Elevations 17. Field/Pool(s): 58 Top of Productive Interval: 1960'FNL,2310'FEL,Sec.04,T1ON,R15E,UM GL 28 ' BF 28.74 PRUDHOE BAY,PRUDHOE OIL ' Total Depth: 2710'FNL,2496'FEL,Sec.04,T1ON,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: ' 12075'/8576' - ADL 028325&028328 - 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 707450 • y- 5951586 • Zone - ASP 4 •13032'/9169' • 70-054 TPI: x- 705459 y- 5944426 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 705295 y- 5943671 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 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 DIL/BHCS/GR/SP,GR/CCL,Gyro,CBL OCT` V 12016 suiego 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEAMOUNT FT. CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 30' 110' 30' 110' 30" 1950#Poleset 13-3/8" 72# L-80 29' 2530' 29' 2504' 17-1/2" 2520 sx PF E,400 sx PF C 9-5/8" 47# L-80 27' 9319' 27' 6785' 12-1/4" 500 sx Class'G',300 sx PF C,605 sx Class'G' 7" 29# L-80 9029' 13032' 6627" 9169' 8-1/2" 450 sx Class'G',200 sx Class'G' 24. Open to production or injection? Yes El No RI 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 5-1/2"17#13Cr80 9140' 9063'/6645' x 4-1/2"12.6#13Cr80 r/� 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. E l _ COMPLETION RECEIVED V E D Was hydraulic fracturing used during completion? Yes III No . DATE V irk Per 20 AAC 25.283(i)(2)attach electronic and printed information (,<<I110 JUN 17 2016 VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED L�` ,r.�^ ^ 12140' Set Posiset Plug V(t.•:l (�J- 12128' 17.2 Gal Cement 12075' 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 w�M Flow Tubing Casing Press: Calculated Oil-Bbl: • Gas-MCF: Water-Bbl: Oil Gravity-API(corn): Press 24 Hour Rate -► Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only ICT ,v VT - 8/3I ;' / L RBDMS (,u JUN 2 0 2016 ,,,, -_yz , 28. CORE DATA • Conventional Core(s) Yes 0 No E1 Sidewall Cores Yes ❑ No Q 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 ❑ No II Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 12043' 8554' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sadlerochit 12043' 8554' Base of Sadlerochit 12932' 9113' Formation at total depth: 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Wellbore Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Browning,Zachary H. Email: Zachary.Browning@bp.com Printed Name: Joe LaskTitle: Drilling Technologist Signature: Phone: +1 907 564 4091 Date: INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 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 • • 11-12 Well History (Pre-Rig Sidetrack) ***WELL SI ON ARRIVAL. DISCUSS WELL STATUS WITH PAD OP***(ELINE - MPBT, CEMENT) INITIAL T/IA/OA= 2350/235/100 PSI STANDBY FOR LRS L&K. RIH WITH 2.125" POSISET PLUG. SET PLUG ME AT 12,140'; CCL TO PLUG ME = 23.5'; CCL STOP DEPTH = 12,116.5'. TOP OF POSISET PLUG AT 12139'. LOG CORRELATED TO SLB PPROF LOG DATED 06-DEC-10. SURFACE 3/25/2016 CONFIRMATION OF PLUG SETTING. T/I/0=2430/185/120 Temp= S/I Assist E-Line (Pre CTD) Pumped 5 bbls meth followed by 577 bbls of 120*f 1% KCL down TBG to load well. Pumped 1 bbl meth followed by 58 bbls ambient diesel down TBG to FP. Hung FP tag on WV. E-line in control of well upon LRS departure. IA/OA=OTG 3/25/2016 FWHP's= 500/310/110 CEMENT RUN 1: RIH W/4.3 GAL CEMENT BAILER, TAG PLUG @ 12139.6', DUMP ON TOP OF POSISET, TOC = 12136.8' CEMENT RUN 2: RIH W/4.3 GAL CEMENT BAILER, DUMP ON TOP OF CEMENT, TOC @12134' CEMENT RUN 3: RIH W/4.3 GAL CEMENT BAILER, DUMP ON TOP OF CEMENT, TOC @12131.4' CEMENT RUN 4: RIH W/4.3 GAL CEMENT BAILER, DUMP ON TOP OF CEMENT, FINAL TOC @ 12128.4' (TOTAL CEMENT = 17.2 GAL) ALL CEMENT RUNS CORRELATED TO SLB PRODUCTION PROFILE W/ DEFT LOG DATED 6-DEC-2010. WELL SHUT IN ON DEPARTURE. RDMO 3/26/2016 FINAL T/I/O = 700/250/150 T/I/0=675/170/115 SI Perform MIT T (CTD) MIT T to 2800 psi ***PASSED*** Pumped 46.6 bbls DSL down TBG to achieve test pressure of 2800 psi. 15 min loss of 90 psi, 30 min loss of 4 psi, for total loss of 94 psi in 30 mins. Bleed TBG to 300 psi Tags hung on WV DSO/WSL notified Valve positions=SV WV SSV closed MV open CVs OTG 3/29/2016 FWHP=800/160/100 T/I/O = 230/20/50. Temp = SI. Bleed WHPs to 0 psi (pre CTD). Tbg & IA FLs near surface. OA cemented to surface. Integral installed on IA inspection =current. Bled IAP to slop trailer from 20 psi to 0 psi in —2 min (gas). Bleed OAP to slop trailer from 50 psi to 0 psi in 1 min (small amount of fluid). Bled Tbg to slop trailer from 230 psi to 85 psi before midnight(gas/fluid). **WSR continued on 04-01-2016. 3/31/2016 T/I/O =910/170/110. Temp = SI. Bleed WHPs to 0 psi (pre CTD). Tbg & IA FLs near surface. OA cemented to surface. Integral installed on IA inspection =current. Bled IAP to slop trailer from 170 psi to 0 psi in 1 hrs (1 bbl). Bleed OAP to slop trailer from 110 psi to 0 psi in 1 min (1 quart). Bled Tbg to slop trailer from 910 psi to 200 psi in 1.75 hrs (gas/fluid, lbbl). Final WHPs = 200/16/40. 3/31/2016 SV, WV, SSV= C. MV= 0. IA, OA = OTG. 17:00 T/I/O = SSV/30/20. Temp = SI. WHPs (post bleed). AL disconnected. Integral installed on IA. IAP increased 25 psi, OAP increased 20 psi in 13 hours. 4/1/2016 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 15:20 **WSR continued from 03-31-2016. T/I/O = 85/13/0+. Temp = SI. BLeed WHP's to 0 psi (pre CTD). Tbg & IA FL near surface. OA cemented to surface. Continue bleeding TP. Bled TP to 0 psi in 5.25 hrs (gas/fluid, 0.5 Bbls), held open for 30 min. TP increased 15 psi during monitor. Final WHP's = 15/5/0+. SV, WV, SSV = C. MV = 0. IA, OA= OTG. 03:45 4/1/2016 S • 11-12 Well History (Pre-Rig Sidetrack) T/I/O =40/40/40. Temp =SI. Bleed WHP's to 0 psi (Pre CTD). AL spool dropped. TBG & IA FL's near surface. OA cemented to surface. Bled TP to slop tank from 40 psi to 0 psi in 1 hr, held open bleed for 2 hrs (gas). Bled IAP to slop tank from 40 psi to 0 psi in 30 min, held open bleed 2 hrs (gas). Bled OAP to slop tank in 1 min (fluid). Monitor 30 min. TP increased 1 psi, IAP increased 3 psi, OAP unchanged. Final WHP's = 1/3/0. 4/2/2016 SV, WV, SSV=C. MV = O. IA, OA= OTG. 15:00. T/I/O = 10/130/40. Temp = SI. WHP's (pre CTD). AL spool dropped. Tbg & IA FL = near surface. OA cemented to surface. TP increased 9 psi, IAP increased 127 psi, & OAP increased 40 psi since bleed on 4-02-16. 4/18/2016 SV, WV, SSV= C. MV = O. IA, OA = OTG. 01:30 T/I/O=25/200/0 Installed TS#07 Performed LTTon M/V, SSV, S/V FWP 25/200/0 See 5/15/2016 log for details. T/I/O = ??/170/0. Temp =SI. Bleed WHPs < 50 psi (pre RIG). Unable to get TP, no wellhead scaffolding. No AL. No flowline, no wellhouse. IA FL near surface. Bled IAP to bleed trailer from 170 psi to 35 psi in 1 hour(all gas). Monitored for 30 min, IAP increased 5 psi. FWHPs = ??/40/0. 5/19/2016 SV, WV, SSV= C. MV = O. IA, OA= OTG. 10:00 T/I/O = ??/70/0. Temp = SI. WHPs (post bleed). Unable to get TP, no wellhead scaffolding. No AL. No flowline. No well house. IA FL near surface. IAP increased 30 psi since bleed on 5/19/16. 5/20/2016 SV, WV, SSV = C. MV= O. IA, OA =OTG. 08:30 T/I/O = ??/100/50. Temp = SI. Bleed WHP's (pre CTD). Unable to get TP, no wellhead scaffolding. No AL. No Flowline or well house. IA FL near surface & OA cemented to 5/21/2016 surface. Bled IAP & OAP to 0 psi (gas) and held open. T/I/O = ??/30/10. Temp = SI. WHP's (pre CTD). No well house, scaffolding, or flowline. IAP increased 30 psi &OAP increased 10 psi in 19 hours. 5/22/2016 SV, WV, SSV = C. MV= O. IA, OA =OTG. 23:55 T/I/O = ??/0/0. Temp = SI. Bleed WHP's (pre CTD). Unable to get TP, no wellhead scaffolding. No AL. No Flowline or well house. IA FL near surface&OA cemented to surface. Bled IAP & OAP to 0 psi (gas)and held open for 5 hours. Monitored for 30 min. IAP &OAP unchanged. Final WHP's = ??/0/0. 5/22/2016 SV, WV, SSV= C. MV =O. IA, OA=OTG. 05:10 T/I/O = SSV/60/15. Temp = SI. WHPs (Pre CTD). No wellhouse, flowline, AL. Unable to access TP do to pad prep work. IAP increased 30 psi, OAP increased 5 psi since 5-22- 5/24/2016 16. T/I/O = SSV/90/15. Temp = SI. WHPs (pre CTD). Wellhouse, scaffold, flowline, and AL disconnected. Need rig scaffold to verify TP. IAP increased 30 psi, OAP unchanged from 5/24/16. 5/27/2016 SSV = C. MV= O. IA, OA = OTG. 00:00 T/I/O = Demobed/100/15. Temp =SI. Bleed WHP's (Pre rig). IA FL near surface. Bled IAP to BT from 100 psi to 0 psi in 30 min (gas).. Bled OAP from 15 psi to 0 psi in <1 min (gas). Monitored for 30 min. IAP increased 2 psi. Final WHPs = Demobed/2/0. 5/28/2016 SV, WV, MV= ?. SSV = C. IA, OA = OTG. 0930. • North Amprlca ALAS >y Page 1 PI' Operation Summary Report �' �� Common Well Name.11-12 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:5/29/2016 End Date:6/5/2016 X3-017RQ-C:(2,084,716 00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:11/16/1984 12:00:00AM I Rig Release:6/7/2016 Rig Contractor.NORDIC CALISTA I UW:500292121200 Active datum:Kelly Bushing/Rotary Table©58.00usft(above Mean Sea Level) Date ! From-To Hrs Task Code ( NPT NPT Depth Phase 1 Description of Operations (hr) (usft) I 5/29/2016 106:00 - 07:00 1.00 MOB P PRE ,TOOL PUSHER AND DRILLER PERFORM ;ROUTE DRIVE WHILE SUPERINTENDENT -- 1 POSTION RIG TO MOVE OFF TARMAC PAD 07:00 - 07:30 0.50 MOB P PRE I HOLD A PJSM TO MOVE TO DS11 107:30 - 10:00 2.50 MOB P PRE MOVE RIG 10:00 - 10:40 0.67 MOB P PRE I RIG ON DS11 LAY 3X12'S TO HELP RIG UP ON RIG MATS IAP IS>50 PSI,-90 PSI ON THE GAUGE, NOTIFY SUPERINTENDENT SARBER [WE HAVE PERMISSION TO MOVE OVER WELL 10:40 - 11:00 0.33 MOB P PRE HOLD A PJSM TO SPOT RIG OVER WELL I-USE A 12"X12"BLOCK TO PREVENT RIG FROM ROLLING TOWARDS WELL !-SUPERINTENDENT WILL MAN ESD WHILE !THE RIG IS BEING SPOTTED PERSONNEL ASSIGNMENTS FOR SPOTTERS -RADIOAND VISUAL COMMUNICATION WILL BE USED TO SPOT THE RIG USE OF THE"STOP"COMMAND BOTH • !VERBALLY AND HAND SIGNAL UNDERSTOOD 11'00 - 11:30 0.50 MOB i P PRE [SPOT RIG OVER WELL 11 30 - 13:00 1.50 MOB P ! PRE ["RIG SPOTTED AND ACCEPTED 13:00 - 13:15 0.25 ' MOB P PRE CALL PAD OP TO REMOVE LOTO ON THE 1 WING r13:15 - 14:00 0.75 MOB P' PRE 'LOCK REMOVED FROM WING OPEN SSV,MASTER&SWAB VALVES,NO !PRESSURE INSTALL FUSIBLE CAP AND BLEED OFF PRESSURE r 14:00 - 14:30 0.50 MOB P PRE RU TEST HOSE TO LTT THE MASTER&SWAB I- I TO BREAK CONTAINMENT FOR TREE CAP 114:30 - 17:00 2.50 MOB P PRE !GOOD LTT,ND TREE CAP AND NU BOPE MU LUBRICATOR 17:00 - 18:30 1.50 MOB P PRE PU INJECTOR AND PREP TO STAB COIL 1 18:30 - 19:00 0.50 MOB P ! PRE CREW CHANGE. RIG CHECKS AND PIT STRAPS. 19:00 - 20:10 1.17 MOB PI PRE 'PJSM FOR PULLING CTACROSS FROM REEL 1 ! I HOUSE INTO INJECTOR. 1 !DISCUSS EXCLUSION ZONES,WORKING AT j I HEIGHTS. PULL TEST GRAPPLE THEN REMOVE CLAMP i AND SHIPPING BAR. PULL CTACROSS PIPE SHED INTO INJECTOR. 20:10 - 22:00 1.83 MOB P PRE 1 REMOVE GRAPPLE AND CUT CT TO FIND ( I !CABLE. !TEST CABLE,GOOD. INSTALL CT CONNECTOR AND NOZZLE, MOVE INJECTOR OVER CIRC HOLE. 122:00 22:30 0.50 MOB P ! PRE RIG EVAC EXERCISE WITH ORLOFF CREW. ALL PERSONS MUSTER AND ACCOUNTED IFOR IN2MIN. 1 CONDUCTAAR AFTER THE DRILL. Printed 6/13/2016 12.15:46PM *AII depths reported in Drillers Depths* • . ,',,: . North America-ALASKA-BP Page 2 Cy. ?,, -,,,,z,,,,,,„„,/,,,,f ,.4; '._ ,/,f, �, Operation Summary Report Common Well Name:11-12 AFE No Event Type:RE-ENTER-ONSHORE(RON) j Start Date:5/29/2016 1 End Date:6/5/2016 1X3-017RQ-C:(2,084,716.00) Project:Prudhoe Bay 1 Site:PB DS 11 i Rig Name/No.:NORDIC 2 Spud Date/Time:11/16/1984 12:00:00AM I Rig Release:6/7/2016 Rig Contractor:NORDIC CALISTA UWI:500292121200 Active datum:Kelly Bushing/Rotary Table @58.00usft(above Mean Sea Level) Date 1 From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 1 (usft) 122:30 - 00:00 1.50 1 BOPSUR P PRE PREP FOR BOP TEST. LOAD TEST JOINTS ONTO RIG. TEST GAS ALARMS AND PVT LEVEL I INDICATORS. 1 FLOOD STACK AND SHELL TEST,GOOD. 5/30/2016 00:00 - 01:30 1.50 BOPSUR P PRE j CONTINUE TESTING BOPS. 1 TEST BLIND SHEARS,UPPER COMBIS AND 1 JCHOKE MANIFOLD VALVES. TEST IS WITNESSED BY AOGCC REP JOHN 'HILL. 01:30 - 03:00 1.50 BOPSUR N 1 RREP PRE LOWER COMBIS WON'T TEST, TROUBLESHOOT. FIND OPEN/CLOSE TAGS ON THE BLOCK WERE LABELLED WRONG. SWAP OPEN/ CLOSE FITTINGS ON THE BOP BODY AND TEST,WORKING FINE. 103:00 - 05:00 2.00 BOPSUR P 1 PRE CONTINUE BOP TEST. TEST LOWER 1 1 COMBIS,VBRS. 1I. [CONDUCT DRAWDOWN TEST. MISSING A PORTED SUB FOR THE 3-1/2 TEST JOINT 05:00 - 07:00 2.00 BOPSUR ' P PRE MU PORTED SUB AND CONTINUE TESTING 07:00 - 11:00 4.00 1 BOPSUR P PRE 1h PERFORM YEARLY BOP MANUAL LOCK `TESTS 11:00 - 11:10 0.17 BOPSUR + P , PRE I BOP MANUAL LOCKS TESTED 1 1 HOLD A PJSM TO PU THE INJECTOR AND __ CALIBRATE THE WEIGHT CELL 11:10 - 12:00 0.83 BOPSUR P PRE PU THE INJECTOR I MU A PULL TEST PLATE AND CALIBRATE WEIGHT CELL IN 5K INCREMENTS TO 25K 112:00 - 13:00 1.00 BOPSUR ._I P PRE 1CALIBRATION IS DONE ! I MU A STINGER&NOZZLE AND STAB ON AND 1 1 TEST THE INNER REEL VALVE&PACK OFF 113:00 - 13:45 0.75 BOPSUR P PRE 1 GOOD INNER REEL TEST I PRESSURE UP TO 4700PSI TO PT THE REEL 1 I HARDLINE BLEED OFF,TEST PUMP MANIFOLD HAS A !LEAK PRESSURE UP TO 4700 PSI 113:45 - 14:00 0.25 ' BOPSUR P PRE GOOD PT TO 4700 PSI I LINE UP TO PUMP SLACK FORWARD AT MAX ' IRATE 114:00 - 14:30 0.50 BOPSUR N SFAL I PRE PU THE INJECTOR AND CHECK FOR WIRE j WE HAVE WIRE HEAD UP 14:30 - 17:00 2.50 BOPSUR i N SFAL PRE WIRE NOT TESTING,DIRECT SHORT BUT 1 WIRE TESTED GOOD LAST NIGHT 1 [MOVE THE INJECTOR TO THE SIDE WHILE 1 1 BHI TROUBLESHOOTS WIRE TO PULL THE 1 TEST PLUG AND INSTALL THE NIGHT CAP TO ALLOW THE GREASE CREW TO CHECK THE TREE BOLTS ' CUT 15'OF COIL AND WIRE,TEST AND 1 FAILED 17:00 - 17:30 0.50 BOPSUR N SFAL PRE !SEAL WIRE AND REVERSE CIRC ELINE TO 1 REMOVE THE UPHOLE END PRESSURE BULKHEAD TO CHECK THE WIRE Printed 6/13/2016 12.15:46PM *All depths reported in Drillers Depths* • I North America-ALASKA-BP Page 3 Off Operation Summary Report Common Well Name:11-12 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:5/29/2016 I End Date:6/5/2016 1X3-017RQ-C:(2,084,716.00) I 1 Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 I Spud Date/me:11/16/1984 12:00:00AM 1 Rig Release:6/7/2016 Rig Contractor:NORDIC CALISTA I UWI:500292121200 Active datum:Kelly Bushing/Rotary Table @58.00usft(above Mean Sea Level) Date From-To Hrs Task ( Code NPT NPT Depth Phase 1 Description of Operations (hr) 1 (usft) 1 17:30 - 19:00 1.50 BOPSUR N SFAL PRE SMALL KINK AT THE UPHOLE END,CUT OUT i 1 AND RU CUTTER TO FIND WIRE THEN TEST IF THE TEST IS BAD CUT MORE PIPE&WIRE TO SEE IF THE LINE WILL TEST. WIRE TESTS BAD. PULL BULKHEAD AND INSPECT WIRE, APPEARS TO BE DRY AT THE BULKHEAD I END. WIRE TESTS GOOD BUT STILL HAS MOISTURE AT THE CONDUCTOR ON THE RIG FLOOR. 19:00 - 21:20 2.33 BOPSUR N SFAL PRE IPJSM THEN INSTALL HYDRAULIC CUTTER. CUT 150 FT OF CABLE AND CT TO LOOK FOR 1 DRY WIRE,INNER ARMOR IS STILL WET. 1 WIRE TESTS GOOD. :DISCUSS WITH SLB AND SPECIALIST/ ACTING WTL,DECIDE TO INSTALL BULKHEAD �AND MOVE FORWARD WITH CONNECTOR. 21:20 - 22:40 1.33 BOPSUR ' N SFAL PRE AFTER ASSEMBLE BULKHEAD,TEST WIRE 1 . AGAIN,GOOD. 1 11 INSTALL CT CONNECTOR AND PULL TEST, IGOOD. 'INSTALL BHI CABLE HEAD WITH DBPV. 22:40 - 23:00 0.33 BOPSUR N SFAL PRE +PRESSURE TEST BULKHEAD AND CT j CONNECTOR,BHI CABLE HEAD TO 300/4700 1 I PSI. 1 I BULKHEAD IS LEAKING,TIGHTEN AND TRY ' l AGAIN. 1 RETEST,BULKHEAD IS LEAKING. 23:00 - 00:00 1 00 BOPSUR N` SFAL PRE REBUILD BULKHEAD. 5/31/2016 00:00 - 03:00 3.00 RIGU N SFAL 1 PRE REBUILD PRESSURE BULKHEAD. 1 ALLOW TIME FOR LOCTITE TO CURE INSIDE BULKHEAD. 1 PRESSURE TEST BULKHEAD AND CT I ;CONNECTOR,BHI CABLE HEAD TO 300/4700 PSI,GOOD. 03:00 - 04:10 1.17 RIGU P PRE 'TEST CABLE,GOOD. �INSTALL NOZZLE AND GET ON WELL,PUMP 1 SLACK FORWARD WHILE CHECKING IN/OUT MM. 04:10 - 04:25 0.25 ( RIGU P r I — PRE PU THE INJECTOR j 'INSTALL THE NIGHT CAP AND TEST TO OPEN 1 UP TO THE WELL 04:25 - 04:55 0.50 WHIP P WEXIT OPEN WELL TO A CLOSED CHOKE WELL HAS I 30 PSI BLEED OFF AND SEE IF IT BUILDS ANY PRESSURE I LINE UP TO PUMP METHANOL ACROSS THE 1 TOP TO ENSURE THE WELL IS FULL 104:55 - 05:05 0.17 WHIP P WEXIT WELL TOOK 15 BBLS 1 1 FLOW CHECK WELL - 05:05 - 05:20 0.25 WHIP F P WEXIT GOOD NO FLOW REMOVE THE NIGHT CAP FLUID IS STATIC IN THE WELL HOLD A PJSM TO MU THE WS BHA 05:20 - 06:00 0.67 WHIP P WEXIT I MU THE BHA 05:45 INJECTOR ON THE WELL 106:00 - 06:15 0.25 WHIP P WEXIT CREW CHANGE Printed 6/13/2016 12:15:46PM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 4 0ly. Operation Summary Report Common Well Name:11-12 AFE No Event Type:RE-ENTER-ONSHORE(RON) ,Start Date:5/29/2016 End Date:6/5/2016 X3-017RQ-C:(2,084,716.00) Project:Prudhoe Bay I Site:PB DS 11 Rig Name/No.:NORDIC 2 {I Spud Date/me:11/16/1984 12:00:00AM Rig Release:6/7/2016 Rig Contractor:NORDIC CALISTA UWI:500292121200 Active datum:Kelly Bushing/Rotary Table©58.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:15 - 08:20 2.08 WHIP P WEXIT RIH FOLLOWING INITIAL WELL ENTRY 1 GUIDELINES TAKING ALL RETURNS I THROUGH THE CHOKE AND OUT TO THE TT 2000'IN THE HOLE WE ARE GETTING GAS CUT FLUID BACK 08:20 - 09:10 0.83 WHIP N DPRB 9,900.00 WEXIT 19900'INJECTOR IS HAVING SOME HYDRAULIC 1 ISSUES,MIGHT BE FROM THE POWER PACK. "iTROUBLESHOOT;ISSUE WILL NOT HINDER CURRENT OPS,CONTINUE TO RIH. 09:10 - 09:55 0.75 WHIP j P WEXIT LOG TIE IN AND START BOTTOMS UP DISPLACEMENT WITH HOT KCL THEN SWAP TO MU 09:55 - 10:10 0.25 WHIP P WEXIT CORRECT DEPTH-19' 1 PUH TO 11500'AND LOG CCL DOWN TO 112100' 10:10 - 11:00 0.83 WHIP P WEXIT LOG CCL SHUT IN-CHOKE TO EMPTY TIGER TANK. 111:00 - 11:45 0.75 WHIP P WEXIT COMPARE BHI GENERATED CCL JUST NOW WITH THE ONE IN THE WELL PLAN AND THE j ONE FOR THE POSISET PLUG SETTING ON MARCH 2016,ALL LOGS MATCH WITHIN 1 FT OF EACH OTHER. NO CHANGE TO SETTING DEPTH REQUIRED. RUN DOWN TO 12,093 FT(LEAVE TOWS AT 12,075 FT)AT 180L AND CLOSE EDC. PICK UP TO NEUTRAL WT AND WAIT FOR TIGER TANK TO GET EMPTIED. - I 4 SET WHIPSTOCK AT 12,075 FT(TOWS)AND 11:45 14:30 2.75 WHIP P i WEXIT ; 180L ORIENTATION. SETTING TOOL SHEARS OUT AT 3500 PSI. 5K ON DWOB,GOOD SET. 1 PICK UP OUT OF SETTING TOOL,OPEN EDC. j ( 1 FINISH CIRCULATING 120 DEG KCL AROUND AT 3 BPM. GETTING GAS CUT FLUID BACK HOLD 200- j 1 300 PSI WH P. [ANNULAR BOTTOM HOLE PRESSURE>4000 j I II PSI WHILE CIRCULATING. 14:30 - 15:40 1.17 WHIP P WEXIT AFTER GETTING CLEAN KCL BACK SHUT DOWN,15 MIN FLOW CHECK IS GOOD,NO FLOW. VAC OUT TIGER TANK TO ALLOW ROOM FOR _ MUD DISPLACEMENT OF KCL IN THE WELL. 15:40 19:40 4.00 j WHIP P WEXIT START MUD DOWN THE CT. CIRCULATE 9.5 PPG MUD DOWN COILAND DISPLACE SYSTEM. BEGIN TO POH WITH 9.5 PPG !FLUID UP INTO THE 4-1/2"TUBING. 1-MONITOR FLUID AT SHAKER,SEE SMALL j ENTRAINED BUBBLES BUT NO METHANE 'READING. DENSITY FLUCTUATED BY.1 PPG. STOP MOVEMENT AT 5900',NO FLOW. DISCUSS LINE-UP PROCEDURE,CIRCULATE THROUGH MUD GAS SEPARATOR AS PRECAUTION. NO ISSUES WITH CIRCULATION,CONTINUE TO POH WHILE CIRCULATING THROUGH MGS. -PULL TO SURFACE,PJSM FOR LAYING 'DOWN BHA. PULL TO 200' FLOW CHECK,NO FLOWALL GOOD. I -PULL TO STACK,POP OFF WITH INJECTOR. Printed 6/13/2016 12:15:46PM *AII depths reported in Drillers Depths* ID • North America-ALASKA BP t Page 5 i` Operation Summary Report57, , r. ` Common Well Name 11-12 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:5/29/2016 End Date 6/5/2016 X3-017RQ-C:(2,084,716 00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/me:11/16/1984 12:00:00AM Rig Release:6/7/2016 Rig Contractor:NORDIC CALISTA UWI:500292121200 Active datum:Kelly Bushing/Rotary Table @58.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) — (usft) '19:40 - 20:30 0.83 WHIP P WEXIT I LAY DOWN BHA,ALL TOOLS GOOD. i-FLOOD AND CLEAN MUD GAS SEPARATOR WITH FRESH WATER -PJSM ON MAKING UP BHA 20 30 - 21:10 0.67 STWHIP P WEXIT GAUGE MILLS,3.80"NO-GO AND 3.81"GO. I MAKE UP WINDOW MILLING BHA. INJECTOR ON AT 20:45. ZERO COUNTERS,TEST BHI TOOL AND QTS, ,RIH. 21:10 - 00:00 2.83 STWHIP P T WEXIT .'I RIH WITH BHA#2. IAROUND 1000 FT,STOP AND ADJUST GOOSENECKAND P14 PUMP ON POWER PACK. NO DELAYS TO RIG TIME, ADJUSTMENTS MADE WHILE RIH. CONTINUE RIH. 6/1/2016 00:00 - 00:30 0.50 STWHIP P WEXIT I LOG TIE-IN FROM 11,970 FT. CORRECT-21 FT. DRY TAG WHIPSTOCK PINCH POINT AT 12,082 FT PICKUP IS CLEAN,43K. 00:30 - 02:00 1.50 STWHIP -P WEXIT I BRING PUMP TO 2.8 BPM. EASE DOWN AND START MILLING 12,081.2 FT. I�1�(c-r 02:00 - 02:30 0.50 STWHIPWWI P EXIT (MILL NDOWAT 12,082.30 FT. J /� I { I '2.81/2.85 BPM WITH 3100 PSI FREE SPIN. 1t 11 c- MILLING AT 1 FT/HR WITH 0.97K DWOB. l 1-I N . OUT RATE IS SLIGHTLY ERRATIC,PICK UP AND FLOW CHECK. 10 MIN FLOW CHECK IS GOOD,NO FLOW. I I MUD IS GETTING AIRED UP SLIGHTLY,WILL ADD SOME DEFOAM. 102:30 - 03:20 0.83 STWHIP P WEXIT I CONTINUE MILLING WINDOW AT 12,082.6 FT. 1 MILL AT 1 FT/HR WITH 2.3K DWOB. I MILL TO 12,083.10 FT. 03:20 - 05:00 1.67 STWHIP P WEXIT r CONTINUE MILLING AT 12,083.2 FT. I 2.82/2.85 BPM IN/OUT,FREE SPIN AROUND 3150 PSI. 9.56/9.48 PPG,ECD=10.26 PPG. I IA/OA=448/13 PSI. 05:00 - 06:20 1.33 STWHIP PWEXIT I CONTINUE MILLING AT 12,084.50 FT WITH 3.38K DWOB. 2.81/2.84 BPM IN/OUT 9.55/9.48 PPG. 1 ECD=10.22 PPG,ANNULAR PRESSURE= 1 4492 PSI. I I GETTING LOTS OF METAL BACK. Printed 6/13/2016 12 15.46PM *AII depths reported in Drillers Depths* • • North America-ALASKA-BP Page 6 Operation Summary Report Common Well Name:11-12 AFE No Event Type:RE-ENTER-ONSHORE(RON) 1 Start Date:5/29/2016 i End Date:6/5/2016 X3-017RQ-C:(2,084,716.00) 1 Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:11/16/1984 12:00:00AM Rig Release:6/7/2016 Rig Contractor:NORDIC CALISTA 1 UWI:500292121200 Active datum:Kelly Bushing/Rotary Table @58.O0usft(above Mean Sea Level) Date From-To 1 Hrs Task Code NPT NPT Depth Phase Description of Operations ( (usft) 06:20 - 13:30 7.17 STWHIP i P WEXIT i CONTINUE MILLING AT 12,085.60 FT WITH I 2.2-4.0K DWOB. 2.81/2.82 BPM AT 2040 PSI FREE SPIN. ECD 1 I.10.22 PPG THROUGHOUT OPERATION I-EXIT FROM MIDPOINT AND NOSE OUT OBSERVED WITH SLIGHT DROP IN ;PRESSURE -LOT'S OF METAL STILL. MW IN 9.53 PPG, 1 j MW OUT 9.47 PPG WITH NO LOSSES TO I,FORMATION. DEFOAMER DID HELP BUT I !STILL SLIGHTLY AIRED UP IN RETURN PIT. SAMPLE FROM WINDOW EXIT POINT AT 12,090'SHOWS SOME GRAINS OF 1 FORMATION BUT PRIMARILY CEMENT I--SLOWLY MILL INITIAL 3'FEET OF RATHOLE TO ALLOW STRING REAMER TO WORK 1 i THROUGH WINDOW 1-MILL TO 12,100' 13:30 - 15:15 1.75 STWHIP P WEXIT CONDUCT REAM'PASSES FROM 12,100'PER WELL PLAN WITH NO ISSUES. ALL PASSES 1 CLEAN. DRY DRIFT,CLEAN. -SAMPLE FROM 12,095'MIXED CEMENT AND i FORMATION -CIRCULATE DOWN HI-VIS PILL WHILE ! 1CONDUCTING LAST REAM PASS ! 1 -SAMPLE FROM CURRENT TD OF 12,100' i SHOWS FORMATION MIXED WITH CEMENT '15:15 - 16:00 0.75 STWHIP P I WEXIT CIRCULATE HI-VIS PILL OUT OF BIT,PULL 1 INTO CASING AND FLOW CHECK WHILE 1 OPENING EDC. FLOW CHECK ALL GOOD. I-SLOWLY PICK UP HOLE TO JET CASING 1 WHILE IN 7" -CIRC AT 3.2 BPM,3000 PSI 1 i -MW IN 9.54 PPG,MW OUT 9.48 PPG,ECD OF 1 10.3 PPG ON BOTTOM 116:00 - 18:00 2.00 STWHIP P 1 WEXIT POOH,PUMP THROUGH OPEN EDC WHILE 1 1 .POOH. 18:00 - 19:40 1.67 STWHIP P ( WEXIT I TAG STRIPPER AND UD BHA#2. 1 INJECTOR OFF AT 18:45. 'CONDUCT KICK WHILE BREAKING DOWN BHA DRILL WITH SIMULATED FLOW AT SURFACE. CREW RESPONDED ACCORDING TO STANDING ORDERS BY PULLING BHA ! 1 AND CLOSING IN WITH BLINDS AND CLOSING F CHOKE. RESPONSE TIME OF 25 SECONDS TO HAVE WELL SECURED. j MILL IS 3.79 NO-GO,3.80 GO. REAMER IS 3.80 1 NO-GO,3.81 GO. M/U BHA#3,BUILD ASSEMBLY. '2.15 DEG ULS MOTOR WITH RES,HYC 4.25 BI-CENTER BIT WITH TCC. I BHA OAL=79.86 FT. F INJECTOR ON AT 19:40. 19:40 - 22:20 j 2.67 DRILL P PROD1 ZERO COUNTERS,OPEN EDC,TEST QTS AND 1 I i BHI TOOLS,RIH. 1 ( ( PUMP 0.6 BPM/900 PSI THROUGH OPEN EDC. ' ISLOW DOWN PAST 4950-5000 FT,NOTHING I 1 ISEEN. Printed 6/13/2016 12:15:46PM *AII depths reported in Drillers Depths* 411 TIS= FMC t. VVELLFfAD_ FMC 1 -1 2 SAFETY NOTES:13-3/8"x 9-5/8"Annulus Cemented to Surface. 9-58"CSG Pinched Q-4975'-499W md. ACTUATOR= BAIth2C """5-1/2"&4-1/2"CHROME TBG&NIPPLES""" KBELEv5� ` , + _ 8_ OP- 2000' If1 IN 1765' --f 9-5/8"HES ES CEMENTER Max Angle= 57" 9200 #CONDUCTOR, ? i$ w4 Qatum MD; ^Y 12501' —#_ +moi i 1787' H9-5/8"BKR ECP,D=8.835" Datum TVD= _. 8800'SS D= /1 9-5/8"CSG,47#,L-80 HY D 563,D=8.835' —{ 1755' /% 2183' - 5-1/2"HES X NIP D=4.562" 9-5/8"BOWEV CSG PATCH,I)=10.750" H 1819'-1823' 9-5/8"CSG,47#, L-80 BTC,D=8.835" H 1823' GAS LFT MANDRELS _S 13-3/8"CSG,72#,L-80,D=12.347" -{ 2529' ST MD TVD DEV TY FE VLV LATCH FORT DATE 4 3399 3241 42 MGM DRAY RIC 0 11/21/15 Minimum ID= 3.80"@ 9127' 3 5837 4785 53 MMG-M DMY RI< 0 05/03/09 MILLED 4-1/2" HES XN NIPPLE 2 7548 5793 56 MING-M DMY RK 0 11/21/15 1 8892 6552 57 MM3-M DMV RK 0 05/03/09 9-5/8"CSG FIN(3-ED(FB2 RW)REPORTS — —4975' 04/09)SEE SAFETY NOTES 5-1/2"TBG,174,13C R-80 VAM TOP HC, H 8959' 8969' 5-1/2"X 4-1/2"XO,D=3.958" _0232 bpf,D=4.892" f TOPOF 7"LNR H 9029' 9032' —4-1/2"HES X NP,D=3.813" oil C4119063 -.17"X 4-1/2"BKR S3 PFS D=3.870" 9096' —4-1/2"HES X MP,D=3.813" 4-1/2"TBG,12.64,13CR-80 VAM TOP, --J 9140' II 9127' J-4-1/2"HES XN NIP MLLE)TO 3.80"(01/14/16) si .0152 bpf,13=3.958" I 9-518"CSG,47#,L-80,D=8.681" 9318' 9140' 1-14-1/2"WLEG,ID=3.958" PERFORATION SUMMARY L#6751-4, 7 Wis(05/31/16) I REF LOG:BHCS ON 12/02/84 ANGLEAT TOP F@2F:48" ���+•#�.�i 1 12128' DUMP BALED CMT(03/26/16) 1 CQ3 1222T *14*«ea,**4*1r4 Note:Infer to Production DB for historical perf data 12140' —2.125"SLB POSISET PLUG(03/25/16) SIZE SPF NIU VAL Opn/SgZ SHOT SOZ I 2-1/2" 4 12227-12233 C 11/09/93 12358' —3-3/8"BKR BP(05106/15) 1 2-5/8" 0.1 12440-12470 C 09/17/88 2" 0.25 12506-12528 C 07/23/89 I 2-1/8" 0 12562-12574 C 10/07/85 2-1/8" 0 12626-12656 C 10/07/85 2-1/8' 0 12674-12684 C 10/07/85 I 2-1/8" 0 12682-12684 C 10/07/85 2-1/8" 0 12700-12806 C 09/17/88 I I PBTD 12969' "*.*®*'*.�i i***i*r*414" *!*+►****ib*: 7"LNR,29#,L-80,.0371 bpf,D=6.184" —1 13032' '••""••" DATE REV BY COMMENTS DATE REV BY COMMENTS PRIAJI-IOE BAY UNIT 12/15/84 ORIGINAL COMPLETION 01/26/16 TTR/JMD MLLED XN tic,(01/14/16) WELL: 11-12 07/18/88 LAST WOIICOVHl 02/25/16 JM3 CORRECTED BP(05/06/15) FERMATNo: 1841950 05/03/09 N2E5 RWO 04/01/16 LAC/JMD SET FLUG/CMT(03/25-26/16) AR No: 50-029-21212-00 08/19/09 MS/JMD DRLG DRAFT CORRIMTIONS 04/07/16 JM) FRS RIG UPDATES SEC 33,T11 N,R15E,136'FNL&107'FEL 05/06/15 JCM PJC SET ER CLOSE PERFS , 11/24/15 RJK/JMD GLV C/O(11/21/15) BP Exploration(Alaska) VOF Tit • A \��\�v7,', THE STATE Alaska Oil and Gas 4? ,-s_ �, o ALASKA S Conservation Commission f i} 333 West Seventh Avenue 1."1"141yialjtit , GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF SSP Fax: 907.276.7542 www.aogcc.alaska.gov John McMullen Engineering Team Leader BP Exploration(Alaska), Inc. P.O. Box 196612 SCANNEV [La 2 2-236 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Bay Oil Pool,PBU 11-12 Permit to Drill Number: 184-195 Sundry Number: 316-117 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, 461 /(3 .47(4 Cathy . Foerster �{ , Chair DATED this Ilo day of February,2016. RBDMS L t- FEB 16 Z016 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMIRON • APPLICATION FOR SUNDRY APPROS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tabing 0 Change Approved Program 0 Plug for Redrill Q • Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing ❑ Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: • 5. Permit to Drill Number: 184-195 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development Q 6. API Number: 50-029-21212-00-00 - 99519-6612 Stratigraphic ❑ Service ❑ 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No Q PBU 11-12 _ RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: FEB 1 0 1 ADL 028325&028328 • PRUDHOE BAY,PRUDHOE OIL - 01'3 /1 /‘ i� 11. PRESENT WELL CONDITION SUMMARY �-7 CC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): v/ Plugs(MD): Q1 t 13032 9169 12358 8767 2380 12358 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 30-110 30-110 1490 470 Surface 2501 13-3/8" 29-2530 29-2504 4930 2670 Intermediate 9292 9-5/8" 27-9319 27-6785 6870 4760 Production Liner 4004 7 9029-13032 6627-9169 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12227-12806 8681 -9041 5-1/2",17#x 4-1/2", 12.6# 13Cr80 9140 Packers and SSSV Type: 4-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and TVD(ft): 9063/6645 12.Attachments: Proposal Summary 0 Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program RI BOP Sketch RI Exploratory ❑ Stratigraphic 0 Development RI Service 0 14.Estimated Date for Commencing Operations: March 1,2016 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended RI 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Gorrell,John be deviated from without prior written approval. ,A 7 Email John.Gorrell@bp.com Printed Name John en 1 Title Engineering Team Leader i ry �7 r /111//{ Signature ,-,--V__.--� Phone +1 907 564 4711 Date 2, I r / / 6 COMMISSION USE ONLY Conditis of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test L1 Mechanical Integrity Test 0 Location Clearance 0 Other: !3G p tt S f to 3 SL G p$–I /9-i.1 v/a /2Krc�"ty, ft✓ trif f o z�G c' /�sy'� / Post Initial Injection MIT Req'd? Yes 0 No A I tt i h �� 1,11/" la ez'GL7 t v7 I G`y/�p/JJ�G v-t C A p-tr,Zc,4.•675./17--(t) Spacing Exception Required? Yes 0 No l Subsequent Form Required: 1 G — "T"G 7- 1 / APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date:2 // / 'ORIGINAL RBDMS I,/". FEB 1 6 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • • To: Alaska Oil & Gas Conservation Commission From: John Gorrell b CTD Engineer Date: January 26, 2016 Re: 11-12 Sundry Approval Sundry approval is requested to plug the 11-12 liner perforations as part of the drilling and completion of the proposed 11-12A CTD sidetrack. History and current status: Well 11-12 was originally drilled and completed in December 1984. Most recently the well had a RWO performed in 2009 to repair a TxIA and surface casing leak, as well as replacing the tubing with a 5.5" x 4.5" 13Cr-80 string. 11-12 had been producing at a high gas cut, and a cast iron bridge plug was set in hopes of reducing the high production of gas in May of 2015. The continued high amounts of gas being produced led to several shut ins, and eventually 11-12 was shut in and released for sidetrack in September of 2015. The CTD target has been planned to gain access to nearby Zone 1A resources, as well as a planned toe up near the end of the well to produce a Zone 1B target as well. Proposed plan: Approval is requested for a permit to drill a CTD sidetrack lateral from well 11-12 by the Nordic 2 Coiled Tubing Drilling rig on or around June 1, 2016. The 11-12A sidetrack will perform a single- string exit through the existing 7" casing. Kick-off will occur in Zone 4 and target Zone 1A reserves. The proposed sidetrack is a —1500' horizontal Ivishak Zone 1A producer which will access targets south of DS 11. The lateral will be completed with a 3-1/2" x 2-7/8" 13-Chrome liner which will be cemented and perforated. This Sundry covers plugging the existing 11-12 perforations via the 11-12A 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. j17 �ve1/ ��y jePo ., /00 h 4 con w(. �o% /> ,Q f 2a�', 6efo/ /4/-4/1/4, 749 (.�s f�/ ; F0� �iiffo>n'�,sfp� f �,t) r�► A/ hoe/ t° z /001040 fter - ty 17er be 4$7 ddoft''f' C,• 6P ,hs anal ;�rr� wsf �,;;�1,��1 i'Ar4t)- 04 �4e God cls`Ott, ( / Cedrr` ✓iho'/c1 allow r /roto vea fecove, 6.01 1,10 wet 0-1)9 OF Ike feel. /11 14 • • • Pre-Rig Work(scheduled to begin March 1, 2016) 1. E Set 7" PosiSet plug. Dump bail cement. 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 June 1,2016) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,380 psi). �' ' ' TWC 2. Pull and kill well (if necessary). 0. 6(�y 3. Set 4-1/2" x 7" delta whifpstock at 12,086'. 4. Mill 3.80"window and 10' of rathole. 5. Drill build: 4.25"OH, —650' (35 deg DLS planned). 6. Drill lateral: 4.25" OH, —850' (12 deg DLS planned). \i/ N`cv/ 7. Run 3-1/2"x 2-7/8" 13Cr-80 liner leaving TOL at—9,110' MD. 8. Pump primary cement job: 36 bbls, 15.8 ppg Class G, TOC at—11,500' MD.* 9. Liner cleanout and RPM/GR/CCL log. 10. Perform liner lap test. 11. Perforate —750' liner based on log interpretation. 12. Freeze protect well to 2,500'TVDss. 13. Set TWC; RDMO. Post-Rig Work 1. V Pull TWC, tree work as necessary. 2. S Set LTP*(if needed) and GLVs. 3. F Pressure test LTP (if set). 3. T Test separator flow back with N2. 4. E Shoot in-situ gas lift perforations. Set patch with orifice. *Approved alternate plug placement per 20 AAC 25.112(i) John Gorrell CTD Engineer 564-5458 229-9986 CC: Well File Joe Lastufka I F5±= FMC 4101 1 -1 2 to rfaNOTES:13-3/8"x 94/8"Annulus Cemented WELLHEAD= FMC ce. 9-5/8"CSG Pinched ,:;', -4975*-4990'md. ACTUATOR= BAKER C "5-1/2"&4-1/2'CHROME TBG&MPPLES*'• KB.ELEV= 58' I I . S BE BEV= I ll 14 40 Si 1764' —9-5/8"FES ES CEMENTER KOP= 2000' I.• r.1 Max Angle= 57°4229200' —4 C°M3UCT°R• 1,4 M Datum AU= 12490' —#, , 1 178T —9-5/8"BKR ECP,1)=8,835" Datum ND= 8800'SS ID= P 9-5/8"eso,47#,L-80 HYD 563,ID=8.835' —1 1755' I I 2183' —5-1/2"FEB X141",ID=4.562" 9-5/8"BOWEN CSG PATCH,D=10.750" — 1819'-1823' 9-5/8"CSG,47#, L-80 BTC,ID=8.835' — 1823' GAS LFT ivIAPCFIELS 13-3/8"CSG,72#,L-80,ID=12.347 — 2529' ST AC ND DEV TYPE VLV 'LATCH FORT DATE 4 3399 '3244 v 41 1.9‘4G-M DU/ ' RK 0 11121/15' Minimum ID = 3.80" @ 9127' 3 5837 4791 v 52 hats-ki DMY RK 0 05/03/09 2 7548 5801 r 56 MIAG-M CMY F 0 11/21/15 MILLED 4-1/2" HES XN NIPPLE 1 8892 6561 '57 MAG-M DIN IRK 0 05/03/09 ./ 9-5/8"CSG PINCHED(FER RV'.O REPORTS — —4975' L 04/09)SEE SAFETY NOTES 5-1/2"TBG, 17#,13CR-80 VAM TOP HC, — 8960' / 8960' H5-1/2'X 4-1/2"XO,1)=1958' .0232 bpf,ID=4.892" TOP OF r LW 1— 9029' I 9032' —14-1/2"HES X M3,ID=3.813" 1 0 X 9063' —7'.X 4-1/2"BKR S-3 PKR,12)=3.870" I 9096' —4-1/2"FES X NW,ID=3.813" 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, — 9140' I 9127' —4-1/T FES XN MP MILLED TO 3.80"(01/14/16) .0152 bpf,ID=3,958" • 9140' —i4-1/2"WLEG,ID=3.958" 9-5/8"CSG,47#,L-80,ID=8.681' —1 931W FERFORATION SUMMARY REF LOG:BHCS ON 12/02/84 ANGLE AT TOP WW:47'@12221' Note:Refer to R-oduction DB for historical perf data SIZE SW IITERVAL Opn/Sqz SHOT SOZ 2-1/2" 4 12777-12233 0 11/09/93 12358' —3-3/8'BKR CEP(05/06/15) 2-5/8" 0.1 124-40-12470 C 09/17188 2" 0.25 12506-12528 C 07/23/89 2-1/8" 0 12562-12574 C 10/07/85 2-1/8' 0 12626-12656 C 10/07/85 2-18" 0 12674-12684 C 10/07/85 2-1/8" 0 12682- 12684 C 10/07/85 2-1/8" 0 12700-12806 C 09/17/88 PBTD —1 12969' I •••••• ••••••• •••••• r•••••• ••••••1 7"UR,29#,L-80,.0371 bpf,ID=6.1E34' H 13032' .,...... .. DATE REV BY COHABITS DATE REV BY COAUNTS PRUDHOE BAY MT 12/15/84 ORIGINAL COM PLET1ON 01/26/16 111-VAE MLLED XN1413(01/14/16) WELL: 11-12 07/18188 LAST WOR(OVER FAT No:v1841950 05/03/09' N2EB MVO AIR hb: 50-029-21212-00 08/19/09 MS/AU CRLG DRAFT CO ,RRECTIONS SEC 33,T11N,R15E, 136'FM L&107'FEL 05/06/15 JCM PJC SET BR CLOSE PEWS , 11/24/15 R.JK/JM) GLV 00(11/21/15) BP Exploration(Alaska) TREE= FMC NOTES:13-3/8"x 9-5/8"Annulus Cemented WELLHEAD= FMC PROPOSED DRAFT 1 1 -1 2A to Surface. 9-5/8"CSG Pinched @-4975'-4990'md. ACTUATOR= BAKERC KB.ELEV= 58' "**5-1/2"&4-1/2"CHROME TBG&NIPPLES"*" BF.ELEV= I '., • 11 KOP= 2000' I'� 1764' —19-5/8"HES ES CEJv1ENTER Max Angle= °@ ' _#CONDUCTOR, e I. Datum MD= _#, !A 71 Datum TV D= 8800'SS 13= .. 1787' H9-5/8"BKR ECP,ID=8.835" 9-5/8"CSG,47#,L-80 HYD 563,D=8.835' H 1755' ' 2183' --I5-1/2"HES X NP,D=4.562" 9-5/8"BOWEN CSG PATCH,D=10.750" —I 1819' -1823' 9-5/8"CSG,47#, L-80 BTC,D=8.835" - 1823' GAS LFT MANDRELS 13-3/8"CSG,72#,L-80,D=12.347" — 2529' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3399 3244/Pr41 MMG-M DMY RK 0 11/21/15 Minimum ID = 3.725" @ 9127' 3 5837 4791 r 52 MMG-M DMY RK 0 05/03/09 4-1/2" HES XN NIPPLE 2 7548 5801 '56 MMG-M DMY RK 0 11/21/15 1 8892 6561 '57 MMG-M DMY RK 0 05/03/09 9-5/8"CSG PINCHED(PER RWO REPOR I b —I -4975' / 04/09)SEE SAFETY NOTES 5-1/2"TBG,17#,13CR-80 VAM TOP HC, H 8960' / 8960' ---15-1/2"X 4-1/2"XO,ID=3.958" .0232 bpf,ID=4.892" TOP OF 7"LNR —1 9029' 1111 — 0 — 9032' -14-1/2"HES X NP,D=3.813" e X 9063' —17"X 4-1/2"BKR S-3 PKR,D=3.870" 111 9096' —14-1/2"HES X NP,U=3.813" TOP OF 3-1/2"X 2-7/8"LNR H 9110' —13.70"DEPLOYMENT SLV,D=3.00" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, H 9140' 9127' —14-1/2"MILL XN NIP,D=3.80" .0152 bpf,D=3.958" l H3-1/2"HES X NIP, ID=2.813" 9-5/8"CSG,47#,L-80,ID=8.681" --I 9318' ` 9140' —14-1/2"1NL EG,U=3.958" MLLOUT WINDOW(11-12A) 12086'-12096' TOC to 11,500' MD ,////// T -fog 3-1/2"LNR, #, 13Cr TH511, H 12186' //` //,/ 12186' 3-1/2"X 2-7/8"XO,D=__ .0087 bpf,ID=2.992" / i 1, 7"BKR DELTA WHIPSTOCK(12/12/15) —1 12086' / PERFORATION SUMMARY V \ REF LOG: on / / I ANGLE AT TOP PERF: °@ ,� I H 2-7/8"MARKER JT Note:Refer to Production DB for historical pert data \_. 112-7/8" %�/ w/RA TAG SIZE SPF INTERVAL Opn/Sqz SHOT SQZ , I I �... PBTD n ."%. I PBTD —I 12969' l •4••••1 2-7/8"LNR,_#,13-CR STL H 1384' ,•,•,•,••,•i ��••- .0058 bpf,D=2.441" 7"LNR,29#,L-80,.0371 bpf,ID=6.184" — 13032' ,•,•,•,•,•,v DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/15/84 ORIGINAL COMPLETION 01/20/16 J: 11-12A PROPOSED DRAFT WELL: 11-12 07/18/88 LAST WORKOV ER PERMIT No: 1841950 05/03/09 N2ES RWO API No: 50-029-21212-00 08/19/09 MS/JMD DRLG DRAFT CORRECTIONS SEC 33,T11 N,R15E,136'FNL&107'FEL 05/06/15 JCM/PJC SET IBP/CLOSE PERFS 11/24/15 RJK/JMD GLV C!O(11/21/15) BP Exploration(Alaska) 0 L \ f 1 i o > . 0 1 eui u ' if: . : _ r' � � mm..f ms • A, 14 i 1- --.1I11III -rrr-- • I Irmo \�\'1►\� z I- I 16! 1i 4 wAl z r.. ' I K i S ire I 2 _ C I < Y Y s 1 gJ I C9 03 I} QI 0 •� 1d a I CU I .. I O 1 ti z lC I .. 1 Q ° 1 1 1 . 2 Z I I O I I r� I ill,. I e �" I 1 es.� I J i s eas a° $1 I I (� i s _rI 1-- , ,\ •a .R 1 (j a 1 i 1 \ V 1 ,_I - 014, x \ r°• *k VIlia* .Y zN Ilt _ II LLI" s =S2• : i .� vv r." 2 u i; 1 2 ge ',T. W \ a a V g i e � s e O \ 1 N» a _ i i i V \ h- V . \\3 imi 5! U 3 „� e i I l x _ i = e V a I �� a xw• .. . .0 tsi 1 � oo g In L� - '' _ -i�l I � ��„ ,I 1 I I z .l 1 Z e e 1 R Ixl ,j a U' $ I 1 11 U x3 s s R I id l S• u C1 x ✓ i _ v . .. u 1 1 1 1 .I I d i I x n • • r 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 GeologistAb ✓/ in the upper left corner of Form 10-403 is checked. If the "Abandon" or / "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work)the initial reviewer will cross out that erroneous entry and initial then/2> it on both copies of the Form 10-403 (AOGCC's and operator's copies). ,/ Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. \%L.. O 5 Gyrodata Incorporated gyroldata 23000 Northwest Lake Dr. Houston, Texas 77095 Precision Wellbore Placement T: (281) 213-6300 • F: (281) 213-6301 JUN f4' 8 n16 SCPOW SURVEY REPORT BP Exploration Drill Site: 11 #11-12 Wellhead Prudhoe Bay, North Slope Borough, AK AK1215GCM190 6 December 2015 RIGHT PLACE FIRST TIME SO www.gyrodata.com �_ Gyrodata Incorporated gyro/data23000 Northwest Lake Dr. Houston,Texas 77095 Precision Wellbore Placement T: (281) 213-6300 • F: (281) 213-6301 December 17, 2015 State of Alaska -AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: Drill Site: 11, Well #11-12 Prudhoe Bay, Alaska Enclosed, please find one (1) copy, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, Kelly Landram Senior Operations Assistant RIGHT PLACE FIRST TIME www.gyrodata.com €501 i 0 O Y (d 0 O o 1-1' +a5 at o o � x a 0E z 3 N 0 6 H o x — o aka U N .> °�' i U a 0 0 caS ° t� U •d U bO A r .0 U o 7 o — — U a) `. U P-4 pa Y C4o O F. c o t o N o W 'v> b `� 0 Q R. d > U x ' Y- 4 0 U H = ° a � z ` O AvCI w F S Q W °� ci °' ' 3cci0 '" o W N ° b!J 0 O QN O M oai d' N H 3 .a P4 ci• ti O az co, VA rn .710 - 0 0 N * O U b O N- N O 00 l\ U Q 030 0 N 'b GJ O Q at E c oO y ^ H n�- . 0 N r Fir 44 N 3333 33333 44W_ 4444 44333 p r CN d: u, l: ll: 't: N CD 't 4 O M ON M 7r 1 c ,--i W O + 000 0 00000 00000 OOvi Q z ¢ 3 �' z 3 P4c c`-' Z O r/1z07D toon070non in UP CA 000 00cno) o O O O O N 8 O 7+1 C\ N 00 :-.4,;) N � N •-" (O 1,"1-: O1 V• 00 C` 0�r O O cy O O .--� M d: N O1 N N N �O N M M W v O 0000 000 -, .- N N M M V' v5 6v3 M . -. N O C7 N H O -" (O N 4 'n O\ 00 Q1 Cl VD VO O VO ,. d• vs �t vs. vs O EI C Kj .-. 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O • o C 12 0 ; X _=. d-+ ' ill zI ' I 1 I I I ' i , I I 1 I l l I I I I I I I I I l ! � I I I _O 0- O CO to [r N 0 00 l0 Tr N 0 CO J .-1 1--1 1-1 .-1 ,--1 (1400I/bap) klll A3S JD1sOa Survey QC - RGS-CT Continuous Specification Sheet gY - a 1 SURVEY QUALI I Y CONTROL- SPECIFICATION DATA PRE-30B CALIBRATION VERIFICATION (ROLL TEST System Parameter dGx dGy dmbo Mean Gravity Error* Stdev Gravity Error Standard Deviation 0.012 0.012 0.012 -0.00025 0.00008 Tolerance 0.033 0.033 0.087 0.00591 0.00720 GYRO VERIFICATION (ADVANCED INITIALISATION) Gyro Compass Parameter Gyro noise dGx dGy dmbo Max corr coef Standard Deviation 0.077 0.008 0.013 0.000 0.07 Tolerance 0.141 0.033 0.033 0.087 0.45 Initialisation inclination standard deviation 0.08 Initialisation azimuth standard deviation 0.35 Initialisation azimuth uncertainty in percent of error model -Tolerance < 100% 0% ACCELEROMETER VERIFICATION (G-TC' y - not applicable for 2 accelerometer systems G-Total Test Parameter Mean Gravity Error Mean Gravity Error Standard Deviation Error 0.00021 0.00003 Tolerance 0.00590 0.02152 CALIBRATION Tool Number F0250 I Calibration Date 10 Mar 2015 OPERATING TEMPERATI. Calibration range From 29.96 To 119.93 Gyro operating range From 37.59 To 68.37 In-Spec if+/- 2.5 °C of Calibration CONTINUOUS DRIFT CORRECTIOC' Linear Drift Uncertainty 0.18 Random Walk Uncertainty 0.04 Tolerance 0.46 Tolerance 0.23 CONTINUOUS MISALIGNMENT CORRECTION Misalignment Parameter dMx dMy Cross corr coef Standard Deviation 0.00 0.00 0.17 Tolerance 0.18 0.18 0.70 DEPTH CONTRO Wireline Company Halliburton Line type 7/32" Encoder SF Gyrodata Max Depth (TD) 11837 CCL Corrected NO Zero Depth (Rig up) RKB @ 58 Ft AMSL Rezero Depth -22.23 Given pup joint depth NA Measured P3 NA Strech cor. At TD divided by TD/1000 .5913 Spec'- 1.5/1000 Dif. Between riqup and rezero depths divided by TD/1000 1.878 Spec'- 2.0/1000 Dif. Between given and meas depth divided by meas/1000 NA Spec'- 2.0/1000 INDIVIDUAL STATION REPORT 0/0 of Total stations accepted Tolerance > 80% 100% Consecutive Interval out of Specification Tolerance < 100 m (300 ft) 0 feet SURVEY RUNNIN Rig up Rig down - Start Inrun Field Survey Presented End outrun Lost Time Comments SURV-Q163 December 2011 Page 1 of 2 Created:14-Dec-15 12:40 AK1215GCM190 Survey QC - RGS-CT Continuous Specification Sheet gym/data ACCEPTANCE SUMMARY Accept NAME AND DATE Yes/ No Pre-job calibration verification (roll test) YE. Click here to enter text. Gyro Verification (Advanced Initialisation) YES Accelerometer verification (G-Total Test) YES Operating temperature within calibration range (+/- 2.5°) YES SIGNATURE Continuous Drift Correction YES Click here to enter text. Continuous Misalignment Correction YES Depth Control YES Individual Station Report YES Note : Any modifications or amendments to this sheet must be reported to the client representative and the Gyrodata survey focal point. SURV-Q163 December 2011 Page 2 of 2 Created:14-Dec-15 12:40 AK1215GCM190 STATE OF ALASKA ;KA OIL AND GAS CONSERVATION COMA. JON REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon L] Plug Perforations H Fracture Stimulate Ll Pull Tubing LJ Operations shutdown ❑ Performed. Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program E , Plug for Rednll ❑ Perforate New Pool Repair Well ❑ Re-enter Susp Well ❑ Other C i5? t ..- 2 Operator 4 Well Class Before Work 5 Permit to Drill Number BP Exploration(Alaska),Inc Name Development 0 Exploratory❑ 184-195-0 3 Address. P O Box 196612 Stratigraphic ❑ Service❑ 6.API Number Anchorage,AK 99519-6612 50-029-21212-00-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028328 PBU 11-12 9 Logs(List logs and submit electronic and pnnted data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary: Total Depth measured 13032 feet Plugs measured 12358 feet E .3 true vertical 9175 83 feet Junk measured None feet 15 JUN 0 9 2015 Effective Depth measured 12358 feet Packer measured 11870 86 feet true vertical 8773 31 feet true vertical 8440 83 feet AOG CC Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 81 20"91 5#H-40 29 19-110 29 19-110 1490 470 Surface 2500.31 13-3/8"72#L-80 28 69-2529 28.69-2504 54 4930 2670 Intermediate 9291 31 9-5/8"47#L-80 26 69-9318 26 69-6793 97 6870 4760 Production None None None None None None Liner 4903 96 7"29#L-80 9028 04-13932 6635 63-9683 4 8160 7020 Perforation depth Measured depth 12227-12233 feet 12440-12470 feet 12506-12528 feet 12562-12574 feet 12626-12656 feet 12674-12682 feet 12682-12684 feet 12700-12806 feet True Vertical depth 8686 62-8690 66 feet 8826 27-8845 25 feet 8867 7-8881 29 feet 8902 17-8909 5 feet 8941 05-8959 16 feet 8969 99-8974 8 feet 8974 8-8976 feet 8985 6-9047 83 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) 3-1/2"Baker FB-1 Packer 11870 86 8440 83 Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) SCANNED JUL 0 9 2015 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 65 9000 8296 1790 862 Subsequent to operation 447 26823 12 1215 871 14.Attachments 15 Well Class after work Copies of Logs and Surveys Run ❑ Exploratory 0 Development El Service 0 Stratigraphic ❑ Daily Report of Well Operations 0 16 Well Status after work Oil 0 Gas ❑ WDSPL 0 Pnnted and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Garry Catron Email Garry.Catron@BP.Com Pnnted Name Garry Catron Title PDC PE Signature lire Phone 564-4424 Date 6/9/2015 V rL 6/49//5- RBDMS JUN 1 1 2015 Form 10-404 Revised 10/2012 Submit Onginal Only -i -� Cl) r Z C) C C C Z -1 O Z Z m C 0 OG) n mnvi m y 0m' m W 00 N A CO O 00 01 CO N 00 = 01 CO 0 0 CD -• • W O A — — Ce3 cin Ca Cid cD O CO j co- CO N N GJ v N V Cn N ra0r = RQ 0 0 w co o o � _ CO cy7 CO N) N CD N N) (p OACON -.ICO 01 D Co —. rh I I . v n co NW O co CO CT W W O O N co O CD 7 0) O) Cn N 0) N N • N co W co Co co 41. al ▪ CO W CO CO 0 000) Nco O) CTI CT! 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ACTUATOR= BAKER C `""5-1/2"&4-1/2"CHROME TBG&NIPPLES"" KB.ELEV= 58' I KOP 2000 FIs 1764'7-9-5/8"HES ES CEMENTER Max Angle= 57° 9200' #CONDUCTOR ? Datum MD= 12490 —# 1787' H 9-5/8"BKR ECP,D=8.835" Datum TVD= 8800'SS D= 9-5/8"CSG,47#,L-80 HYD 563,D=8.835' - 1755' 2183' 5-1/2"HES X NP 13=4.562" 9-5/8"BOWEN CSG PATCH,D=10.750" —{ 1819' -1823' 9-5/8"CSG,47#, L-80 BTC,D=8.835" H 1823' GAS LFT MANDRELS 13-3/8"CSG,72#,L-80,D=12.347" — 2529' ST MD TVD DEV TYPE VLV LATCH FORT DATE 4 3399 3244 41 MGM DONE RKP 16 05/18/09 Minimum ID = 3.725" @ 9127' 3 5837 4791 52 MMG-M DMY RK 0 05/03/09 2 7548 5801 56 I G-M SO RK 20 05/18/09 4-1/2" HES XN NIPPLE 1 8892 6561 57 MMG-M DAY RK 0 05/03/09 9-5/8"CSG (PER RWO REPORT'S — ^-4975' / L 04/09)SEE SAFE rY NOTES 5-1/2'TBG,17#,13CR-80 VAM TOP HC, 8960' 8960' --I5-1/2"X 4-1/2"XO,D=3.958" .0232 bpf,ID=4.892" TOP OF r LM H 9029' ' 9032' —14-1/2"HES X NPP,D=3.813" 9063' —17-x4-1/2.•BKR S-3 FKR,13=3.870" ' 9096' —I4-1/2"HES Xr4?D=3.813" 4-1/2"TBG, 12.6#,13CFt 80 VAM TOP, — 9140' ' 912T —14-1/2"INS XN NP,D=3.725" .0152 bpf,ID=3.958" 9-5/8"fS(;,47#,L-80,D=8.681" H 9318' • 9140' —I 4-1/7 WLEG,D=3.958" PBRFORAT1ON SUMMARY REF LOG:BHCS ON 12/02/84 ANGLE AT TOP F :47"Q 12227' Note:Refer b Abduction DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SOZ 2-112" 4 19997-12233 0 11/09/93 12358' —3-3/8'BKR 061'(05/06/15) 2-5/8" 0.1 12440-12470 C 09/17/88 2" 0.25 12506-12528 C 07/23/89 2-1/8" 0 12562-12574 C 10/07/85 2-1/8" 0 12626-12656 C 10/07/85 2-1/8" 0 12674-12684 C 10/07/85 2-1/8" 0 12682-12684 C 10/07/85 2-1/8" 0 12700-12806 C 09/17/88 PBTD •- 12969' I •••••• i Ln 7— C wtnw `[C^nl 0 vNt0 :a9ulL[J W �c >/ X � LQ pO. 0 C v O Z on > O a - O E II O. u vI > C y Q O O O tL -0 O O 1111 a Q Q u. _' u y v E s m w Q < 2 < 22 < < n n wa v Z a M N �O M O N > U y v > , Y N O ❑ O ❑ ❑ ❑ ❑ ❑ ❑ u s s o J J J J J J J J J (O v u el W W W W W W WWW pOp O i� 0 .-+ LL LL LL LL LL LL LL LL LL N E -O N c al O Q Q Q Q Q Q Q Q Q co. O C O : Z Z Z Z Z Z Z Z Z u co aj G) u - LL LL LL LL LL LL LL LL LL 4J ^ ,� U 41 14 - 0 E ca v > Y OV _ Q O 0 E Q1 0) O U m Z C O _a sa al v O v Q 8 a N Q1 Q) ,-L'- '.." - C) V ~ J J F_ Q a) C c n3 OU > U N i.. G 0 0 =, O O u O 2 2 u cp - N J W J G a tfW NVou tm XX 11'J PI 4) m n U co w C x p Z Iw 0 } } } 2 S m 5 d J >J >J O >J >J O O -I F1 F+ 2 co N > > W > > W W ? w 2 E2 At-pill / It w d >, > >, >, >, >. > 2Zammmmmom c Z 0 V O O O O O O O 3 0 m t L L L L L .0 W C 7 7 3 -7 7 7 7 ,_ V �+- J a a a a a a a a o O '1/4# _ . T N C� b..° a UJ CO M O COID COaO N V COO X V1 O - , ) N N N N N N N O U) V 0 O O N 0 0 N 0 e• O W 0 0 0 0 0 0 0 0 0 RI_ 0 0 0 0 0 0 0 0 .ro Q V C 0 u 2 C u Z 0 E �/ 7 N > C N CO> N } O 9' " - W 000000000 c Cl) CO X p O O O N 0 0 N e' 0 V ID 0 0 0 0 0 0 0 0 0 o N 00 O O O N 00 0 CM a C E f,1 In 0 Tr CO N N CO IA IA .b O N M N N 0 0 0 M 0 N NINANNNNNNN F.- O T T 07 0 0 6 O) O) 0 _0 N N N N N N N N N Q1 O O O O O O O O O W O O O O O O O O O c_ co to to to to co IA co in r-. O Q1 CC ce L co c a V C a n. E cu u > U� Cl) CC CC _ iCsi ,r E A e' Q Ic, M O) `�' e m Q N M E a Y • • • csi • • N r w 41 H iep �_ d Q N J LL e- (� o Tr d N a) ra e� � 3 t - IA ect Well History File' Cover~.ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. _L/ ~¢' ~2/- j ¢.~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: O Diskettes, No, [] Maps: [] Grayscale items: [3 Other, No/Type [] Other. items scannable by large scanner [] Poor Quality Originals: ..~ OVERSIZED (Non-Scannable) [] Other: ~ , NOTES: [] : Logs of various kinds [] Other BY: ~ BRE" VINCENT SHERYL MARIA LOWELL DATE: ~"'Z.~ IS/ Project Proofing BY: BEVERLY BREN(~SHERYL Scanning Preparation MARIA LOWELL · x BY: BEVERLY BREN~SHERYL Production Scanning Stage I MARIA LOWELL BY: ~ BREN VINCENT SHERYL MARIA LOWELL Stage 2 IF NO IN STAGE.l, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: BEVERLY BREN VINCE~RIA LOWELL (~N~G ~ COMPLETE AT THIS ~ UN~ SPEC~ A~NT~N ~ REQUIRED ~ ~ ~DN~UAL PAGE ~E TO QU~, ~Y~ ~ C~OR i ReScanned (individual page [special attention] scanning completed) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ISl General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wp<:l 01/20/11 Schiumberger NO. 5676 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambea Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503.2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 14-43 BGZ7 -00010 CROSSFLOW CHECK ' ' _. / y 11/13110 1 _• 1 NGI -14 AN/ill-00052 Irrallffl ; rl aSi all.IIMIMIII. !� Z.r 1 L-205 BL000 MEM PL 11 i -- US. 11/01/1 1 , . j 1 1 A-42A BL65-00012 MEM PRODUCTION PROFILE d a j`� / 0 01/06/17 1 1 r!a. i 1 01 -30 BCZ2 -00031 INJECTION PROFILE _) 2 (.� rd - ) 1 1 12/03/10 1 1 _ 02.20 BBSK -00040 RST — 11/19110 1 •1 1 07 -238 AY1 M -00056 T1i�L ' ritt r "' 1 K -11A B088 -00073 MCNL — 1_ 11/03/10 1 _ ♦ 4 o 1 04 -24 AYIM -00058 RST )-.C) 12/05/70 1 .0(. 1 11 -12 BCZ2 -00033 RST f -- g t<j ' 12/07/10 1 0 • - 1 74 2- 288/0 -19 BCRJ -00055 RST • ♦ -�( (� 12/01/10 _ 1 _ � 1 S -128 BCZ2 -00035 USIT —) 01/02/11 . 06, r • 7 1 W -220 BG4H -00025 USIT — 72/27/10 •� 1 1 S-41A 10AKA0108 OH MWD WO EDIT _] FtTMM 1 S -41AL1 IOAKAO10e del 8'Yn 7Ia ^1.7�Bi - r, , 7-7 1 H -11 BGZ7 -00014 RST / 'NU — their 12118/10 1 _ • 1 0`t —n - - AO fr"s I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 i MAP 1. .ti t+ • • 0 .S.----- rArr tat , F ); if a y e I ,` , _ . pr I f , r9 12/30/10 Schkunberger NO. 5672 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503.2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Y 6 Anchorage, AK 99501 Job it Log Description Date BL Color CD E -05= BL65-00011 MEM DDL 12/18/10 1 1 �r AY1 M -00056 • ' e r • - . IP Ai- - 11127/10 1 a . 4N 1 BCZ2 -00033 • LJ:I.Alti3e7di ;r-f/E/Lje _QWit - � ill1111_— BG4H -00022 INJECTION PROFILE ajwr - 0•jjL-�ro.gmm-- AY1M -00058 PROD PROFILE ♦ — IIIMBICIII0MIIIM111■— B - 00077 - kewxL _ mnmri0)a -- BCZ2 -00030 wd 0 BCRJ- 000566 I! !i44R.a.a. i M',T INIIIIIIIIIIMEMO IViO -- r BBSK -00043 II21X1i1.l.l d.ltlle3 jiiMIL'/!'iFKM'MEZIELCII04 5M. - - -- 04-10 INJECTION PROFILE V t 1- • _ r 111.1111.111.1111.1. 2-2813/0-19 BCRJ-00055 15-26B r : 5 MEM PROD PROFILE , 7 , - • ® ®V.„. • • - PROD PROFILE • • • _ i i 0 0 t : SCMT _ - -/ ' i *of • 1 1 000 SCMT at�d -� [_9 •. 1 SCMT J (' --- r e 4 , 1 ' 000 '• SCMT fi5,,, — i i P2-16 B5JN-00077 / 05-27B BAUJ-00049 : 1 ■ QS ' . � -- 16-06B RST _ • - 1 ± ,.? si0 — 0 RST 09/2W10 cr ++ 00 MCNL — 1 �' ' "' CH EDIT PD-GR USIT � • ' ' �t'� a - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 S IN MAR 1 4 2.D' • • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 21, 2010 E NE , AN 4' 2011 tw o' Mr. Tom Maunder ", .: 4v Alaska Oil and Gas Conservation Commission 333 West 7 Avenue ° = `I ` '' �I� Anchorage, Alaska 99501 purls.',:, 4sion Subject: Corrosion Inhibitor Treatments of GPB DS 11 4tje Dear Mr. Maunder, 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 1 921 12 0 50029206440100 NA _ Sealed NA NA 6/25/2010 11 -02 1811280 50029206490000 NA Sealed NA NA 6/25/2010 11 -03A 1 911 520 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 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 STATE OF ALASKA A~ OIL AND GAS CONSERVATION COM SSION REPORT OF SUNDRY WELL OPERATIONS ~ s~o~ ~A~l ~ :~. 2Q05 1~18Sk6 ®IP ~tt ~~~ C~~~~_ C;nrnrr~i~s'sa~r~ Form 10-404 Revised 04/2006 1. Operations Performed: ~.~~„!~,; , ~~ ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing ~ ®Pull Tubing . ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. -® Development ^ Exploratory 184-195 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21212-00-00 - 7. KB Elevation (ft): 58, 9. Well Name and Number: PBU 11-12' 8. Property Designation: 10. Field /Pool(s): _ ADL 028325 & 028328 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 13032' feet true vertical 9176' , feet Plugs (measured) None Effective depth: measured 12969' feet Junk (measured) None true vertical 9140' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 2529' 13-3/8" 2529' 2505' 4930 2670 Intermediate 9318' 9-5/8" 9318' 6794' 6870 4760 Production Liner 4003' 7" 9029' - 13032' 6636' - 9176' 8160 7020 ~.~6r+~~wiG.o+~ t t t ~ ~7 ~ ~ ~J J Perforation Depth MD (ft): 12227' - 12806' Perforation Depth TVD (ft): 8687' - 9048' 5-1 /2", 17# x 4-1 /2", 12.6# 13Cr80 9140' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker'S-3' packer 9063' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 11770'. Cut and pull 9-5/8" cas ing from 1820'. Run 9-5/8" tieback to 1823' and cement w/ 126 Bbls Class 'G' field 1.17. Run new Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram -® Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mark Staudinger, 564-5733 309-093 Printed Name Terrie Hubble Title Drilling Technologist Signature ~ Prepared By Name/Number: Phone 564-4628 Date ~ '~~ Terrie Hubble 564-4628 .. „ . i~~Y` ~ ~ L~~,i~ Submit Original Only • • 11-12, Well History (Pre Rig Workover) Date Summary 03/24/09 T/I/O =SSV/130/0+. Temp = SI. Monitor for cellar liner (pre RST). No AL, flowline, scaffold or wellhouse. No cellar liner. Cellar is 7x7 wooden box (it is 3' below grade). SV, WV = ?SSV = C. MV = O. IA, OA = OTG. NOVP. 03/27/09 T/I/O =SSV/130/0+. Temp = SI. Monitor cellar for liner installation. Well house and flowline have been removed, drilling scaffolding on well. Liner in cellar is dry and aooears to be rurPrl_ SV, WV, SSV =Closed. MV =Open. IA & OA = OTG. NOVP. 03/28/09 T/I/O = 50/130/0+. Temp = SI. TBG & IA FL (FB). TBG FL @ surface. IA FL C~ 220' (10 bbls). Slick line currently on well. 03/28/09 WELL S/I ON ARRIVAL. RAN 2.80" CENT. & 2.50" LIB TAGGED IBP Q 11,877' SLM. (GOOD IMPRESSION OF FISHING NECK). LEFT WELL S/I NOTIFY DSO. 03/29/09 T/I/0=140/140/10 CMIT TxIA to 3500 psi. 03/30/09 CMIT TxIA PASSED to 3500 psi. (Pre RWO) Pumped 27.2 bbls crude down IA while maintaining open bleed on OA to reach test pressure for CMIT TxIA. T/IA lost 60/60 psi in the 1st 15 mins and 20/20 psi in the 2nd 15 mins for a total pressure loss of 80/80 psi in 30 mins. Bled back (--17bbls). FWHP's = 140/140/0. DSO Notified of valve positions: Swab, Wing, SSV shut. Master, IA & OA open. 03/31/09 WELL SHUT-IN ON ARRIVAL. (E-LINE TUBING JET CUT). INITIAL T/IA/OA: 200/200/0. RIH WITH 2.5" JET CUTTER. TIED INTO TUBING TALLY DATED 18-JUL-1988. TAGGED TD EARLY AT 11806' (EXPECTED IBP AT 11860'). CUT 3-1/2" TUBING AT 11770'. FINAL T/IA/OA; 100/140/0. DSO NOTIFIED OF VALVE POSISTIONS ON DEPARTURE. WELL LEFT SHUT-IN. JOB COMPLETE. 04/08/09 T/IA/OA= SSV/0/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T RU 2 HP BT onto THA test void 0 psi, flushed void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 4950/ 30 minutes. Bled void to 0 psi, RD test equipment. Cycled and torqued "Standard" all were in good working condition 2PPPOT-IC RU 2 HP BT onto IC test void 0 psi. flushed void until clean returns achieved. Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled void to 0 psi, RD test equipment. Cycle and torqued LDS "Standard" all were in good working condition. "~" A!I LDS ran out 1.5" ran in and then torqued. 04/09/09 T/I/0=120/120/0 Circ-Out Well CMIT TxIA PASSED to 1000 psi (RWO Prep) Pumped into the Tbg with a 5 bbl neat methanol spear followed by 1344 bbls of Seawater and capped with 135 bbls of 100° diesel for freeze protect. U-Tube diesel into IA. Pumped 2.2 bbls of diesel into the Tbg to CMIT TxIA. CMIT lost 40/40 psi in the 1st 15 min and 20/20 psi in the 2nd 15 min for a total loss of 60/60 psi in the 30 min test. Bled TxIAP back down. Final WHP's = 0/0/0. Valve positions at the time of departure: Swab, Wing, SSV =Closed /Master, IA, OA =Open. 04/11/09 T/I/O =Vac/0/0 Set 5-1/8" FMC IS-A BPV # 537 thru tree 1-2' ext. used, tag Q 90", pre-rig, no problems. Page 1 of 1 • BP EXPLORATION Page 1 of 15 ~, Operations Summary Report Legal Well Name: 11-12 Common Well Name: 11-12 Spud Date: 11/16/1984 Event Name: REENTER+COMPLETE Start: 4/13/2009 End: 5/4/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/4/2009 Rig Name: NABORS 2ES Rig Number: Date. ', From - To Hours ' Task ', Code NPT Phase Description of Operations 4/13/2009 18:00 - 00:00 6.00 MOB P PRE Start moving rig camp, shops, and sub from X-pad to DS-11. 4/14/2009 00:00 - 12:00 12.00 MOB P PRE Finish moving camp, and shops from X-pad to DS-11. Continue to move sub from X-pad to DS-11. 12:00 - 18:00 6.00 MOB P PRE Finish moving sub to DS-11. 18:00 - 21:00 I 3.00 RIGU P PRE MIRU Nabors 2ES. 21:00 - 00:00 4/15/2009 00:00 - 02:00 02:00 - 03:30 03:30 - 05:30 05:30 - 09:00 09:00 - 10:00 10:00 - 11:00 11:00 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 16:30 16:30 - 19:30 19:30 - 00:00 3.00 WHSUR P 2.00 WHSUR P 1.50 WHSUR P 2.00 WHSUR P 3.50 WHSUR P 1.00 WHSUR P 1.00 WHSUR N 1.00 WHSUR P 1.00 WHSUR N 1.00 WHSUR P 2.50 WHSUR P 3.00 BOPSU P Rig accept at 21:00. DECOMP U LRS for CMIT-TxIA. RU 2" bleed line from 13-3/8" x 9-5/8" annulus to cuttings tank. Off-load seawater to pits. DECOMP Finish RU LRS and 2" OA bleed line. PJSM for CMIT. DECOMP Pressure test equipment to 4000 psi for CMIT-TxIA, good test. Pum 10.3 bbls down IA to ressure u to 3500 si, 2.5 bbls used to fill void. 1st 15 min -lost 65 psi, 2nd 15 min -lost 10 psi. Good test. RD LRS. DECOMP RU DSM and pull BPV. RD DSM. DECOMP RU lines and circulate diesel freeze protect from well. DECOMP Attem t to install BPV with T-bar. Well out of balance. WAIT DECOMP Wait for DSM. DECOMP RU DSM. Install BPV and test for 8 minutes at 1000 psi,- leakino past BPV. SFAL DECOMP Pull BPV and set a new BPV. DECOMP Test BPV for 10 minutes at 1000 si - ood test. RD DSM. DECOMP ND Tree and install blanking plug into tubing hanger. DECOMP NU BOPE and function rams. Fill the stack, flush lines and prepare for BOPE testing. DECOMP Start testing BOPE with 3-1/2" test joint to 250 psi low / 3500 psi high. Test annular preventer with 3-1/2" test joint only to to 250 psi low / 2500 psi high. 4.501 BOPSUR P 4/16/2009 100:00 - 01:00 I 1.001 BOPSUR P 01:00 - 02:30 1.50 BOPSUFj N 02:30 - 03:30 1.00 BOPSU~j P 03:30 - 04:00 0.50 BOPSU P 04:00 - 05:30 1.50 BOPSU P 05:30 - 06:00 0.50 PULL P 06:00 - 07:00 1.00 PULL P 07:00 - 08:00 1,00 PULL P 08:00 - 11:30 3.50 PULL P 11:30 - 12:00 0.50 PULL P 12:00 - 21:00 9.00 PULL P 21:00 - 21:30 1 0.501 PULL I P AOGCC test witness waived by John Crisp. Test witnessed by BP WSL Travis Peltier and NAD Toolpusher John Castle. DECOMP Continue testing BOPE with 3-1/2" test joint. Pull 3-1/2" test joint from ROPE with blanking plug attached. HMAN DECOMP Re-install blanking plug in tubing hanger. DECOMP Test BOPE with 5-1/2" test joint to 250 psi low / 3500 psi high. All BOPE tests pass. AOGCC test witness waived by John Crisp. Test witnessed by BP WSL Travis Peltier and NAD Toolpusher John Castle. DECOMP LD BOPE testing equipment. DECOMP RU DSM and pull BPV. RD DSM. Monitor well. DECOMP RU to pull tubing. DECOMP BOLDS and pull hanger free at 160k. Pipe free at 1 SOk. DECOMP Circulate surface to surface sweep. 510 gpm at 320 psi. DECOMP Pull 5-1/2" x 3-1/2" completion from 11,770' to 9585'. Recover BAL-O SSSV and 55 of 57 stainless steel bands. DECOMP LD control liner spooler. DECOMP Continue to LD tubing. With 129 _its_ out of hole and no overpulls, lose 15k string weight. Recover 217 joints of 5-1/2" tubing, 15 joints of 3-1/2" tubing, and the top pup above GLM #4 (1st GLM in the 3-1/2" tubing). DECOMP RD tubing handling equipment. Clean and clear rig floor. Printed: 5/11/2009 10:34:02 AM • BP EXPLORATION Page 2 of 15 Operations Summary Report Legal Well Name: 11-12 Common Well Name: 11-12 Spud Date: 11/16/1984 Event Name: REENTER+COMPLETE Start: 4/13/2009 End: 5/4/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/4/2009 Rig Name: NABORS 2ES Rig Number: Date I From - To Hours ' Task ', Code, NPT Phase Description of Operations 4/16/2009 21:30 - 00:00 2.50 BOPSU P DECOMP MU 4" and 3-1/2" test joints to test lower pipe rams in BOPE. Attempt to test 4" -fluid leaking from test port fitting on tubing spool. Replace fi#ting and continue test. Good Test 4/17/2009 00:00 - 00:30 0.50 BOPSU P DECOMP Finish testing lower pipe rams with 4" and 3-1/2" test joints. All tests pass. RD BOPE testing equipment. 00:30 - 02:00 1.50 FISH P DECOMP MU BHA #1 (tubing fishingi Itco type 3-1/2" spear, bumper sub, jars, DC's, pump out sub) to 311'. 02:00 - 11:30 9.50 FISH P DECOMP RIH with drillpipe singles from 311' to 9395'. PU - 140k, SO - 115k. 11:30 - 12:00 0.50 FISH P DECOMP RIH to 9415' and taa fish. Attempt to enaaae fish -fail. Pumping at 3 bpm, 450 psi. 12:00 - 16:00 4.00 FISH P DECOMP POH from 9415' to 311'. 16:00 - 17:00 1.00 FISH P DECOMP LD tubing fishing BHA (BHA #1). 17:00 - 18:00 1.00 FISH P DECOMP MU BHA #2 (tubing fishing, 12' Itco type 3-1/2" spear, bumper sub, jars, DC's, pump out sub) to 317'. 18:00 - 20:30 2.50 FISH P DECOMP RIH from 317' to 9349'. PU - 140k, SO - 110k. 20:30 - 21:00 0.50 FISH P DECOMP Wash down to 9415' at 2 bpm, 520 psi. Engage fish -good indication of latch. PU - 165k, SO - 115k. Open pump out sub. 21:00 - 00:00 3.00 FISH P DECOMP POH from 9415' to 2385'. 4/18/2009 00:00 - 01:00 1.00 FISH P DECOMP POH from 2385' to 317'. 01:00 - 02:30 1.50 FISH P DECOMP LD tubin fishin BHA BHA #2 from 317'. Spear fully inserted into fish w/ grapple in 10' pup joint below parted 3-1/2" GLM. 02:30 - 03:00 0.50 FISH P DECOMP RU to LD 3-1/2" tubing. 03:00 - 06:30 3.50 FISH P DECOMP LD 3-1/2" tubing. Tubing extremely corroded, especially in couplings and GLM's. Recover an additional 73 full joints of 3-1/2" tubing, 5 3-1/2" GLM's + pups, and a 17.33' cut joint of ~ 3-1/2" tubing. Total recovered for well: 5-1/2" Joints - 217 5-1/2" GLM - 3 5-1/2" SSSV - 1 SS Bands - 55 3-1/2" x 5-1/2" XO 3-1/2" full joints - 88 3-1/2" GLM + pups - 5 3-1/2" cut joint - 17.33' long 06:30 - 07:30 1.00 FISH P DECOMP RD tubing handling equipment. 07:30 - 09:30 2.00 CLEAN P DECOMP MU BHA #3 (casing cleanout; 6" flat bottom mill, 9-5/8" casing scraper, bumper sub, jars, DC's) to 248'. 09:30 - 11:00 1.50 CLEAN P DECOMP RIH from 248' to 5018'. Encounter tight spot. PU - 105k, SO - 90k. 11:00 - 11:30 0.50 CLEAN P DECOMP Work ti ht s of from 5018' to 5230'. 10k - 15k overpult, slack off both ways to get through. PU - 120k, SO - 75k. Worked section 5 times. 11:30 - 13:30 2.00 CLEAN P DECOMP RIH from 5230' and tag liner at 9023'. Wash down to 9059'. 13:30 - 14:30 1.00 CLEAN P DECOMP CBU at 550 gpm, 2370 psi. RPM - 40, TO - 4k. PU - 140k, SO - 115k, ROT - 125k. 14:30 - 16:00 1.50 CLEAN P DECOMP Slip and cut drilling line. Service top drive, drawworks and crown. Printed: 5/11/2009 10:34:02 AM ~ i BP EXPLORATION Page 3 of 15 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: ~ From - To 11-12 11-12 REENTE NABOB NABOB Hours R+COM S ALAS S 2ES ' Task PLET KA DRI ~, Code E LLING NPT Start I Rig Rig Phase Spud Date: 11/16/1984 : 4/13/2009 End: 5/4/2009 Release: 5/4/2009 Number: Description of Operations 4/18/2009 16:00 - 19:30 3.50 CLEAN P DECOMP POH from 9059' to 248'. 10k - 15k overpull required to pass from 5230' to 5018'. 19:30 - 20:30 1.00 CLEAN P DECOMP LD casin cleanout BHA BHA #3 . 20:30 - 22:00 1.50 CLEAN P DECOMP RU SLB E-line. 22:00 - 00:00 2.00 CLEAN P DECOMP E-line: RIH with USIT/GR/CCL. RIH to 4958' and tag obstruction, pull tight. Overpull and come free. PU to 4900' and begin logging. 4/19/2009 00:00 - 01:30 1.50 CLEAN P DECOMP E-line: Finish logging USIT/GR/CCL from 4900' to surface. 01:30 - 02:30 1.00 CLEAN P DECOMP RD SLB E-line. 02:30 - 03:00 0.50 CLEAN P DECOMP RU and perform casing pressure test to 3500 psi for 10 minutes -good test. Lost 5 si in 10 minutes. 03:00 - 05:00 2.00 CLEAN P DECOMP MU BHA #4 Hole o enin ; 8.25" Swage, jars, bumper sub, accelerator, DC's) to 319'. 05:00 - 07:00 2.00 CLEAN P DECOMP RIH from 318' to 4978'. PU - 105k, SO - 90k. 07:00 - 08:00 1.00 CLEAN P DECOMP Work thru tight spots in casing. 10k over both ways from 4978' to 5100'. 20k over both ways from 5100' to 5230'. 10k over both ways from 5230' to 5275'. 08:00 - 09:00 1.00 CLEAN P DECOMP Circulate a hi-vis sweep C~ 500gpm, 1150 psi from 5308'. 09:00 - 11:00 2.00 CLEAN P DECOMP RIH 1 std to 5401'. POH from 5401' to 319'. 11:00 - 12:00 1.00 CLEAN P DECOMP LD hole opening BHA (BHA #4) from 319'. Pressure test casin to 3500 si or 5 minutes - ood test. 12:00 - 13:00 1.00 CLEAN P DECOMP MU BHA #5 (Hole opening; 8.375" swage, jars, bumper sub, acce erator, DC's) to 322'. 13:00 - 15:00 2.00 CLEAN P DECOMP RIH from 322' to 4974'. PU - 110k, SO - 90k. 15:00 - 16:00 1.00 CLEAN P DECOMP Work thru ti ht s ots in casin .From 4975' to 4984', pass with 20k to 25k SO and 15k to 20k overpull. From 4984' to 5284', pass with 5k to 10k SO and 10k to 15k overpull. 16:00 - 17:00 1.00 CLEAN P DECOMP RIH to 5304' and CBU at 550 gpm, 1300 psi. Pressure test casin to 3500 si for 5 minutes - ood test. 17:00 - 19:00 2.00 CLEAN P DECOMP POH from 5304' to 302'. 19:00 - 20:30 1.50 CLEAN P DECOMP LD hole o enin BHA BHA #5 from 322'. Clean and clear rig floor. 20:30 - 21:30 1.00 DHB P DECOMP MU RBP and running tool to 54'. 21:30 - 22:00 0.50 DHB P DECOMP RIH from 54' to 1935'. 22:00 - 22:30 0.50 DHB P DECOMP Set RBP. When setting RBP on PU, RBP slid up to 1933'. ~ Re-verif RBP set - ood set. 22:30 - 23:00 0.50 DHB P DECOMP PU to 1924' and attempt to pressure test RBP to 1000 psi for 1 V IIIII IULI:J ^' 1 V JLRJ UtIII:UI[IICU 1 QRC .7/ Jl1URCJ LV ICJJUIC up to 1000 psi, RBP failed to hold an ressure. 23:00 - 00:00 1.00 DHB P DECOMP Unlatch RBP and move to 1940'. Set RBP. When setting RBP on PU, RBP slid up to 1939'. Verify RBP set -good set. 4/20/2009 00:00 - 00:30 0.50 DHB P DECOMP PU to 1924' and ressure test RBP to 1000 si for 10 minutes (-10 stks calculated). Take 12 strokes to pressure up to 1000 psi -goo es . os psi m s minutes, 0 psi in 2nd 5 minutes. PU to 1829' and RU to dump sand on RBP. 00:30 - 04:30 4.00 DHB P DECOMP Dump 2200# 20/40 river sand on RBP, 50' in 9-5/8" casing. 04:30 - 05:30 1.00 CLEAN P DECOMP Displace well from seawater to 9.8 ppg brine. 05:30 - 06:30 1.00 CLEAN P DECOMP Ta sand @ 1 879'. POH from 1879 to surface. LD RBP running tool. 06:30 - 07:00 0.50 CLEAN P DECOMP MU BHA #6 casin cutter) to 76'. 07:00 - 07:30 0.50 CLEAN P DECOMP RIH from 76' to 1766'. PU - 55k, SO - 55k. Printed: 5/11/2009 10:34:02 AM • BP EXPLORATION Page 4 of 15 Operations Summary Report Legal Well Name: 11-12 Common Well Name: 11-12 Spud Date: 11/16/1984 Event Name: REENTER+COMPLETE Start: 4/13/2009 End: 5/4/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/4/2009 Rig Name: NABOBS 2ES Rig Number: Date From - To 'Hours Task Code j NPT ' Phase- Description of Operations 4/20/2009 07:30 - 09:00 1.50 CLEAN P DECOMP Circulate at 3 bpm. SO to locate collars and cut point. Tag collars at 1801' and 1843'. Prepare for cutting. 09:00 - 10:00 1.00 CLEAN P DECOMP Cut casin at 1820'. TO - 4k on, 1 k off. Circulate at 6 bpm, 850 psi. 10:00 - 14:30 4.50 CLEAN P DECOMP RU LRS. Circulate 20 bbls of diesel and line up to take returns to cuttings box. Circulate 80 bbls of hot diesel and let soak for 30 minutes. Circulate out arctic pack at 208 gpm, 2630 psi. Pump 30 bbls Safe Surf - O pill. Bleed lines and monitor well. 14:30 - 15:00 0.50 CLEAN P DECOMP POH from 1820' to 76'. 15:00 - 15:30 0.50 CLEAN P DECOMP LD casing cutter BHA (BHA #6) from 76'. 15:30 - 19:00 3.50 CLEAN P DECOMP Split wellhead from stack at the tubing spool, remove snap ring and bushing. Pull 9-5/8" packoff. Spear the 9-5/8" casing - come free at 100k. Pull emergency slips. 19:00 - 20:30 1.50 CLEAN P DECOMP NU BOPE w/ tubin s ool attached. 20:30 - 21:00 0.50 CLEAN P DECOMP CBU at 500 gpm, 120 psi. 21:00 - 00:00 3.00 CLEAN P DECOMP Pull 9-5/8" casing and spear and LD. POH with 21 joints of 9-5/8". Breakout torque varied between 16k ft-Ibs to 30k ft-Ibs. 4/21/2009 00:00 - 02:00 2.00 CLEAN P DECOMP Continue POH with 9-5/8" casing. Recover 42 full joints, an unexpected triple -connect on Jt. #15 and a 19.07' cut joint. 02:00 - 03:00 1.00 CLEAN P DECOMP RD casing handling equipment. Clean and clear rig floor. 03:00 - 04:00 1.00 CLEAN P DECOMP MU BHA #8 (9-5/8" dressoff asst'; dress-off, boot basket, scraper, float, bumper, DC's) to 125'. 04:00 - 05:00 1.00 CLEAN P DECOMP RIH to from 125' to stub at 1820'. 05:00 - 06:30 1.50 CLEAN P DECOMP Dress-off 9-5/8" casing stub at 1820'. Pump 40 bbls Safe-Surf-O pill followed by 50 bbls 9.8 ppg brine. 06:30 - 07:30 1.00 CLEAN P DECOMP Trip out of the hole from 1827' to 1721'. Make up the RTTS and set 33' below the RKB. 07:30 - 11:00 3.50 CLEAN P DECOMP Nipple down the BOPE and remove the ra lock clam s. Break out the startin head and remove. Move it to the shop for repairs. 11:00 - 14:00 3.00 WHSUR P DECOMP Replace the pack-off and seals in the starting head. Clean up the clamp and well head equipment. 14:00 - 18:00 4.00 WHSUR P DECOMP Install the starting head. Noticed that the casing had creeped up and pulled off the starting head. Re-cut the 9 5/8" with the Wachs utter. 18:00 - 21:00 3.00 WHSUR P DECOMP Re-install the starting head and nipple up the BOPE. 21:00 - 21:30 0.50 WHSUR P DECOMP Test the break to 250 psi low / 35 psi ig oo es . 21:30 - 22:00 0.50 WHSUR P DECOMP Test the starting head from the inside out against the RTTS to 2000 psi for 15 minutes. Good Test 22:00 - 00:00 2.00 CLEAN P DECOMP Trip out the hole racking back the drillpipe and laying down the dress off BHA. 4/22/2009 00:00 - 01:30 1.50 CLEAN P DECOMP Finish laying down the Dress off BHA. 01:30 - 03:30 2.00 CASE P DECOMP Remove Baker fishing tools from the rig floor and rig up and prepare to run casing. 03:30 - 05:30 2.00 CASE P DECOMP Run in the with 9 5/8" Hydril 563 casing. Baker lock the Casing patch, ECP, and ES cementer connections. Torque BTC-M connections to 9,400 ft/Ibs. 05:30 - 10:30 5.00 CASE P DECOMP Run in hole with 9 5/8" Hydril 563 casing to 1,751' md. Average torque was 15,200 fUlbs. Printed: 5/11/2009 10:34:02 AM • • BP EXPLORATION Page 5 of 15 Operations Summary Report Legal Well Name: 11-12 Common Well Name: 11-12 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date From - To II Hours Task Code NPT Spud Date: 11 /16/1984 Start: 4/13/2009 End: 5/4/2009 Rig Release: 5/4/2009 Rig Number: Phase Description of Operations 4/22/2009 05:30 - 10:30 5.00 CASE P DECOMP 115K Up weight. 90K Down weight. 10:30 - 11:30 1.00 CASE P DECOMP Make up and space out. Rig up circulating head. 11:30 - 12:30 1.00 CASE P DECOMP Establish circulation at 2 bpm @ 50 psi. Rotate at 10 RPM with 5K torque while engaging patch over stub. Slack off 30K down weight. Pull 30K. Slack off 50K. Pull 50K. Slack off 50K. Pull 281 K Slack off to 130K. Rig up cement head. Stub located at 1,820' md. 12:30 - 13:30 1.00 CASE P DECOMP Pressure up casing to 1,000 psi for 10 minutes, increasing 13:30 - 15:00 1.50 CASE P D ECOMP 15:00 - 16:00 1.00 CASE P D ECOMP 16:00 - 18:30 2.50 BOPSU P D ECOMP 18:30 - 21:30 3.00 BOPSU P D ECOMP 21:30 - 22:00 0.50 BOPSU P D ECOMP 22:00 - 00:00 2.00 BOPSU P D ECOMP Pressure test to 2,000 psi for 10 minutes. -Good test. Bleed pressure off. Then pressured up to 2,900 psi opening ES Cementer. Displaced well from 9.8 ppg NaCI Brine to hot 8.5 ppg Seawater. Hold PJSM for cementing. Return seawater at 91 degrees. Shut down pumps and turn over to SLB. Pump 5 bbls of water and pressure test lines to 4,000 psi. Pump 126 bbls (567sks) of 15.8 ppg Class G cement with a yield of 1.17 cu. ft. Kick out closing plug with 5 bbls of water. Displace cement with 8.5 ppg seawater via Rig pumps. Plug bumped on strokes (124 bbls). Increase pressure closing ES Cementer. Bleed down pressure and check for flow. - No Flow. Cement in Place at 15:00 hrs. Received 21 bbls of cement back to surface. Rig Down cement head. Flush BOPE stack. Suck down seawater from casing. Nipple down BOPE. Set Emergency slips with 100K on slips_ Rig up Wachs casing cutter and cut 9 5/8" casing. Cut Jt. = 19.07' Nipple Up ROPE. Set 9 5/8" Pack off and tested to 3,800 psi for 15 minutes. - Good test Lay down test tool and Make up test equipment. Set plug. Start testing BOPE Choke, Top Drive, 4" TIW and Dart to 250 psi low / 3500 psi high. Test annular preventer with 4" test joint only to to 250 psi low / 2500 psi high. All good tests. AOGCC waived witness of test by Jeff Jones. Test witnessed by Nabors Tool Pusher Ken Helf, and BP WSL Chris Kobuck, WSLf John Willoughby 4/23/2009 00:00 - 03:30 3.50 BOPSU P DECOMP Test the BOPE. Install test plug and test the Upper and lower rams with the 4" and 5.5" test joints to 250 psi / 3500 psi for 5 minutes and chart. Test the Annular to 250 psi / 2500 psi for 5 minutes and chart, with the 4" test joint. Test all other BOPE to 250 psi / 3500 psi. All tests passed and charted. AOGCC waived witness of test by Jeff Jones. Test witnessed by Nabors Tool Pusher Ken Helf, and BP WSL Chris Kobuck, WSLf John Willoughby 03:30 - 04:00 0.50 CLEAN P DECOMP Clean and clear the floor and prepare to RIH with cement cleanout BHA. Printed: 5/11/2009 10:34:02 AM BP EXPLORATION Operations Summary Report Legal Well Name: 11-12 Common Well Name: 11-12 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date III From - To ' Hours Task Code NPT -__ _ 4/23/2009 104:00 - 05:00 I 1.00 CLEAN P 05:00 - 06:30 I 1.501 CLEAN I P 06:30 - 09:30 3.001 CLEAN P Start: 4/13/2009 Rig Release: 5/4/2009 Rig Number: Page 6 of 15 Spud Date: 11/16/1984 End: 5/4/2009 Phase. i Description of Operations DECOMP Make u the 9 5/8" cement cleanout BHA and single in the hole. BHA consists of: -8.5" Bit -(2) Boot Baskets -Bit Sub -6.25" Bumper Sub -6.25" Oil Jars -(6) Drill Collars -XO DECOMP Picking up drill pipe from 215' and to 1,718' md. Establiish parameters: 65K up weight. 65K down weight. 65K rotating weight. DECOMP Wash down from 1,718' and to 1,762' and tagging top of up cement and tag plug at 1,765' md. Drill ahead to 1,768' 09:30 - 10:30 I 1.001 CLEAN I P 10:30 - 11:00 0.50 CLEAN P 11:00 - 12:00 1.00 CLEAN P 12:00 - 13:00 1.00 CLEAN P 13:00 - 14:00 1.00 CLEAN P 14:00 - 15:30 1.50 CLEAN P 15:30 - 17:00 I 1.501 CLEAN I P 17:00 - 17:30 0.50 CLEAN P 17:30 - 19:30 2.00 CLEAN P 19:30 - 21:00 I 1.501 CLEAN I P and Rotating at 70 RPM with 2K torque on bottom and 1 k torque off bottom. Pumping at 250 gpm with 250 psi. Weight on Bit of 5 - 10K. DECOMP Drilling cement stringers from 1,768' and to 1,879' md. Tag top of sand at 1,879' and dry. Dry drill ahead from 1,879' and to 1,884' md. Turn on pumps and wash down from 1,884' and to 1,895' md. 250 gpm at 250 psi. DECOMP Pump hi-vis sweep surface to surface at 420 gpm with 600 psi. Spot dry job. DECOMP Pull out of hole from 1,895' and to 215' md. Change out handling equipment. DECOMP Stand back drill collars. Empty and lay down boot baskets. DECOMP Pressure test casing to 3,500 psi for 30 minutes. -Good Test. DECOMP Pick up BHA. Reverse circulating Junk Basket. Boot Baskets, Scraper, Drill collars. Run in hole to 1,767' and and set down 10K. DECOMP Wash down from 1,767' and to 1,770' md. Worked thru this area twice. Tagged up at 1,819' and and reamed thru. Washed down to 1,895' and and dry drill to 1,897' md. Wash and Ream down to 1,905' md. 65K up weight. 65K Down weight. 65K rotating weight. 60 RPM at 2-3K torque. 345 gpm at 790 psi. DECOMP Pump hi-vis sweep surface to surface at 420 gpm and 1,090 psi. DECOMP Pull out of hole from 1,905' and to 226' md. Stand back drill collars. Break down Boot baskets, RCJB. Retrieved rubber and small amount of metal. DECOMP Make second run with Reverse circulating Junk baskets BHA and run in hole to 1,905' md. Printed: 5/11/2009 10:34:02 AM • BP EXPLORATION Operations Summary Report Page 7 of 15 Legal Well Name: 11-12 Common Well Name: 11-12 Spud Date: 11/16/1984 Event Name: REENTER+COMPLETE Start: 4/13/2009 End: 5/4/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/4/2009 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task , Code NPT Phase ~ Description of Operations 4/23/2009 21:00 - 22:00 1.00 CLEAN P DECOMP Wash sand and junk from 1,905' and to 1,920' md. 70K up weight. 65K down weight. 65K rotating weight. 30 rpm at 1 K torque. 535 gpm at 1,820 psi. 22:00 - 22:30 0.50 CLEAN P DECOMP Pump hi-vis sweep surface to surface at 535 gpm and 1,820 psi. 22:30 - 23:00 0.50 CLEAN P DECOMP Pull out of hole from 1,920' and to 222' md. Stand back drill collars. Clean boot baskets. Recovered large chunks of sleeve and face of rubber plug. 23:00 - 00:00 1.00 CLEAN P DECOMP Make 3rd run with Reverse circulatin Junk baskets BHA. Run in hole to 1,917' md. 4/24/2009 00:00 - 01:30 1.50 CLEAN P DECOMP Taa sand_at 1.919' and Drop ball and saw minimal pressure increase onl up to 450 psi at 273 gpm. Due to minimal gain dropped second ball and attempt to seat with no pressure increases. Decision was made to pull out of hole and inspect RCJB. 01:30 - 05:00 3.50 CLEAN N DFAL DECOMP Pull out of hole from 1,919' and and lav down RCJB. Wait on , .N vuv,. ,,, ,~........ ,.. .,,.... Establish circulation at 150 gpm with 450 psi. Shut down pumps and break off stand to drop ball. Drop ball and establish circulation at 330 gpm pressure up to 1,830 psi. 05:00 - 05:30 0.50 CLEAN P DECOMP Wash down to top of sand at 1,919' md. Wash sand and junk down to 1,928' md. Rotate down at 35 rpm with 1 K torque. Circulate at 330 gpm with 1,850 psi. 05:30 - 06:30 1.00 CLEAN P DECOMP Circulate hi-vis sweep surface to surface. Circulate at 330 gpm with 1,850 psi. 06:30 - 09:00 2.50 CLEAN P DECOMP Pull out of hole from 1,928' md. Lay down BHA. Clean Boot baskets and RCJB. Recover 3" piece of metal and small fragments of metal. 09:00 - 10:30 1.50 CLEAN P DECOMP Make u RBP retrievin tool BHA with Boot askets. Run in hole to 1,928' and and wash down to 1,940' and (Top of RBP). 10:30 - 11:30 I 1.00 I CLEAN I P 11:30 - 13:30 I 2.001 CLEAN I P 13:30 - 14:00 0.501 CLEAN P 14:00 - 16:30 I 2.501 CLEAN I P Up and Down weight of 55K. 170 gpm at 150 psi. DECOMP Circulate hi-vis sweep surface to surface. Pull RBP free with 25K overpull. 550 gpm with 620 psi. DECOMP Pull out of hole from 1,940' and with RBP. La down RBP and BHA. Clean and clear rig floor. DECOMP Pick up Swage BHA. Bring Swages up beaver slide. DECOMP Make uo Swaae BHA to 707' md. Consisting of: -4.5" Bull nose -6.25" Bumper Jar -6.25" Oil Jar -9) 6.25" Drill collars -6.25" Intensifier Printed: 5/11/2009 10:34:02 AM • BP EXPLORATION Page 8 of 15 Operations Summary Report Legal Well Name: 11-12 Common Well Name: 11-12 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date. From - To Hours Task Code NPT Spud Date: 11 /16/1984 Start: 4/13/2009 End: 5/4/2009 Rig Release: 5/4/2009 Rig Number: Phase Description of Operations 4/24/2009 14:00 - 16:30 2.50 CLEAN P DECOMP -XO 14/25/2009 16:30 - 17:30 17:30 - 22:00 22:00 - 00:00 00:00 - 01:00 1.00 CLEAN P 4.50 CLEAN N 2.00 CLEAN P 1.00 CLEAN P 01:00 - 03:30 I 2.501 CLEAN I P 03:30 - 06:30 I 3.00 I CLEAN { P 06:30 - 08:00 1.50 CLEAN P 08:00 - 08:30 0.50 CLEAN P 08:30 - 09:30 1.00 CLEAN P 09:30 - 11:30 2.00 CLEAN P 11:30 - 13:30 2.00 EVAL P 13:30 - 17:00 3.50 EVAL P -4) Stands 4" Drill pipe -XO's -8.375" Swage -XO -Float sub -XO DECOMP Service Rig and Top Drive. RREP D ECOMP Inspect and replace Torque cylinder on Iron roughneck. D ECOMP Run in hole with Swage BHA from 707' and to 4,185' md. D ECOMP Run in hole with Swage BHA from 4,185' and to 4,841' md. Wash down from 4,841' and to 4,935' md. 400 gpm with 600 psi. 110K up weight. 90K down weight. D ECOMP Run in hole from 4,935' and to 5,285' and while circulating at 190 gpm with 180 psi. -From 4,975' and to 5,285' and 15 - 25K over down force with 20 - 30K up weight with 8.5" Swage at these depths. -Run in hole to 5,670' md. -With 8.375" Swage at 4,975' and 30 - 35K over on down force. Run in hole to 6,000' md. Up weight 125K. Down weight 95K. D ECOMP Pull out of hole from 6,000' md. -With 8.375" Swage at 4,975' and 25 - 30K overpull. -With 8.5" Swage from 5,280' and to 4,970' and 5 - 20K overpull. At 4,975' and 50K overpull. D ECOMP Lay down BHA. Clean and clear rig floor. D ECOMP Pressure test casin to 3,500 si for 10 minutes. -Good Test. D ECOMP Lay BHA tools down Beaver slide. D ECOMP Service rig and perform preventative maintenance while waiting on Wire line. D ECOMP Rig up to run logs with wireline. D ECOMP Run in hole with SWS caliper tool to log tight spot. Loa from 5.387' up to 1.392' Wireline measurement. Noted: collapsed casing in joint 121 at 4,974' restricting the to 8.05" recordings indicated slit ~ severity from 3.120' to 17:00 - 19:00 I 2.001 EVAL I P I I DECOMP 19:00 - 20:00 1.00 EVAL P 20:00 - 21:30 1.50 CLEAN P 21:30 - 23:30 I 2.001 FISH I P wireline measurment. Did not see DECOMP Rig down SWS wire line tools. DECOMP Run in hole with 6 1/4" drill collars. Pull out of hole laying down drill collars. Lay down bumper sub, Jars, and intensifier. DECOMP Pick u fishin BHA to 309' md. Consisting of: -4 3/4" bumper Jar -4 3/4" Oil Jar -(9) 4 3/4" drill collars -4 3/4" Intensifier Printed: 5/11/2009 10:34:02 AM • • BP EXPLORATION Page 9 of 15 ~ Operations Summary Report Legal Well Name: 11-12 Common Well Name: 11-12 Spud Date: 11/16/1984 Event Name: REENTER+COMPLETE Start: 4/13/2009 End: 5/4/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/4/2009 Rig Name: NABOBS 2ES Rig Number: Date From - To I Hours Task Code NPT Phase Description of Operations 4/25/2009 21:30 - 23:30 2.00 FISH P DECOMP -3 1/2" Pump out sub -XO 23:30 - 00:00 0.50 FISH P DECOMP Run in hole picking up drill pipe from 309' and to 962' md. 4/26/2009 00:00 - 04:30 4.50 FISH P DECOMP Run in hole from 962' and to 11770' md. 04:30 - 06:30 2.00 FISH P DECOMP Cut and slip 76' of drilling line, service the draw works, and top drive. 06:30 - 07:30 1.00 FISH P DECOMP Run in hole from 11770' to 11788'. Establish parameters of 83 gpm (~3 268 psi, Up Wt. 195k, and Down Wt. 125k. En a e the fish with 15k down and pick up to 210k. Verified fish was free when si rose to 450 si. Slack off and pick up wt. increased 15k. Laydown jt. of drill pipe and drop dart. 07:30 - 08:00 0.50 FISH P DECOMP Open circ. sub C~ 1950 psi and pump slug. 08:00 - 11:30 3.50 FISH P DECOMP Trip out of the hole from 11758' to 309'. Change out elevators. 11:30 - 14:00 2.50 FISH P DECOMP Rack back the drill collars and laydown the BHA. Use tubing punch to verif no tra ed as. Onl 23' of fish recovered. Fist was parted at top of the GLM. 14:00 - 15:30 1.50 FISH P DECOMP i t e finder f the fish. 15:30 - 18:00 ~ 2.50 ~ FISH ~ P 18:00 - 19:30 I 1.501 FISH I P 19:30 - 21:00 I 1.501 FISH I P 21:00 - 00:00 3.00 FISH P 4/27/2009 00:00 - 05:00 5.00 FISH P 05:00 - 07:00 I 2.001 FISH I P Consists of: -ITCO Spear "C" Dim Type 3.5" -4.75" Bumper Jar -4.75" Oil Jar -(9) 4.75" Drill Collars -4.75" Accelerator -3.5" Pump out sub-XO DECOMP Run in hole from 317' to 11775'. -Up Wt. 200k / Dn Wt. 125k DECOMP Make up to Top drive and circulate at 83 gpm C~ 450 psi. Slack off to engage spear in fish. Ta to ~ 11816' and continue into the fish to 11827'. Pick up 225k and slack off twice. Pick up to 250k and slack off twice. Pick up to 275k and slack off twice. Energize the jars then pick up to 250k, jar, and slack off twice. While jarring the second time the fish dulled free. Break circulation and pump at 84 gpm ~ 550 psi to verify the fish was on. Lay down 1 stand and pressure test the annulus to 500 psi for 5 minutes. Good Test. DECOMP Drop dart to shear the pump out sub @ 2050 psi. Pump dry job and prepare to trip out of the hole. DECOMP Trip out of the hole from 11775' to 3397'. DECOMP Trip out of the hole from 3397' to 318'. Change out the handling equipment and pull the fish to the floor. Fish consisted of 1 GLM and pup jt, 2 Jt's of 3.5" tubing, and a seal assembly (total of 91.87') DECOMP Make u new BHA to mill u and ull the acker. Consists of: -2.375" Spear -(4) 3.125" PRT Ext -6" OD Packer Mill -Triple connect -(3) 4.75" Boot Basket -Bit Sub -4.75" Bumper Sub -4.75" Oil Jar -(9) 4.75" Drill Collars Printed: 5/11/2009 10:34:02 AM • BP EXPLORATION Page 10 of 15 Operations Summary Report Legal Well Name: 11-12 Common Well Name: 11-12 Spud Date: 11/16/1984 Event Name: REENTER+COMPLETE Start: 4/13/2009 End: 5/4/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/4/2009 Rig Name: NABORS 2ES Rig Number: Date From - To Hours ', Task Code NPT Phase Description of Operations __ -- 4/27/2009 05:00 - 07:00 2.00 FISH P DECOMP -Pump out sub 07:00 - 10:00 3.001 FISH P 10:00 - 12:00 I 2.001 FISH I P 12:00 - 13:00 I 1.001 FISH I P 13:00 - 14:00 I 1.001 FISH I P 14:00 - 15:00 I 1.001 FISH I P 15:00 - 20:00 I 5.001 FISH I P 20:00 - 21:30 I 1.501 FISH I P 21:30 - 00:00 2.50 FISH P 4/28/2009 00:00 - 01:00 1.00 FISH P 01:00 - 07:00 I 6.001 FISH I P 07:00 - 08:00 I 1.001 FISH I P 08:00 - 12:30 I 4.501 FISH I P 12:30 - 13:30 1.00 FISH P 13:30 - 14:30 1.00 FISH P -XO DECOMP RIH from 332' to 11880'. Install the blower hose and prepare to enter the packer with the PRT. DECOMP Get the PRT into the acker at 11897'. Up Wt. 210k /Down Wt. 125k /Rot. Wt. 155k. Establish circulation at 146 gpm C 550 psi. Shut down the pump and work the string up and down making it into the packer to 11911'. Unable to circulate, rack back a stand and work up and down. Pressure increased to 912 psi. Slack off and release pressure. Attempt to circulate again at 86 gpm Q 176 psi. Make up stand and attempt go into the packer again at 86 gpm C~ 173 psi. Slack off to 11896' when pressure built to 1128 psi. Bring the pumps down to 54 gpm and continue to work with no success. Decision was made to trip out of the hole and pick up 6" packer mill with no PRT. DECOMP Pump a dry job, remove the blower hose and blow down the top drive. Monitor well for 10 minutes. Static. Install air slips and stripping rubbers. DECOMP Safety meeting to discuss the current operations and the plan forward for the next run due to failure of getting the PRT into the packer far enough to mill up the packer. DECOMP Service top drive and draw works. Prepare to pull out of the hole. DECOMP Trip out of the hole from 11880' to 332'. Change out the handling equipment and lay down the BHA from 332'. DECOMP Make up new BHA to 316'. Consists of: -6" x 3.5" MM Packer Mill -(3) 4.75" Boot Basket -Bit Sub -4.75" Bumper Sub -4.75" Oil Jar -(9) 4.75" Drill Collars -Pump out sub -XO DECOMP Run in the hole from 316' to 10173'. DECOMP Run in the hole from 10173' to 11864'. Establish circulation at 260 gpm C«~ 782 psi. -Up Wt. 205k /Down Wt. 125k DECOMP Begin milling on the packer which was located at 11897'. Pumped a steel tube sweep to reduce torque from 7-8k off and 9-10k on with 4k WOB to 5-6k off and 8-9k on. Circulate out expected gas through the gas buster at 115 gpm ~ 493 psi. Monitor well for 5 minutes. Static. Continue milling ahead to 11900'. _Lose returns with an initial loss rate of 480 bph. Continue millin the acker which came free @ 11903'. DECOMP Push the packer to 12510'. Put 5k down to verify it's in place. Prepare to trip out of the hole. DECOMP Trip out of the hole from 12510' to 316'. Losses of 120 bph. Total Losses for tour 965 bbls. DECOMP Lay down the BHA from 316' and clean and clear the floor. DECOMP Pick up BHA to spear and pull out the packer. Printed: 5/11/2009 10:34:02 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: 11-12 Common Well Name: 11-12 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date '~ From - To '~ Hours Task Code 14/28/2009 113:30 - 14:30 I 1.001 FISH I P 14:30 - 18:00 3.50 FISH P 18:00 - 19:30 1.50 FISH P 19:30 - 20:30 1.00 FISH P 20:30 - 00:00 3.50 FISH P 4/29/2009 ~ 00:00 - 05:30 05:30 - 07:00 5.50 ~ FISH P 1.501 FISH I P 07:00 - 10:00 3.00 FISH P 10:00 - 11:00 1.00 FISH P 11:00 - 12:00 1.00 FISH P 12:00 - 16:00 4.00 FISH P 16:00 - 18:00 2.00 FISH P Start: 4/13/2009 Rig Release: 5/4/2009 Rig Number: Page 11 of 15 ~ Spud Date: 11 /16/1984 End: 5/4/2009 NPT Phase Description of Operations DECOMP Consists of: -2.375" ITCO Spear -2.375" Spear Ext. -3.5" IF x 2.375" REG Spear Stop Sub -4.75" Bumper Jar -4.75" Oil Jar -(9) 4.75" Drill. Collars -4.75" Accelerator -3.5" Pump out sub -XO DECOMP Run in the hole from 312' to 12407'. DECOMP Slip and cut 103' of drilling line and service the top drive and draw works. DECOMP Run in the hole from 12407' to 12565'. Tagged the packer at 12565' wit an p Wt. 215k /Down t. 130 and 100 gpm ~ 201 psi. Spear engaged the packer 3' and overpulled 10-30k. Packer came free and verified with Up Wt. 220k /Down Wt. 135k and 100 gpm ~ 290 psi. DECOMP Trip out of the hole from 12568' to 4518'. Showed up to 25k overpull inside the 7" liner, but dropped off once we entered the 9 5/8". Total Losses for tour 1100 bbls. DECOMP Continue to trip out of the hole from 4518' to the fish. Tubing punch all connections on both sides to verify no trapped pressure. Break out and lay down the fish which consists of Packer, mill out extension, XO, 1 full jt., and 1 cut jt 17.85' . Which totaled 67.03'. IBP was located across the connection between the mill out extension and crossover. Cut jt. was belled out to 5" OD. DECOMP Pick up spear and make up new BHA to 309'. -3.5" ITCO Spear -4.75" Bumper Jar -4.75" Oil Jar -(9) 4.75" Drill Collars -4.75" Accelerator -3.5" Pump out sub -XO DECOMP Run in the hole from 309' to 12609' with Up wt. 220k /Down wt. 130k and circulating at 164 gpm C~ 1323 psi. DECOMP Run to 12629' and to the fish. Slack off and saw a pressure increase of 400 psi. Shut down the pumps and bottom out on the fish at 12633' slack off 10k. Verify the fish is engaged. by attempting to circulate, pressured up immediately. Drop pump out sub dart and prepare to trip out of the hole. DECOMP Trip out of the hole from 12633' to 11951'. Make up topdrive and shear open pump out sub at 2200 psi. Blow down the top drive. Continue to trip out of the hole from 11951' to 9884'. Losses for tour 1511 bbls of 8.5 ppg seawater DECOMP Trip out of the hole from 9884' to 309'. DECOMP Pull the fish to the floor and use the tubing punch to punch holes on both sides of the plug and collars. Fish was a total of 22.9'. Consisted of cut jt., XN nipple, pup jt., shear out sub, Printed: 5/11/2009 10:34:02 AM • BP EXPLORATION Page 12 of 15 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 4/29/2009 16:00 - 18:00 18:00 - 20:00 20:00 - 23:00 23:00 - 00:00 4/30/2009 100:00 - 02:30 02:30 - 07:00 07:00 - 14:30 14:30 - 15:30 15:30 - 23:00 23:00 - 00:00 5/1/2009 100:00 - 08:30 11-12 11-12 REENTER+COMPLETE Start: NABOBS ALASKA DRILLING I Rig Release: NABOBS 2ES Rig Number: Hours Task Code ~ NPT I Phase i 2.00 FISH 2.00 CLEAN P 3.00 CLEAN P 1.00 CLEAN P 2.50 CLEAN P 4.50 CLEAN P 7.50 CLEAN P 1.00 BOPSU P 7.50 BOPSU P 1.00 BOPSU P 8.50 CLEAN P Spud Date: 11 /16/1984 4/13/2009 End: 5/4/2009 5/4/2009 Description of Operations DECOMP and PXN plug. DECOMP Pick up cement drill out BHA to 584'. -6" Bit -(2) 4.75" Boot Basket -Bit Sub -4.75" Bumper Jar -4.75" Oil Jar -(9) 4.75" Drill Collars -3.5" IF Pump out Sub -XO -(3 Jts.) 4" HT40 Drill Pipe DECOMP Run in hole from 584' to 12600'. DECOMP Make up the top drive and tag the cement at 12652'. Begin drilling cement/sand to 12750' circulating at 250 gpm @ 850 psi. Torque at 8-9k at 80 RPM with Up wt. 220k/ Down wt. 130k /Rot 185k. DECOMP Drill cement and sand from 12 750' and to 12 969' md. Circulating at 507 gpm with 3,434 psi. Pump sweep which brought backs lots of sand and some cement debris. Up Weight 220K. Down weight 125K. Rotating weight 165K. DECOMP Circulate a hi-vis sweep to clean hole at 512 gpm with 3,400 psi. Rotated at 36 RPM's and reciprocated a full stand. Continually getting sand back to surface. Due to the amount of debris back to surface from the second sweep we deci ed to pump a third hi-vis sweep at 353 ppm Q 1615 psi. Lots of .,~~ .,~~~.,~~....,,.~, ~~.. ,...,.,.,~ ~~.,.,...,., r~,.y .....,~.....,,.,....,,,. Up Wt. 240k /Down Wt. 125k DECOMP Trip out of the hole from 12969' and lay down the cement cleanout BHA. Losses are still running around 120-130 bbls/hr. DECOMP Pull the wear bushing and make up the BOPE test equipment. DECOMP Test BOPE- Choke, Top Drive, 4" TIW and Dart to 250 psi low / 3500 psi high. Test annular preventer with 4" test joint only to 250 psi low / 2500 psi high. Install test plug and test the Upper and lower rams with the 4" and 5.5" test joints to 250 psi / 3500 psi for 5 minutes and chart. Test all other BOPE to 250 psi / 3500 psi. All tests passed and charted. AOGCC rep. Lou Grimaldi witnessed the test along with Nabors Tool Pushers Ken Helf and Chris Page, and BP WSL's Matt Martyn and Chris Kobuck. Had to keep filling the annulus while testing due to losses to the formation 195bb1s . DECOMP Pull the test plug, install the wear bushing, and blow down all surface equipment and lay down all testing equipment. DECOMP _ Make u 7" and 9 5/8" Scra er BHA and run in hole to 9300'. Took 5k at bit depth of 8155' which was 9 5/8" scraper depth of 4952, then took 10k down wt. and 40k up wt. from 4959' to 4969' 9 5/8" scraper depth. Worked the scraper through the area 4 times with no changes. At bit depth of 9025', (Liner top depth at 9029') slacked off 5k, picked up, slacked off and took Printed: 5/11/2009 10:34:02 AM • BP EXPLORATION Page 13 of 15 ~ Operations Summary Report Legal Well Name: 11-12 Common Well Name: 11-12 Spud Date: 11/16/1984 Event Name: REENTER+COMPLETE Start: 4/13/2009 End: 5/4/2009 ,Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/4/2009 ',Rig Name: NABORS 2ES Rig Number: Date 'From - To Hours Task Code' NPT ', Phase. Description of Operations 5/1/2009 00:00 - 08:30 8.50 ~ CLEAN P 08:30 - 10:30 I 2.001 CLEAN I P 10:30 - 18:00 ~ 7.50 ~ CLEAN ~ P 18:00 - 21:30 I 3.501 CLEAN I P 21:30 - 22:30 I 1.001 CLEAN I P 22:30 - 00:00 I 1.501 CLEAN I P 5/2/2009 100:00 - 01:30 I 1.50 I CLEAN I P 01:30 - 02:30 I 1.001 CLEAN I P 02:30 - 03:30 1.00 CLEAN P 03:30 - 09:00 5.50 CLEAN P DECOMP 20k, picked up and rotated and slack off through with no wt. taken. Continued in the hole to 12227'. BHA Consists of: -6" Bit -(2) 4.75" Boot Baskets -7" Casing Scraper -Bit Sub -4.75" Bumper Sub -4.75" Oil Jar -(9) 4.75" Drill Collars -(6) HWDP -3.5" Pump Out Sub -XO Sub -4" Drill Pipe -XO Sub -XO Sub double pin -9 5/8" Scraper -Bit Sub -XO Sub DECOMP Pump a hi-vis sweep at 420 gpm ~ 1850 psi. No significant debris from the sweep. Pumped a dry job and prepare to trip out of the hole. DECOMP Rack back the first stand of drill pipe, then trip out of the hole laying down the drill pipe from 12146' to 5651'. DECOMP Trip out of the hole from 5651' racking back the stands of drill pipe, laydown the 9 5/8" scraper at 3210'. Continue out of the hole from 3210' to 495' racking back the drillpipe. Change out the elevators and lay down the remainder of the BHA. DECOMP Pick u BHA for 9 5/8" drift run to 590' md. BHA consists of: -Mule shoe. -HT 40 Drill pipe 92.57'. -XO. -Double pin sub. -8 1/8" Guide shoe 2.39' Ion . -Triple connect drive sub. -XO. -4 3/4" bumper sub. -4 3/4" Oil jar. -9) 4 3!4" Drill collars. -6) Heavy weight Drill pipe. -XO. DECOMP Run in hole with drill pipe from 590' to 3,847' md. Dail losses of 724 bbls seawater. DECOMP Run in hole with drill pipe from 3,847' and to 6,477' md. Encountered ti ht s of with Drift at 4 971' to 4 974' . Saw 5k decrease in down weight and an increase in up weight of 5-10K while pulling through. DECOMP Slip and cut drilling line. Rigged up for slip /cut operations. Held prejob. Cut 103' of drilling line. DECOMP Service rig. Topdrive, Crown, Draw works -adjusting brakes. DECOMP Pull out of hole from 6,477' and to 579' md. laying down drill Printed: 5/11/2009 10:34:02 AM BP EXPLORATION Page 14 of 15 Operations Summary Report Legal Well Name: 11-12 Common Well Name: 11-12 Spud Date: 11/16/1984 Event Name: REENTER+COMPLETE Start: 4/13/2009 End: 5/4/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/4/2009 Rig Name: NABOBS 2ES Rig Number: Date From - To II Hours Task ,Code NPT Phase Description of Operations 5/2/2009 03:30 - 09:00 5.50 CLEAN P DECOMP pipe. 09:00 - 11:00 2.00 CLEAN P DECOMP Lay down BHA -Heavy weight drill pipe, Drill collars, Jars, Bumper sub, XO's, Guide shoe, Drill pipe, Mule shoe. Clean and clear rig floor. 11:00 - 11:30 0.50 CLEAN P DECOMP Remove wear bushing. 11:30 - 14:00 2.50 BUNCO RUNCMP Ri u to run com letion. Pick up casing tools, Change out bails, Rig up torque turn equipment. 14:00 - 15:00 1.00 BUNCO SFAL RUNCMP Trouble shoot problems with power tongs, Change out power tong head. 15:00 - 00:00 9.00 BUNCO P RUNCMP Pick u and run 4.5" 12.6#, 13 Cr-80 tubin and jewelry. Pick up and run Baker S-3 4.5" X 7" packer. - Bakerlok every joint below packer. Pick up and run 4.5" X 5.5" XO assembly. Change over equipment for 5.5" 17# 13Cr-80 Vam Top HC RIH with 5.5" completion replacing joint #5 (39.87') with extra joint of 40.07' in length. Continue to run in hole to 4,637' md. i Torque turn 4.5" jts to 4440 ft/Ibs. Torque turn 5.5" jts to 6588 ft/Ibs 5/3/2009 00:00 - 09:00 9.00 BUNCO RUNCMP RIH with 5.5", 17#, 13Cr-80 completion. Continue to run in hole from 4,637' md. to 9,139' md._ Saw 15k drag with GLM#1(7.834" OD) and 7k drag with GLM#2 (7.834" OD) at tight spot at 4974'. Another 5 to 10K of drag was seen for GLM#3 (7.834" OD). -Torque Turn all 5.5" jts to 6,588 fUlbs. Up weight 170K. Down weight 110K. 09:00 - 10:30 1.50 BUNCO P RUNCMP Make up tubing hanger. Land the tubing and run in lock down screws. 10:30 - 14:30 4.00 BUNCO P RUNCMP Reverse circulated in 261 bbls of 105 F clean seawater (Tubing volume plus 50 bbls) followed by 249 bbls of clean seawater with corrosion inhibitor (Spotted from packer up to GLM#4 wlDCR shear valve) followed by 149 bbls of clean seawater (from DCR shearvalve to surface). Rate-126 gpm with 130 psi. 14:30 - 18:00 3.50 BUNCO P RUNCMP Drop ball and rod. Wait 30 min to let fall. Pressure up tubing to Pressure test tubing to 3,792 psi and held for 30 min. Pressure dropped to 3,775 psi in first 15 min. and to 3,761 psi in next 15 min. -Good test. Bleed off tubing to 2,000 psi. Pressure u and test ann. to 3 620 si and held for 3 min. Pressure dropped to 3,570 psi in first 15 min. and dropped to 3,565 psi in second 15 min. -Good test. Bleed down tubing and back side. Pressure up on annuli to 2,700 psi and sheared the DCR shear valve. Continued to pump at 84 gpm with 400 psi to confirm shear. Pumped down tubing at 84 gpm with 160 psi to confirm shear. Install TWC and test to 1,000 si from above and below for 10 minutes each. -Good test Bleed off pressure. 18:00 - 19:00 1.00 BUNCO RUNCMP Blow down all surface equipment and suck out fluids from BOPE. Printed: 5/11/2009 10:34:02 AM BP EXPLORATION Page 15 of 15 Operations Summary Report Legal Well Name: 11-12 Common Well Name: 11-12 Spud Date: 11/16/1984 Event Name: REENTER+COMPLETE Start: 4/13/2009 End: 5/4/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/4/2009 Rig Name: NABOBS 2ES Rig Number: I Date ,From - To Hours ~ Task ~, Code NPT Phase Description of Operations 5/3/2009 19:00 - 20:00 1.00 BUNCO P RUNCMP PJSM -Nipple down BOPE's. Remove Riser, Turnbuckles and nipple down stack. Bring tree into cellar. 20:00 - 23:00 3.00 WHSUR P RUNCMP Nipple up tree and adaptor flange and test void to 5,000 psi. - Good test. 23:00 - 00:00 1.00 W HSUR P RUNCMP Fill tree with diesel and cycle valves to work air from tree. Pressure up tree and work valves to fuid pack tree. 5/4/2009 00:00 - 01:30 1.50 WHSUR P RUNCMP Pressure test tree with diesel and cycle valves to work air from tree. Tightened up top cap and connections. Pressure up and down a few times attempting to get test on tree. Warm cellar and tree up and tested tree to 5,128 psi losing 90 psi in first 6 minutes then 30 psi in next 9 min. -good test. 01:30 - 03:00 1.50 WHSUR P RUNCMP Rip up DSM lubricator and aressure test to 500 qsi. 03:00 - 04:00 1.00 WHSUR P RUNCMP PJSM. Rig up Little Red Hot Oil Services. Pressure test lines. 04:00 - 05:30 1.50 WHSUR P RUNCMP Little Red Services pumped 140 bbls of Diesel down IA at 84 gpm with 75 psi. Freeze rotectin IA and tubing down to 2100' and (2096 TVD). This will leave 48 bbls of diesel in the tubing and 92 bbls of down IA 05:30 - 12:00 6.50 WHSUR P RUNCMP Rig up and allow well to U-Tube. 12:00 - 15:00 3.00 WHSUR P RUNCMP Ri u DSM lubricator and test to 500 si. Install BPV with lubricator. Rig down lubricator. Rig up Little Red and Test BPV from below BPV to 1,000 psi for 10 min.- Good test. Rig down Little Red. Secure tree and cellar. Release rip at 15:00 hrs. Printed: 5/11/2009 10:34:02 AM TF~ _. 1N8_LFiEAD = ACTUATOR = KB. 8_EV = 58 BF. REV ._ KOP = _ 2000' Max Angle = 8800' Datum MD = 12491' Catum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-{ 2529' 9-5/8" CSG Ranched -See Safety Notes ~ -4975' Minimum Id = 3.7"5" a~ 9127' 4-112" HES XN NIPPLE 5-1!2" TBG„ 17#, 13Cr 80, .17232 bpf, !D = 4.892° ~ 8959'' TOP OF 7" LNR 90129' 9-518" CSG, 47#, L-80, ID = 8.6$1" 9318`. 4-1/2" TBG, 12.6#, 13Cr-80, .0152 bpf, ID = 3.958" 9139' f'F=F7k~ORATK}N SUMMARY REr LOG_ 8!-{CS C3N 121023$4 ANGLEATTOPPERF: 47 ~z7 1222T Note: Refer to Production Cf3 for f,YStorical perf data .. SfLE SPF INTERVAL OpNSgz DATE 2-112" 4 12227 -12233 C 11/09193 2-518" 0.1 12440 - 12470 C 09/17188 2" 0.25 '' 12440 - 12470 C 071;3/89 2-118" 0 12506 - 12528 C 10107/85 2-118" ' 0 12562 - 12574 C 10107/85 2-116" 0 12626 -12656 G 10107185 2-118" 0 12674 -12684 C 10107185 2-118" ' 0 12682 -12684 G 09117/88 2-1/8" 0 12700 - 12806 C 09/17/88 PBTD (as cleaned out by rig Apr09) ~~1 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~ ~ SAF~OTES: 13-3/8" x 9-5/8" Annulus Cemented to S e. 9-5/8" Casing pinched @ -4,975' - 4,990' md. See RWO Reports April 09 for details. 1764' --~ HES 9-5/8" ES Cementer 1786' Baker 9-5/8" x 13-3/8" Ext. C: 1819' Bowen 9-5/8" Overshot Cash 2183' 5-1/2" HES X NIP, ID = 4.562" GAS LIFT MANDRELS ST R~fD TVD DEV TYPE VLV LATCH PORT DATE 4 3399' 3244 41 ~t1MG M DCft RKP 0 05.!03109 3 5837 4792 52 i+~R'u1G M DMY RK 0 oS!03I09 2 7548 5801 56 IL'~,tG- M DMY RK 0 0.5/03,'09 1 8892 6569' S7 MMG-M DNIY RK 0 05;03!09 DATE REV BY COMMENTS DATE REV BY COMMENTS 12/15/84 ORIGINAL COMPLETION 07/18/88 LAST WORKOVER 01/04/02 RN/TP CORRECTIONS 05/03/09 MJM RWO Completion 05/06/09 PJC DRLG DRAFT CORRECTIONS x 9032' ~4-1/2" HES X NIP, ID = 3.813" $0.63' 7" X 4-11" BAKER 5-3 PKR 9096' 4-1/2" HES X NIP, ID = 3.813" 912'7" 4-112" HES XfJ-N1P, 1D = 3.72. 9139' 4.5" 12.6# 9Cr WLEG PRUDHOE BAY UNff WELL: 11-12 PERMff No: 184-1950 API No: 50-029-21212-00 SEC 33, T11N, R15E, 2423.68 FEL 2718.67 FNL BP Exploration (Alaska) FMC 7-1/16" FMC GBV 3 11-12 CAMfftON 04/27/09 ch~umber~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wpll _inh ft ~ .... n...-: _.:_~ NO. Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 F-45A AP3O-00033 ~~~~ RST GRAVEL PACK LOG p4/17/Og u~- 1 VVIVr VU 1 P2-07 AVYO-00023 PRODUCTION PROFILE a ^ 04/05/09 1 1 11-12 AYOO-00019 USIT L - ~ 04/19!09 1 1 X-05 AYTO-00010 USIT Q/~5 04/03/09 1 1 X-01 AZ4D-00012 PRODUCTION PROFILE - (~ 03/18/09 1 1 Z-21A AP3O-00022 RST ~' 02/24/09 1 1 E-34L1 AYTU-00010 OH LDWG EDIT (IFLEX) 02/08/09 1 1 L-106 22026 OH LDWG EDIT (REDO) 01/10/02 1 MPF-96 09AKA0039 OH MWD/LWD EDIT ~ 02/23/09 2 1 F-19A 40018664 OH MWD/LWD EDIT 02/14/09 2 1 F-18A 09AKA0034 OH MWD/LWD EDIT 03/16/09 2 1 06-23C 12066550 MCNL ~ 09/14/08 1 1 03-146 BIJJ-00005 MCNL 03/30/09 1 1 11-18 BOCV-00006 RST --- ( l 03/02/09 1 1 07-208 AWJB-00028 MCNL ~ 02!27/09 1 1 MPB-22A AXBD-00005 CH EDIT PDC-GR (CBL) 12/23/08 1 07-29D AXBD-00016 MCNL '~ ~ ,[~ 03/17/09 1 1 09-33A AWJI-00019 MCNL '~j -- - 04/01/09 1 1 o~ CAQC nnvw.r~.en ~nnr n BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~! r't s -:.w-~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by:_ i ~~ • ~~I;il,~ ' ~ p,'„ I J it f\L,~1 ALASSA OIL A1~TD GA5 COI~TSERQATIOI~T COM1~II55IO1~T Robert Tirpack Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 • SARAH PALIN, GOVERNOR ' 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~g~ \ ~~ Re: Prudhoe Bay Wield, Prudhoe Bay Oil Pool, PBU 11-12 Sundry Number: 309-093 {~~ (, c h Dear Mr. Tirpack: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Cummission an application for rehearing. A request for rehearing 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, A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~7day of March, 2009 Encl. ,~~ STATE OF ALASKA ~~ MAR 1 0 2009 3'~ ~b (~.' , 0~ ALA OIL AND GAS CONSERVATION COMMON N-~'5~~~. 3 ~ 3-~~ APPLICATION FOR SUNDRY APPROVAL Alaska Gtl ~ Gas Cons. Commisston 20 AAC 25.280 Rnchorage 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ®Alter Casing- ~ ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program '® Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. - ®Development ^ Exploratory 184-195 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21212-00-00- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 11-12 - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028325 & 028328- 58' - Prudhoe Bay Field / Prudhoe Bay Oil Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13032' - 9176' - 12682' 8975' 11860' 12621' sin Len th Size M TVD r olla se Structural r 11 20" 110' 11 14 47 urface 252 ' 13-3/8" 2529' 2505' 49 267 Intermediate 9 1 9-5/8" 9318' 794' 687 47 0 P in Liner 4003' 7" 9029' - 1 032' 36' - 9176' 81 0 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plug: 12227' - t2sos' 8687' - 9048' S-1 /2", 17# x 3-1/2", 9.3# L-80 / J-55 11965' Packers and SSSV Type: 7" x 3-1/2" Baker'FB-1' packer Packers and SSSV MD (ft): 11871' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: April 20, 2009 ®Oil- ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Staudinger, 564-5733 Printed Name Robert Tirpack Title Engineering Team Leader Prepared By NameMumber: ? Terrie Hubble, 564-4628 Signature ~ Phone 564-4166 Date I~f Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~\~ 51 ~~~ _ ^ Plug Integrity ~OP Test ^ Mechanical Integrity Test ^ Location Clearance ~~~. rr^^~~ tt Other. 3~V~S~ I,C..~-i ~~ ~, ~+-~<V\ir•'~V'4`t C3 h~~C'~5~ ; ~ . . ~~.~~~ ~s~~~ off- ~~ ~Z ~~~~~e Sao ~~c, ~ s. ~-~ ~~~ .. Subsequent Form quired: ~~ APPROVED BY ~ / A roved B COMMISSIONER THE COMMISSION Date ! Form 10-403 Revised 06/2006 ~~~~I~ ~.. ~, Submit In Dupliclate • • by ~r,~ 11-12 Expense Rig Workover Scope of Work: Pull 5-'/z" x 3-1/2" completion, mill and recover packer and tailpipe, and recover fish above 7" cement cap. Cut and pull 9 5/8" casing, repair leak on 13-3/8" starting head, run 9 5/8" casing and cement to surface, run 5-'/z" 13Cr-80 premium thread completion. Other Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE as follows when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the three-ram drilling BOP stack. MASP: 2425 psi Well Type: Producer Estimated Start Date: April 20, 2009 Production Engineer: Bob Chiwis Intervention Engineer: Mark Staudinger Pre-Rig Work: F 1 CMIT TxIA to 3500 psi to confirm plug integrity/barrier. No planned MITOA - clamp C 13-3/8" han er leaks C~? 200 si. S 2 Drift tubin for 4-1/2" Power Jet Cut. Ta 2-1/4" IBP ~ 11860'. E 3 Power Jet Cut tubin 10' above 2-1 /4" IBP. F 4 Circulate well to seawater. FP with diesel to 2000'. W 5 Check all lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. V 6 Set BPV in tubin han er. O 7 Remove the well house & flow line. Level the ad as needed for the ri . O 8 Line the Cellar around the wellhead with im ermeable, s ra -sealed Herculite. Proposed Procedure Summary: 1. MIRU. Pull BPV. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. Set TWC. 2. ND tree. NU BOPE and pressure test to 250 psi low / 3500 psi high. Pull TWC. 3. Pull and LD 5-'/z" x 3-1/2" tubing string to the cut. 4. RIH and engage tubing stub. Jar free and recover 3-1 /2" stub and seal assembly free from Packer Seal Bore Extension. 5. Mill and retrieve packer and tubing tail. 6. RIH and recover 3-1/2"fish located above cement cap in 7" liner. 7. Cleanout 7" liner and 9-5/8" casing. • 8. Set RBP ~ 8900' MD. 9. Run USIT log to determine top of cement in 9-5/a" x 13-3/8" annulus. 10. Set retrievable bridge plug 100' below the top of cement. Dump 50' of sand on top of RBP. 11. Mechanically cut and pull 9 5/8" casing in the 2"d full joint above the top of cement. Plan is to take returns to lined cellar. Note: Pipe rams will not be changed to 9 5/8" as the well has two tested barriers (Two RBPs) to the reservoir. 12. ND BOP, tubing and casing spool. Replace seals in 13-3/8" starting head. NU casing and tubing spools. NU and test BOP's to 3500 psi. 13. Perform cleanout run in 13-3/8" casing. 14. Run and fully cement new 9 5/" casing to surface. 15. Pressure test new casing and drill out shoetrack. 16. Clean out to retrievable bridge plug(s) and retrieve same. 17. Run 5-'/z" 13Cr-80 completion with 9-5/8" x 5-1/2" chrome packer. 18. Displace the IA to completion fluid and set the packer. 19. Test tubing and IA to 3500 psi. Set TWC. 20. ND BOPE. NU and test tree. 21. Pull TWC, Freeze protect to 2200' MD, Set BPV, Secure Well, RDMO. ATTACHED: Current Schematic Proposed Schematic _ = FMC G WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 58' BF. ELEI/ _ KQP = 2000' Max Angle = 8800' Datum MD = 12491' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-' 2529' I Minimum ID = 0.001" @ 11952' 3-1 /2" OTIS XN NIPPLE,W/ PXN PLUG SET 07/17/00 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" $907' TOP OF 3-1 /2" TBG-PC 8907' TOP OF 7" LNR 9029' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9318' ~ 3-1/2" TBG, 9.3#, J-55, .0087 bpf, ID = 2.992" i PERFORATION SUMMARY REF LOG: BRCS ON 12/02/84 ANGLE AT TOP PERF: 47 @ 12227' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 12227 - 12233 C 11/09/93 2-5/8" 0.1 12440 - 12470 C 09/17/88 2" 0.25 12440 - 12470 C 07/23/89 2-1/8" 0 12506 - 12528 C 10/07/85 2-1/8" 0 12562 - 12574 C 10!07/85 2-1/8" 0 12626 - 12656 C 10/07/85 2-1/8" 0 12674 - 12684 C 10/07/85 2-1/8" 0 12682 - 12684 C 09/17/88 2-1/8" 0 12700 - 12806 C 09/17/88 PBTD 12995' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 13032' DATE REV BY COMMEMS DATE REV BY COMMENTS 12/15/84 ORIGINAL COMPLETION 07/18/88 LAST WORKOV ER 01!04/02 RN/TP CORRECTIONS 01/17/06 RWL/TLH TT CUT / WRP SET 11/18/06 TEUPAG SET BKR IBP@ 11860' 11 ~1 2 SAFETY NOTES: LDL COMMUNICATES @ 9378', 100 1369', 10484', 11793', FTS, OA COMM TO ATHERETHRU 13-3/8" CSG HGR, TRBL WELL, OA COMMUNICATES TO ATM OSPHERE WHEN PUMPING DOWN TBG, TXIA COMM, FTS. LDL SHOWS COMMUNCATION @ 4536'. PLUG @ 11952' 2172' 5-1/2" CAMCO BAL-O SSSV NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3044 2962 42 MMG-2 RK 2 6657 5289 53 MMG-2 RK 3 8481 6334 55 MMG-2 RK 4 9378 6827 57 MMG-2 RK 5 9991 7180 54 MMG-2 RK 6 10484 7487 50 MMG-2 RK 7 10943 7791 47 MMG-2 RK 8 11369 8088 45 MMG-2 RK 9 11793 8386 46 MMG-2 RK 5-1/2" X 3-1/2" XO 11860'~~2-1/4" BKR IBP, MID-~EMHVT (11/18/06) 11871' 7" X 3-1/2" BAKER FB-1 PKR 11874' 3-112" BAKER SEAL BORE EXTENSION ASSY 11931' WRP PLUG (01/18/06) 1965' ELM CHEM CUT TT (01/17/06) 12621' -{3-1/2" OTIS XN (2-3/4" NOGO) w/PXN PLUG, BKR BREAKOUT SUB, & TT, ID = 0.001" 12682' CMT CA P PRUDHOE BAY UNff WELL: 11-12 PERMfT No: 184-1950 API No: 50-029-21212-00 SEC 33, T11 N, R15E, 2423.68 FEL 2718.67 FNL BP 6cploration (Alaska) TREE = FMC GEN 3 WELLHEAD = FMC ACTUATOR = ,~.~. _ -.-a.-. AXELSON KB. F1EV = 58' BF. ELEV ~ 11-12 Proposed KOP = 2000' Max Angle = 8800' Datum MD = 12491' Datum TVD = 8800' SS 9-5/8" CSG, 47#, L-80, ID = 8.681" -~ 13-3/8" CSG, 72#, L-80, ID = 12.347" 2529' Minimum ID = 4.455" 5-1 /2" HES XN NIPPLE 5-1/2" TBG, 17#, 13Cr-80, .0232 bpf, ID = 4.892" TOP OF 7" LNR - 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-~ 931$' PERFORATION SUMMARY REF LOG: BRCS ON 12/02/84 ANGLE AT TOP PERF: 47 @ 12227' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 12227 - 12233 C 11/09/93 2-5/8" 0.1 12440 - 12470 C 09/17/88 2" 0.25 12440 - 12470 C 07/23/89 2-1/8" 0 12506 - 12528 C 10/07/85 2-1/8" 0 12562 - 12574 C 10/07/85 2-1/8" 0 12626 - 12656 C 10/07/85 2-1/8" 0 12674 - 12684 C 10/07/85 2-1/8" 0 12682 - 12684 C 09/17/88 2-1/8" 0 12700 - 12806 C 09/17/88 PBTD -~ 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" SA~NOTFyS: 5-1/2"Chrome Tubing New acking Dement in 13-3/8" Starting Head 5-1/2" HES X NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2 3 4 5-1 /2" HF~ X NIP, ID = 4.562" I 9-518" X 5-1/2" BAKER S-3 PKR 5-1/2" HES X NIP, ID = 4.562" 5-1/2" HF~ XN NIP, ID = 4.455" 5-1/2" WLEG 126$2' i-i CMT CAP DATE REV BY COMMHVTS DATE REV BY COMMENTS 12/15/84 ORIGINAL COMPLETION 07/18/88 LAST WORKOVER 01/04/02 RNITP CORRECTIONS 01/17/06 RWL/TLH TT CUT/WRPSET 11/18/06 TEUPAG SET BKR IBP @ 11860' 03/06/09 MIS RWO Proposed Draft PRUDHOE BAY UNff WELL: 11-12 PERMff No: 184-1950 API No: 50-029-21212-00 SEC 33, T11 N, R15E, 2423.68 F[12718.67 FNL BP 6cploration (Alaska) OS 4-11, 11-12 Annulus Pressure Monitorieformation for... , ¡ 4.. l qs e Subject: OS 4-11, 11-12 Annulus Pressure Monitoring information for AOGCC From: "Engel, Harry R" <Harry.Engel@bp.com> Date: Wed, 22 Nov 200616:11:32 -0900 To:winton3u.Jbert@admin.$tate.ak : "GPB, FS OTU gr" < <Mic (ABZ)" < Well Oper Integrity Engi <Bruce.J.Willia bp.c <Harry. Engel@bp.com> '" '1(' If! M!::'~¡'''';Ii' Winton- è~t~~'(!ß~þt This is a follow-up to our November 13th telephone conversation regarding the subject wells. Prudhoe Bay Unit well 04-11 is a water injector operated under Sundry Approval 303-252 due to confirmed Tubing X Inner Annulus communication. The approval requires pressure testing every two years and monthly reporting of daily injection rates and pressures. The well was shut in on 08/27/06, passed an MIT-OA on 08/29/06 and remained shut-in until 10/20/06 when it was put on Produced Water Injection. Daily injection rates and pressures were monitored however, on 10/28/06, the outer annulus (OA) valve was found closed, rendering the OA pressure gauge incapable of monitoring the true OA pressure. Upon opening the valve, the pressure gauge read 2200 psi. The OA pressure was bled on 10/28/06 and has remained stable since. The outer annulus valve was inadvertently closed from approximately 8/29/06 to 10/28/06. Prudhoe Bay Unit well 11-12 is a long term shut-in producing well with Tubing X Inner annulus communication and a wellhead and surface casing leak when the OA pressure builds. As a result, the OA pressure is maintained near zero. The well was secured with a tubing tail plug in January 1994 and has been shut in since. In January 2006, the tubing tail was cut off to allow logging in the well. The well was again secured with a WRP set in the remaining tubing tail on 01/19/06 after running the log. Operator recorded OA pressure readings changed from 10 psig to 40 psig on 10/11/06. On 10/28/06 a needle valve immediately upstream of the OA valve was found closed, rendering the OA pressure gauge incapable of monitoring the true OA pressure. Upon opening the valve, the pressure gauge read 40 psi. The OA pressure was bled on 10/28/06 and has remained stable since. The needle valve was inadvertently closed from approximately 10/11/06 to 10/28/06. BPXA takes these incidents very seriously, consequently they have been reviewed by our Operations staff to establish corrective actions to prevent future incidents of this nature. Corrective actions include; 1. Expectations have been reinforced with the wells support group regarding the requirement to properly tag and flag all valves where positions have been changed. 2. Discussions with Operators have communicated and reinforced clear expectations related to permit close out and sign off to validate work completed and condition of equipment. Additionally, we have emphasized the need for thorough daily operator checks which include proper valve position and accurate pressure readings. 3. Needle valve handles will be replaced with quarter turn valves to make their position easily identifiable. I am available if you require further information. 1 of 2 11/28/20063:44 PM Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well YDS01-26A ¡o¡g-ùl?- 'Ý11-12 I~ - ¡q!5 Job# 11087213 11087220 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: DÞJ'd-~IOG :" r~ ~ "1f'f ~:~::. j FEB 222006 04~"",..._ ..".. - ........ '-'0.111.:1, "JVIlIiJ!1:j.~) !..J1 An~~e -,w~ç~ " Log Description LEAK DETECTION LOG RST -SIGMA ANNElf"-"'.. ~ b r\ ~) 8.' 2D D D "'-"r F. 1'". - D ?! ~ ~~ . ~ " ~.....,' Date 01/13/06 01/19/06 NO. 3671 Company: 01/26/06 State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne Pt. BL 1 1 Color CD -~ '--" Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth a STATE OF ALASKA _ ALA_ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS D D D 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: 58 KB 8. Property Designation: ADL-028328 11. Present Well Condition Summary: Total Depth measured 13032 true vertical 9175.83 Effective Depth measured 12682 true vertical 8974.8 Casing Conductor Surface Production Liner Length 80 2500 9290 4003 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# L-80 Perforation depth: Measured depth: 12227 - 12682 True Vertical depth: 8686.62 - 8974.8 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. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure SHUT-IN SHUT-IN 15. Well Class after proposed work: Exploratory 0 Development I;ï! 16. Well Status after proposed work: Oil I;ï! Gas WAG Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development I;ï! Stratigraphic 0 feet feet feet feet MD 30 - 110 29 - 2529 28 - 9318 9029 - 13032 12682 - 12806 Closed 8974.8 - 9047.83 5-1/2" 17# 3-1/2" Baker FB-1 Packer 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal Signatu~..I dJ4 Form 10-404 Revised 04/2004 RECEIVED FEB 1 6 2006 StimulateD 1U Qthe;;,@ Set W~ WaiverD Time~MMiMl~ fi~1f IS; n Re-enter Suspended Well DAnchora e 5. Permit to Drill Number: 184-1950 6. API Number: 50-029-21212-00-00 ...,¡ Exploratory Service 9. Well Name and Number: 11-12 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool Plugs (measured) Junk (measured) 11931 WRP 12621 TVD Burst Collapse 30 - 110 1490 470 29 - 2504.54 4930 2670 28 - 6793.97 6870 4760 6636.15 - 9175.83 8160 7020 (':'j'. '~J\i"t~· :Jvr.. .!" "'......... L-80 28 - 8907 11871 R8DMS 8FL FEB 1 7 2006 Tubing pressure Service WDSPL Title Data Mgmt Engr Phone 564-4424 Date 2/15/2006 AL Submit Original Only e e 11-12 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 1/14/2006 ***WELL SHUT IN ON ARRIVAL***(ctd screening) TAG TOP OF PXN PLUG @ 11962' SLM W/ 2.81" CENT & SAMPLE BAILER EMPTY ***WELL LEFT S/I*** 1/17/2006 TAGGED PLUG AND PRONG AT 11971', CUT TUBING AT 11965' CORRELATED TO CAMCO COLLAR LOG DATED 7-30-88. CONFIRMED JET CUTTER FIRED. **NOTIFY DSO THAT WILL BE BACK TO RUN RST** 1/18/2006 ***WELL SHUT IN ON ARRIVAL*** (drift tubing) RIH W/2.75 CENT,TAG TD @12,621 SLM, PULL UP INTO TAIL PIPE NO PROBLEMS,POOH ***WELL SHUT-IN, CONTACT DSO*** 1/19/2006 CORRELATED TO SCHLUMBERGER PRODUCTION LOG DATED 6- DEC-1993 FOR RST AND CAMCO COLLAR LOG DATED 30-JUL-1988 FOR WRP FIELD PICK FOR GOC = 12338 FT SET WRP AT 11931 FT **NOTIFY DSO OF WELL STATUS** 1/26/2006 T/I/O=1350/1350/160. Temp=SI. Bleed T&IA < 500 psi. (post-WRP). IA FL @ 6657' (Sta #2). Drilling scaffolding on well head. Will return to bleed to U/R tank. 1/27/2006 T/I/O=1340/1340/160. Temp=SI. Bleed T& IA < 500 psi. (Post-WRP). TBG FL @ 6090', IA FL @ 6320'. Bled lAP from 1340 psi to 280 psi in 3.5. TBG pressure tracked lAP during bleed, no change in IA FL, OAP decreased 130 psi. Monitored for 30 min, TBG & lAP increased 10 psi. Final WHP's = 290/290/30. Note: Well haS no flowline, or AIL line. Drilling scaffolding on well. 1/28/2006 T/I/O= 290/290/30. Temp= SI. WHP's post-bleed (secure). Drilling scaffolding over wellhead. No change in pressures. FLUIDS PUMPED BBLS 2 2 I ~:::L Re: DS 11-12 Casing Leak PERMIT TO DRILL 184~19~5_..' Subject: Re: DS 11-12 Casing Leak PERMIT TO DRILL 184-195 Date: Tue, 25 Jul 2000 11:28:31 -0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: PRB Problem Wells <P1041@ppco.com> CC: tom_maunder~admin.state.ak.us, Well Operations Supervisors AAI <P2010~ppco.com>, Dan R Babcock <DBABCOCK~ppco.com>, aogcc north slope address <aogcc_prudhoe_bay~admin.state.ak.us> Jerry/Jo, Thanks for your memo on the casing leak problem. Please keep us apprised of your findings and plans. Please also contact our inspector - currently John Spaulding, then Lou Grimaldi. Thanks, Blair PRB Problem Wells wrote: > Blair / Tom: As you may recall, back on February 2, 2000, we reported a leak > from the casing head (OA) to atmosphere on DS 11-12 as a spill. It appeared at > that time the eline log and pumping activity caused thermal expansion, raising > the OA pressure which then leaked through the surface casing head to atmosphere. > Repairs were attempted on the casing head, and the well was being prepared to > repeat the eline log. The purpose of the log is to determine whether there are > enough reserves to justify a workover on this well (RST log). > On 7/12/00 the tailplug was pulled from the tubing. Eline was expected to follow > shortly, the rigup to include venting the OA to a tank to prevent pressure > buildup. However, tubing & IA pressure (T x IA communication) leaked into the > OA, which caused the leak to re-appear. The Drillsite Operator found gas and > diesel/Arctic Pack bubbling around the conductor pipe on 7/17/00. The OA had 80 > psi; steps were immediately taken to bleed the pressure off to a tank. The > bubbling ceased at about 10-15 psi on the OA. Spill Response was alerted, a > tailplug was re-run, and the well loaded with seawater. Proper spill reporting > steps were taken. > Today, 7/18/00, contaminated gravel was removed from around the conductor pipe. > It appears there may be a leak well below ground level in the casing. About 3' > down free oil product was found. We have stopped the removal at this time; > consideration is being given to using a backhoe so there is not a safety risk > with the hydrocarbons. There will be no further plans to enter this well until a > plan is in place to 1) prevent or minimize the chance of another spill to > complete the eline log, or; 2) P&A the well for good. We will have to study this > awhile to figure out what the leak mechanism is. > Call Joe Anders or me if you have any questions. > Jerry Dethlefs > Problem Wells 7/25/00 11:29 AM Re: DS 11-12-PTD 84-0195 ,~-~----. ~ .,,, Joe or Jerry, I just received a final agency spill report regarding an apparent leak from the OA on well 11-12. What is the present situation and condition of the well? Did you send any notice of this event to Blair or our NS inspectors?? Looking forward to your reply. Tom Maunder Nar~: 11-12 History. doc 11-12 History. doc Type: Microsoft Word Document (app/ication/msword) En©ding: base64 De~ription: Mac Word 3.0 Re: DS 11-12-PTD 84-0195 Subject: Re: DS 11-12--PTD 84-0195 Date: Thu, 24 Feb 2000 08:58:57 -0900 From: Lou Grimaldi <lou_grimaldi@admin.state.ak. us> Organization: State of Alaska, Dept ofAdmin, AOGCC To: Tom Maunder <tom_maunder@admin.state.ak. us> Internal Mornin Tom, I am up and at em. Got in about midnight, felded a couple of calls and went to bed. This well is a example of procrastination, the problem has been known for twelve years, holy cow, what time frame is allowed to fix a important well component such as the pack-off? I know money is tight but these things are embaressing. Lou Tom Maunder wrote: Jerry, Thanks for the info. Casing hanger problems...where have we heard that one?? With regard to the notification, would you please check with the FEC and be sure we are on the list--especially for anything involving a well. I suspect since we got a final report, we probably got the initial report. With this one involving a well, it caught me a little off guard that I hadn't heard anything about it. Again, thanks for the info. I'll renew and get back with you or Joe. Tom PRB Problem Wells wrote: > Tom: Attached is a short history of events related to the 11-12 OA leak The > well is currently shut-in, loaded, and secured with a tail plug As you can see, > the history of this OA problem goes back further than rny database information. > The only reference I can find about the OA hanger problem is a failed packoff > test on the surface casing hanger on 5-7-88. The well has been shut-in a number > of years with bad tubing. I believe the RST log that was attempted when the > spill happened was intended to look for potential reserves and possibly future > utilization of the we//. > At the time of the spill the ARCO Field Environmental Compliance (FEC) was > notified (as per po/icy). It is their responsibility to notify all government > and internal agencies of spills as they happen. To my know/edge the Field > Inspectors and/or Blair Wondzell were not specifically notified un/ess they are > on the FEC notification list. > As far as working on the well, the Valve Shop crew is to check the torque on the > casing hanger clamp, which is an FMC Gen III Emergency head from the original > completion. The casing head contains a metal ring gasket that is either leaking > or completely failed. In addition the casing packoff assembly must be leaking; > the failed packoff test back in 1988 would support this evidence. After the > c/amp torque is checked we will perform another packoff test and check the > lock-down screws. Beyond that we have no additional plans or remedies yet on the > books. > Jerry Dethlefs(See attached file: 11-12 History. doc) > ARCO Problem Wells Tom Maunder <torn_maunder@admin. state, ak. us> on 02/23/2000 09:08:56 AM To: PRB Problem WelIs/AAI/ARCO cc: AOGCC North Sope Offioe <aogcc_prudhoe_bay@admin. state, ak. us> Subject: DS 11-12-PTD 84-0195 Problem Well History For Well 11-12 Date Comment 2/6/2000 WL attempted RST. While loading well, OA pressure increased to 400 psi, oil started spraying out of 13-318" clamp connection. Stopped pumping, bled OA to slop trailer, leak stopped. Loaded well with SW, set TTP to secure. DHD Notes:T/IlO = 190011900~50 IA FL @ 3000'. OA FL near surface. Bled IA from 1900 psi -- psi via next well#32. 1/25/1994 T!110=2200175010, well SI with plug in tbg tail (plug run 1/21/94). Combo Tbg x IA MIT passed to 3000 psi: -180 psi/30 min. Well was loaded with 735 bbls crude. The well was a FTS that is now secure. It will remain SI until remedial action. 1/6/1994 A Leak Detection Log was run and several leaks were noted. Leaks were identified at 9390'/#4 GLM and at 10485'/# 6 GLM. 1/3/1994 1/2/1994 1/1/1994 T/110=90011500/50. Checked pressures; clamp still leaking slightly. T/110=750117001360, flowing. Bled OA to zero+ in 30 min -all gas. Replaced 13-3/8" hanger buttonhead fitting - test port pressure will not stay zero. Clamp still leaks gas very slightly even with the OA @ zero psi. TII!0=800117001200. FMC clamp @ 13-3/8" casing hanger reported leaking gas. DSM bled off OA & tightened clamp bolts. Began leaking again as OA built back up. Re-bled OA from 200 to zero+. Checked 9x13 packoff: test port had zero+, bled to zero. Flushed through w/hyd fluid & performed PPPOT to 3000 psi: PASSED. Checked 13x20 packoff: Test port buttonhead appeared to be plugged, pressure behind it. Tightened LDS -.-3 turns each. Clamp still leaking gas. Wednesday, February 23, 2000 Page 2 of 2 ,~. Feb-23-O0 og:2g r_~P_~i~charge Pr~ed: 02/23/2000 Page: I From-ARCO ENVIRONI~NTAL PB LCO Alaslm, Inc,, Eastern Operating Area Prudhoe Bay/GPMA, Phone: 907-659-8270 Final Agency Report T-$14 P. OZ/OZ ~-OZZ LOCATION OF DISCHARGE: DSI l ADDITIONAL LOCATION INFO. Ddllsim 11-12 TIME OBSERVF. D: I 1:55:00 AM 0210612000 RSPORTED BY: TO: LINDA ALLEN, I::EC TECH ADEC; 2123100 Final Fax ADNR: 0d23/00 Final Fax NSB: Fax 2/8/00 Other: AOGCC 2/23/00 Final RESPONSIBLE GROUP: ARCO ALASKA 1NC. TYPE AND AMOUNT: 60,0 Total Gallon(s) 0.0 Gallon(s) Unto Tundra, covering 0.0 area 0.0 Gallon(s) Into Water, covering 0,0 area 0.0 Gallon(s) Inside Secondary Con:ainmon~ 0,0 Gallon(s) Into Building 100 % CRUDE CAUSE OF DISCHARGE: ENVIRONMENTAL DAMAGE: EQUIPMENT DIFFICULTY Casing Flange at ]3 3/8" casing hanger started leaking after dA pre.~.~ure rose from 0 to 440 PSI Outing normal operations (1000 PS[ normal sate working pressure). Investigation revealed that the flange had been repaired arm' a similar leak 6 years ago. None. The spill was conlaincfl cm rile gs'avel pad, CLEAN UP ACTIONS: CLEANUP VERIFICATION: AMOUNT OF SPILL RECOYERED: PREVENTIVE ACTION: Tho spill response team was called out to thc spill. Recovered snow and ico with loader. Transported to Pad 3 tbr disposal, Recovered contaminated gravel with ~upersUckm' and transporte_xl to G&I for di.~posal. VISUAL 100% Better documentation of annular problems. Possiblcy including a remark on wells group schematic, DISPOSAL/RECYCLF- LOCATION: DRILL SITI! 4 (GRIND & INJECT) PAD 3 EAST SNOW PIT COMMENTS: THE SPILL WAS NOT REPORTED TO THE AGENCIES UNrFIL A DAY LATER BECAUSE THE ESTIMATED VOLUME WAS ORIGINALLY THOUGHT TO BE LESS THAN 42 GALLONS. · ,R.e: DS~ 1-12-PTD 84-0195 ~-"---- ~ Subject: Re: DS 11-12--PTD 84-0195 Date: Wed, 23 Feb 2000 14:11:53 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: PRB Problem Wells <P1041@mail.aai.arco.com> CC: AOGCC North Sope Office <aogcc_prudhoe_bay@admin.state.ak. us> Jerry, Thanks for the info. Casing hanger problems...where 'have we heard that one?? With regard to the notification, would you please check with the FEC and be sure we are on the list-especially for anything involving a well. I suspect since we got a final report, we probably got the initial report. With this one involving a well, it caught me a little olf guard that I hadn't heard any[hing about it. Again, thanks for the info. I'll review and get back with you or Joe. Tom PRB Problem Wells wrote: Tom: Attached is a short history of events related to the 11-12 OA leak The well is currently shut-in, loaded, and secured with a tail plug As you can see, the history of this OA problem goes back further than my database information. The only reference I can find about the OA hanger problem is a failed packoff test on the surface casing hanger on 5-7-88. The well has been shut-in a number of years with bad tubing. I believe the RST log that was attempted when the spill happened was intended to look for potential reserves and possibly future utilization of the we//. At the time of the spill the ARCO Field Environmental Compliance (FEC) was notified (as per po/icy). It is their responsibility to notify all government and internal agencies of spills as they happen. To my know/edge the Field Inspectors and/or Blair Wondze/I were not specifically notified un/ess they are on the FEC notification list. As far as working on the well, the Valve Shop crew is to check the torque on the casing hanger clamp, which is an FMC Gen III Emergency head from the original completion. The casing head contains a metal ring gasket that is either leaking or completely failed. In addition the casing packoff assembly must be leaking; the failed packoff test back in 1988 would support this evidence. After the c/amp torque is checked we will perform another packoff test and check the lock-down screws. Beyond that we have no additional plans or remedies yet on the books. Jerry Dethlefs(See attached file: 11-12 History. doc) ARCO Problem Wells Tom Maunder <torn_maunder~admin. state, ak. us> on 02/23/2000 09:08:56 AM To: PRB Problem WelIs/AAI/ARCO cc: AOGCC North Sope Offio~ <aogcc_prudhoe_bay@admin. state, ak. us> Subject: DS 11-12--PTD 84-0195 Joe or Jerry, I just received a final agency spill report regarding an apparent leak from the OA on we//11-12. What is the present situation and condition of the we//? Did you send any notice of this event to Blair or our NS inspectors?? Looking forward to your reply. Tom Maunder Narre: 11-12 History. doc o.,Io I~1~ ~1 ' -Re: D~'~ 1-12-PTD 84-0195 > 11-12 History. doc Type: Microsoft Word Document (application/msword) > En©ding: base64 > De~;ription: Mac Word 3.0 Tom Maunder <tom maunderC, admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission Problem Well History For Well 11-12 Date Comment 2/612000 WL attempted RST. While loading well, OA pressure increased to 400 psi, oil started spraying out of 13-3/8" clamp connection. Stopped pumping, bled OA to slop trailer, leak stopped. Loaded well with SW, set TTP to secure. DHD Notes:T/IlO - 1900/1900/50 IA FL @ 3000'. OA FL near surface. Bled IA from 1900 psi -- psi via next well#32. 1/25/1994 T/110-2200/75010, well SI with plug in tbg tail (plug run 1121194). Combo Tbg x IA MIT passed to 3000 psi: -180 psi/30 min. Well was loaded with 735 bbls crude. The well was a FTS that is now secure. It will remain SI until remedial action. 1/6/1994 A Leak Detection Log was run and several leaks were noted. Leaks were identified at 9390'/#4 GLM and at 104857# 6 GLM. 1/3/1994 1/2/1994 1/1/1994 T/110=90011500150. Checked pressures; clamp still leaking slightly. TII10=750/17001360, flowing. Bled OA to zero+ in 30 min -all gas. Replaced 13-3/8" hanger buttonhead fitting - test port pressure will not stay zero. Clamp still leaks gas very slightly even with the OA @ zero psi. T/1/O=800/1700/200. FMC clamp @ 13-3/8" casing hanger reported leaking gas. DSM bled off OA & tightened clamp bolts. Began leaking again as OA built back up. Re-bled OA from 200 to zero+. Checked 9x13 packoff: test port had zero+, bled to zero. Flushed through w/hyd fluid & performed PPPOT to 3000 psi: PASSED. Checked 13x20 packoff: Test port buttonhead appeared to be plugged, pressure behind it. Tightened LDS ,-,3 turns each. Clamp still leaking gas. Wednesday, February 23, 2000 Page 2 of 2 r_SP_Discharge Printed: 02/23/200(I Page: I Fr0m-ARCO ENVIR~NTAL PB $$g-8228 .RCO Alaska, Inc,, Eastern Operating Area Prudhoe Bay/GPMA, Phone: 907-659-8270 Final Agency Report T414 P.O2/OZ F-022 LOCATION OF DISCHARGE: DSI 1 ADDITIONAL LOCATION INFO, Ddllsim 1i-12 TIME OBSERVI~D; I1 :$5:00 AM ~ 02/06/2000 REPORTED BY; TO: LINDA ALLEN, F'F.C TECH ADEC; 2/23/00 Final Fax ADNR: 2/23/00 Final Fax NSB; F~ 2/8/00 Other: AOGCC 2/23/00 Final RESPONSIBLE GROUP; TYPE AND AMOUNT: RECEIVED ARCO ALASKA 1NC. Oil & Ga8 Gon~. Camm~mion 60,0 Total Gallon(s} ....... 0,0 GaBon(s) Unto Tundra, cove6ng 0,0 area 0.0 Gallon(s) Into Warm', covering 0.0 area 0.0 Gallon(s) Inside Secondary Containment 0.0 Gallon(s) Into Building 100 % CRUDE CAUSE OF DISCHARGE: ENVIRONMENTAL DAMAGE: EQUIPMENT DIFFICULTY Casing Flange at ] 3 3/8" casing hanger starred leaking alter GA pre.q.~ure rose (rom 0 to 440 PSI during .or~nal opet'ations (1000 PST normal safe working pressure). Investigation revealed that the tlange has been repaired afte,' a similar leak 6 years ago. None. The spill wa~ contained on Mir gravel pad, CLEAN UP ACTIONS: CLEANUP vERIFICATION: AMOUNT OF SPILL RECOVERED: PREVENTIVE ACTION: Tho spill response team wu~ called out to thc spill, Recovered snow and ice with loade~. Te~spone¢l to Pad 3 for disposal, Recovered contaminated gravel with ~upersacker and tran.~Im~texl to G&I for disposal, VISUAL 100% Better documentation or' annular peoblems. Possibley including a rcmark on wells group scl~ematic. DISPOSAL/RECYCLE LOCATION: DRILL SITE 4 (GRIND & INJECT) PAD 3 EAST SNOW PIT COMMENTS: THE SPILL WAS NOT REPORTED TO THE AGENCIES UNTIL A DAY LATg. R BECAUSE THE ESTIMATED VOLUME WAS ORIGINALLY THOUGHT TO BE LESS THAN 42 GALLONS. ARCO A~aska, Inc. Date' Subject: From/Location: Telephone: To/Location: P.O. Box 100360, }horace, AK Jan 28, 1994 Transmittal #: ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 94016 99S10~ ~. iWell ; Number 70-/4 i 1-3 'TT'-- 5'7' J 1-11 ~'0- 2~ ~ 2-29A vt¢-¢q ~ 3-2 ~ 3-2 ~-~Z~/ 3-22 !\ 3-22 i \3-22 qt~g0! 3-35 ~~ 3-36 7~-5~J 4-13 qt-~ 5-355.35 ~i 9-13 ~5-~ i 9-30st 11-24 oi/15-7 ¢% 15-7 ~~ 17-13 Number of Records:24 DeGrey i Log Datei Tool Type i Run, (M-D-Y) ¢0c-~ ~ .i Scale 1-14-94 ! Tubing Puncher i, 1,5" 1-14-94 ! Perf Record ! 1, 5" I 1-13-94 i 1-18-94 ! 1-19-94 i 1-15-94 ! 1-10-94 ,, i 1-19-94 ~ 1-16-94 I 1-10-94 ! 1-21-94 i 1-20-94 { 1-15-94 i 1-18-94 i 1-18-94 i 01-14-94 ! 1-22-94 ! 1-19-94 I 1-17-94 ----i 1-23=-94 1-22-94 : 1-17-94 ! 1-8-94 I i 1-20-94 Bridge Plug ~,~,~ ~:~, 5" CNL !~ 1, 5" Bridge Plug ¢j~ 1, 5" Leak Determin IF~tP~I,, 5"/~'~, Perf Record i 1, 5" Brid Leak Detect Perf Record Prod Ini Profile IBPSetting Prod Leak Detect CompI R Contractor Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch 'Sch Sch Sch Sch Sch Sch Sch Sch I 5" Leak Detect Tubing Cutter CompI Record ~ 1, 5" Tubing Cutter _~. 1, 5" Tubing Puncher ~,~1, 5" Patch Settincj ~ 1, 5" Dual Burst TDTP f 1, 5" PBOE Document Control Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon state Of AlaSk~ Mobil RECEIVED FEB 0 1 1994 AJaska Oil & Gas Cons. Commission Anchorage Please acknowledge receipt by signing and returning a copy of transmittal. By: /,_,... Date: ARCO Alaska, Inc. I$ a Stesi;~ry of AtlantlcRichtleldCompeny ARCO Alaska, inc. Date: Jan 19, 1994 P.O. Box 100360, An~-~'~rage, AK Transmittal #: 94012 99510~ ~ Subject: ARCO Cased Hole Finals From/Location: John E. DeGrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution Well Log Date Tool Type Run, Scale Contractor Number (M-D-Y) 1-33 01-05-94 CNL 1, 5" Sch *02-08. 01-09-94 CNL 1, 5" Sch 02-22 01-04-94 Perf Record/(,~.t ¢~.g. 1, 5" Sch 03-10 01-~9~94 1~..,~. GNE 1, 5" Sch 3-15A 01-08-94 Prod Prof 1, 5" ~*'3-25A_ 12-26-93 Pref Record 1, 5"I Sch 4-30ST 01-07-94 Prod Profile 1, 2"&5" 4-32 12-26-93 l Prod Profile 1, 1"&5" 4-32 01-04-94 I Leak Detect 1, 5" 6-01 01-07-94 t Dual Burst TDTP 1, 5" i Sch 6-02 12-27-93 ~ CNL 7, 5" t Sch 9-13 01-05-94I Alpha Tubing~i~z~3, 2"&5" i Sch 9-29 01-03-94 ~ Bridge Plu9 1, 5" 11-01A 12-28-93 i Perf Record xi 1, 5" i Sch 11-I 2 01-06-94 Leak Detect 1, 1 "&5" 14-01A 01-09-94 Complet Record 1, 5" Sch ':14-01A 01-09-94 Perf Depth Cntl" 1, 5" Sch _*~*'14~4 12-27-93 · Prod Profile 1, 5" Sch 15-22 12-27~93 Perf Record 1, 5" ~ .Sch 15-22 01-06-94 Perf Record 1, ~" '- Sch 16-09A 12-28-93 Perf Record 1, 5" Sch 17-13 01-08-94 Patch Set Record 1, 5" t Sch _ ' ~'/,,"--IZz. * 02-08 ~e co~t m~. depth is 9850.0 F & the correct min. depth is 9550.0F ., _. :. ::.: .' . ** 3-25A The corr~t API¢ is 50-029-21021-01 ' ', '.~ '-.. : *** 14-04 The co~t API¢ is 50-029-20320-00 ' . ~ ? .;~,~';~' ..' -' Number· of.- ReCords: 22 '~:~;~.~,~:~;:~: PBOE Document Control Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon State of Alaska Mobil Please acknowledge receipt by signing and returning a copy of transmittal. By: ~/A~-~~Z~., Date: RECEIVED / :- :.: :.::5:i.,. .::)'-::.: : ,:: ::.:~% : : ' . · . ARCOAla~ka, ln~lsaSubsldla'YofAllantlcRlchfleldC~ ~-:;~.!:.~.; ~:.':~:;..,~;'.: ' , -. dAN21 1994 . :: ,; :~ :... ' Alaska Oil & Gas Col'Is. ~ . -:..: ,,, .:;:-,~:. ::-::~:':. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-4-94 REFERENCE: ARCO CASED HOLE FINALS 5-7 11-30-93 Prod Proflle~l~"?l~la~,~ 1, 5"~t~4~ch 5-23 11-30-93 Dual Burst TDT-P Run 1, 5" Sch 6-6 11-30-93 Perf Record ~~z~gz Run 1, 5" Sch 6-12A 12-02-93 PerfRecord 'i~0o-~l~? Run 1, 5" ~ch 11-12 12-02-93 Prod Profilei~c~Pi~a}./~'(Run 1, 5''/z~~ch 11-18 11-29-93 ~od ~ofile-~¥n ~;~,~'~'~ R~ 1, 14-2 11-26-93 ~/G~~L ~F'~g~ R~ 1, 5''q~''~/;c° 14-5A 12-01-93 Completion '-.~.~C~Scc~ R~ 1, 5" Sch 14-43 12-01-93 Pe~Record~?~-~q~i~ R~ 1, 5" Sch 16-17 12-03-93 ~b~g GLM Packer R~ 1, 5'''~z<a~''';'~/:' Sch /18-23A 11-24-93 ~~ (1~} ?~.~.-v~-c R~m 1, 5" ~18-23A 12-01-93 CBT/GR/CCL ~lo~S R~ 1, 5" '~ Sch ~8-23A 12-01-93 USIT (e~;) ~ ~lor R~ 1, 5" ' ~ Sch # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA # PHILLIPS # ANO8 GEOLOGY # EXXON # MOBIL The corrected well name is 14-2 and the corrected API# is 50-029-20318-00. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: REFERENCE: '~-11 12-18-93 ~2-~ ?-°t 1-18 12-12-93 ~~-22 12-03-93 75 ~___-.239 '3__1-25 12-17-93 ~~ ~-6 12-05-93 ~-~ 2-22 10-22-93 ~ L · 12-20-93 ~~6 12-11-93 ~O~ 4-1 12-06-93 ~~- 1 lA 12-13-93 ~i~ ~'~_4-23A 12-14-93 ~'~-~ ~_4-31 12-11-93 ., . ]~ 4-41 12-14-93 '¥i~- ifa~ 5-28 12-10-93 %--~k. 6-2 12-20-93 ?~(-L- ~_~} 6-16 12-15-93 ' ~- ;9-1 12-5-93 .... ~9-1 12-9-93 ~?~t _9-20 12-19-93 ..... ~~_._9-29 12-13-93 ~-36A 12-17-93 ~-36A 12-17-93 m-o7-93 ~t~ 11-12 12-06-93 ~~ 1-13A 12-14-93 ~4-1 12-5-93 · ~~15-9A 12-9-93 ~-17 12-4-~3 ~ ~-23 12-1 q~l 6-29A 12-18-93 $¢~18-29A 1-3-94 ARCO CASED HOLE FINALS CNL (CH) l~?_.Zo---io~S50 Run Leak Detect }~f~,q/T'~-12/¢r¢5~br' Run Perf Record ~/-~ (~0 --105oo Run Prod Pronlei %(0 I-'Semi ;a-e~]~ r.~Run PerfRecord ~O\~%-I%qqO - Run TDTP (depth corrected) Run Inj Profile i .~t~,,~ )-[em¢l¢ce%$ Run PeffRecord IZ~qt~--tZ-aq 0 Run Perf Record ~c~0 -flSu~o Run Perf Record l oo a o - I t¼oo Run Dual Burst TDT-P (~, , Rrm Prod Profile N¢,,~ b'~'.'m¢!e!%)(:f~' Run Perf Record a*~,'.5. --~-.-'~£ ,~ Run Dual Burst TDT-P IL3 ~ Run Production/.-~;i~ ~ ?e n'.i::: ~?.-e~ .L a:a.: % Rrm Prod Profile ,%.'~ Leak D ete ct } ?~ 5 !-~;'~;i~?,', ;~ ~'/,'- Leak Detecti MI Inj Profile ~;,gL-'~ T-4',~,c :¢':;--';i.e~.~ Run CNL} Cfi3T&~ ~0~0 ~r4Lict~' Run Dual Burst TDT-P/GR , ~ IRun Prod Proltle~t2:,0 Produc onl Prod Proflle/5¢w~ T~ Curt. ex q.~0 ~q'?f't( Rrm GR/CCL (ii, P,) c~¢0 "r'*/:~90 Rrm et c on Leak Detection I¥~e5[ '?-tm(~ 5car,) Run Perf Record ! 19o~- i-LL ~2~ Rrm 1, 5" Sch 1, 5' ¥:~-00 - c/ZOo Sch 1, 5" Sch 1, 5" citgo .deo'zo Sch 1, 5" Sch 1, 5" ¢/C0m --' 9"'550 Sch l, 5" ! tO00 -tZ~5~o Sch 1, 5" Sch l, 5" Sch 1, 5" Sch t, 5" q'~P, -R::/-2-~ Sch 1, 5" q%a ~ I.:~! i~; Sch 1, 5" Sch 1, 5" ;'-": ?' -:'>';'~'? i Sch 1, 5" f~::.~ S' :',; u, :7:7Sch 1, 5" ('i ':C'C -- '-'."'i (': ~.L Sch 1, 2"&5"C }'c -lc .'-4 eSeh 1, l"&5"--.-': ::-_- - l, 5"':[', L:.; --~')'-~ C n; Sch l, 5" ~qC~" ' '~ ~ ~c,o Sch 1, 5" Sch 1, 5" '-lo'3o~q~ q..-k Sch 1, l"&5" 0-- I 1~2.O Sch l, 5" izA~O- 17xoq S Sch l, 5" q~50- IOO~'ul Sch 1, 5" Sch 1, 5" Sch 1, 2d_', 5"a~z~" ~-'-'~> 1,~'&5"90-- 11~'5(2 Sch 1, 5" Sch 10-19-93 TDTP (depth corrected) Run I, 5" Please sign and return t~e atta~ched cgpy a~, ~)ceipt of data. RECEIVED John E. DeGrey AT0-1529 # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA APPROVED Trans# 94002.. # PHILLIPS t/il ,~ # ANO8 GEOLOGY # EXXON # MOBIL The correct well name is 4-1lA and the corrected APl# is 50-029-20286-01 The correct well name is 4-31 and the corrected API# is 50-029-21334-00 The correct wen name is 18-29A and the corrected APl# is 50-029-22316-01 ARCO Alaska~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-10-93 REFERENCE: q~-24A ~-!~1 ~1-30 ~4-40 ~?_~~ 9-13 -26 -42 1-12 1-18 ~-~ * 11-22 7~ ¢0 ~-1 ~-1 ~~-~0 7-1~ 7-14-93 7-5-93 7-11-93 7-17-93 7-17-93 7-10-93 7-6-93 7-6-93 7-8-93 7-11-93 7-3-93 7-3-93 7-9-93 7-4-93 7-4-93 7-8-93 7-2-93 7-16-93 7-16-93 7-5-93 7-6-93- 7-9-93 7-13-93 7-12-93 Completion Record llun I, 5 Perf-Record ~)0u-~z~ R-_n 1, 5" Inj Profile ~ ~o-~c~ Run 1, 5" Peri Recordl~'~I~'~z5 R-n 1, 5" Prod Profile ~t~°-~5% Run 1, 5" ~ucflon ~g ~R- 1, Sch Sch Sch 8ch Sch Sch Sch Production Log~>-~OSORun 1, l"&5" Sch Completion Record Peri Record ~'t~-~b~q% Run 1, 5" Sch Peri Record )z%o-tz~ ~r~ R.n 1, 5" Sch Peri Record%~/)-a~c~ R~_m 1, 5" Sch Leak Detect ~a~-)o050 Completion Record Leak Detect Leak Detect ~o~5~o l~m! Burst TDTP R-n I' 5" ~c~o_ou~.Sch Run , ~" ~Sch Run 1, 2" o- ~0~5 Sch Run 1, 2"&5" Rl111 1, 5"~0-~05~Sch Peri Record ~v~co- ~z~51 Run 1, 5" Sch Tie-In Log- IBP ~0a~b~R.n 1, 5" Sch Leak Detect ~-a%~o R!!n 1, 2" Sch Peri Record ~s~a~ Run 1, 5" Sch lnJ P/oflle/Data hc Rim 1, 5'qsf~-I~ZSch Peri Record I~F~-I0%t~ I R.n 1, 5" Sch Leak Detect b- I ot~ R~!Yi 1.2" Sch Please sign and return the attached copy s~s receipt of data. RECEIVED BY ~ .~__~ .... T--'V--- ....... Have A Nice Day! Sonya Wallace APPR OV E D_ __~_____~°~ ATO- 1529 Trans# 93081 # CENTRAL FILES # PI~LI.rPS # CHEVRON # CLINT CHAPMAN # BPX # EXXON # STATE OF ALASKA # MOBIL * The correct top logged interval for 11-22 is 380 feet. ARCO ~lAska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-1-92 REFERENCE: ARCO CASED HOLE FINAL~ 1-4 3-24-92 Prod Profile 3-2 3-19-92 Prod Profile 3-10 3-20-92 Inj Profile 3-17 3-21-92 ~j ~o~e 3-22 3-20-92 ~od ~offie 3-24 3-22-92 ~od ~offie 4-1 ~~ 3-23-92 ~od~offie ~-~-~ ~o~ 11-4 3-30-92 ~od ~offie 11-12 3-22-92 ~od ~o~e 11-24 3-23-92 ~d ~o~e 12-20 3-23-92 ~j ~o~e 18-16~-W 3-24-92 PITS Run 1.5" Camco R-n 1, 5" ~co R-n 1.5" C, aInco R,n 1, 5" ~co RI,n 1.5" Camco Rll- 1.5" Camco R11n 1. 5" CKlnco Run 1.5" Camco R11n 1.5" Camco R11n 1.5" Camco Rim 1.5" Camco R11n 1.5" Camco R.n 1.5" Camco Rim 1.5" Camco Rl!n 1.5" Camco Rim 1.5" Camco Please sign and return ~e a_tta~ch~ as receipt of data. RECEIVED Have A Nice Day? RECEIVED Sonya Wallace ATO-1529 MAY '11 199:~ A]aska Oil & Gas Cons. Commissiorl Anchorage # CENTRAL FILES # CH~ON. D& M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL APPROVED ~ Trans# 92095~' ....... # PHILLIPS PB WELL FU.,F_~ R&D # BPX # STATE OF ALASKA TEXACO PLEA::-;'Ii-:: :::!(:.N AN:;')F;,'ETUF;,'N THE A"f'i'RL:HED c,l::.U[: ........ BY ...... f..., 'r C ' · .~AvE A -..,. E DAY. C 0 F:' Y A S I:;,' Iii C Iii .[ F:"f' 0 F:' D A'i" A,, I) I $ T R I B U l' I 0 N :~: C E i:.! T R A !... F I !_ E :'~ .~: F:' ~"..[ I.. I.. I F" ,.? · ,,.'"' C I"1E V R 0 N P B W E I... I.. F' I t.. E S 1) ~ I:;..' <:.~ )":' ·" '1 '1 ~ -' · ,,."'. F. .... X T F N S I 0 N F.*. X F L 0 R ~.~ I I 0 N '"'.,,. B I::' X '"'.,,- E X X 0 J**J. .~,'~',!*/'f' A "l*' E 0 F' A L A ,*:.:; K A H A 1::.: A l'H 0 N T E X A C: 0 ' :~ ki 0 B I L ARCO ALASKA: INC~ F'~O. BOX i 00.¥6,:::0 ANCFIORAGE, ALA2KA DATE ' 5-8-90 REFERENCE · ARCO RECEIVED Alaska Oil & Gas Cons. Commission Anchorage CASED HOLE FINALS .--~. r 4-i 6-0'.; 6- ~ 7 4-9-90 7 - 4 4 '- :2 $ - 9 (') 7-i 6 4-23-96, 7-'33 4-2.S-90 i I-t 4-'"'2-90.- i i-;5 4-i8-90 i i -i 2 4-i 7-90 i t -25 4-'~¥-90-. i -°- t 0.. 4.-i'=~- m,:.).. ~-.-.( i ~-26 4/20-2t/90 i 4-2~ 4-t t -96' t ~-i 4-t t -9O i $-i t 4-22-90 t $-i $ 4-i 4-9e t ~-2£:' 4- t i -90 t 6-8 4-i i 6-i 9 4-t F'LEASE SIGN AND RETUR PRODUCTION PROFILE F"r TS PRODUCTION PROFILE INJECTION PROFILE INJECTION F'ROFILE F'RODUC'FION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE GAS' LIFT S'URVEY F'RODUCT!ON PROFILE INJECTION PROFILE TEMP SURVEY LEAK DETECTION SURVEY PRODUCTION PROFILE TEMF' SURVEY PRODUCTION PROFILE PRODUCTION PROFILE LEAK DETECTION SURVEY LEAK DETECTION SURVEY N THE ATTACHED COPY AS RUN t , i "¢..,5' RUN i, 5 ' RUN i , _..~'" RUN t, 5' RUN i, RUN RUN 1, ...~" RUN ~., 5' RUN i, t"&5' RUN i, 5" RUN RUN ~ , 5' RLJN t, 5' RUN RUN RUN t , 5' RUN i , RUN ~ , 5 ' RUN t, 5" RECEIPT OF DATA RECEIVED BY HAVE A NICE DAY! SALLY FtOFFEC:K ER ATO- t 5,;.. C A M C O C A M C C) C A M C O C A d C O C A M C 0 C A i"t C 0 C A M C 0 C A i'd C 0 C~HCO CAMCO C A H C 0 CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILE~. ~'~ F'HILLIF'~ CHEVRON F'B WELL FILES D&M R&D EXTENSION EXPLORATION $ BPX EXXON $ STATE OF ALASKA MARATHON TEXACO MOBIL , THE CORRECTED AF'I~ FOR t5-20 I$ 50-029-2tt;t3. .... STATE OF ALASKA ._. ALAS!~'-' '.AND GAS CONSERVATION'~" /IISSION REPOR, OF SUNDRY WELL O EHATIONs: ' 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 136' FNL, 107' FEL, Sec. 33, T11N, R15E, UM At top of productive interval 1971' FNL, 2226' FEL, Sec. 4, T10N, R15E, UM At effective depth At total depth 2559' FSL, 2410' FE, Sec. 4, T10N, R15E, UM 12. Present well condition summary 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 58 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 11-12 9. Permit number/approval number 84-195/9-1054 10. APl number 50 - 029-21212 11. Field/Pool Prudho9 _B.ay. O_iI.Pool Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Sudace 2471' Production 9260' 13032 feet Plugs(measured) 9175 feet 12995 feet 9153 feet Junk(measured) Size Cemented 20" 1950# Poleset MAY 1 o 1990 ~laska 0ii & 6as Cons. Commission ..Anch0rag~ Measured depth 110' 13-3/8" 2520 sx PF 'E' & 400 sx PF 'C' 2529' 9-5/8" 500 sx CI 'G' & 300 sx PF 'C' 9318' Liner 4003' 7" 450 sx CI 'G' 13032' feet True vertical depth 110' 2504' 6793' 9175' Perforation depth: measured 12440-12470'; 12506-12528'; 12562-12574'; 12626- 12656'; 12674-12682' true vertical 8825-8844'; 8867-8880'; 8901-8908'; 8940-8958'; 8969-8973' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8907' MD; 3-1/2", 9.2#, J-55, PCT @ 11963' MD Packers and SSSV (type and measured depth) Baker FB-1 packer @ 11871' MD; 5-1/2", Camco Bal-0 SSSV @ 2172' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attachment 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 1349 6543 707 2074 2795 1271 Tubing Pressure 1771 227 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 ~ ~ ~~-- Title Date Form 10-404 Rev 06/15/88 ,,-,, .,',, ,,'~ ia , n ......... I /"'~--.kA. AT~"% 4A'~O [~4144 4'")%1, AI4 ~ SUBMIT IN DUPLICATE DS 11-12 DESCRIPTION OF WORK COMPLETED SAND DUMP / CEMENT PLUG FOR GAS SHUTOFF 12/27/89: Sand Plug laid in as follows: MIRU, and PT equipment to 4000 psi. RIH w/CT and loaded wellbore w/252 bbls of Crude. Pumped 50 bbls of Sand slurry (3.3# per gal 20/40 Sand, and HEC Gel). Displaced CT w/7 bbls of diesel flush, and 25 bbls of 60/40 Meth - Water. POOH. Rigged down. 12/28/89: MIRU, and RIH to tag top of sand at 12836' MD. POOH. Rigged down. 12/29/89: Additional Sand Plug laid in as follows: MIRU, and PT equipment to 4000 psi. RIH w/CT to tag top of sand at 12836' MD. Pumped 28 bbls of Sand slurry, then 35 bbls of XCD gel/water flush. POOH. Rigged down. 12/30/89: MIRU, and RIH to tag top of sand at 12757' MD. POOH. Rigged down. 1/2/90: Additional Sand Plug laid in as follows: MIRU, and PT equipment to 4000 psi. RIH w/CT to tag top of sand at 12762' CTM. Pumped 14 bbls of Sand slurry (4.0# per gal 20/40 Sand), then 30 bbls of XCD gel/water flush. POOH. Rigged down. 1/3/90: MIRU, and RIH to tag top of sand at 12693' MD. POOH. Rigged down. 1/6/90: Cement Cap Dump attempted as follows: MIRU, and PT equipment. RIH w/ cement started down CT. Hit obstruction at 6306' MD. Some cement entered well. POOH. ' Replaced CT nozzle and displaced cement from CT w/Meth - Water flush. Shear disk was broken. RIH w/ CT to clean out cement from CT and wellbore w/Biozan, and Mud Acid. Hit obstruction at 3672' MD. Pumped 94 bbls of Biozan, and worked to 4517' MD, then pumped 128 bbls of Meth - Water flush. Switched to acid, and pumped as follows: 5 bbls 7.5% HC1, followed by, 5 bbls 6% HC1 - 1.5% HF, followed by, 5 bbls 7.5% HC1, followed by, 5 bbls 6% HC1 - 1.5% HF, followed by, 15 bbls Meth - Water. Worked CT down to 5540' MD, and resumed pumping, 5 bbls 7.5% HC1, followed by, 5 bbls 6% HC1 - 1.5% HF, followed by, 15 bbls Meth - Water, followed by, 5 bbls 7.5% HC1, followed by, 5 bbls 6% HC1 - 1.5% HF, followed by, DS 11-12 DESCRIPTION OF WORK COMPLETED SAND DUMP / CEMENT PLUG FOR GAS SHUTOFF 1/6/90 (cont.): 16 bbls Meth - Water, followed by, 3 bbls 7.5% HC1, followed by, 4 bbls 6% HC1 - 1.5% HF, followed by, 32 bbls Meth - Water. Could not make additional headway past 5540' MD. POOH. Rigged down. 1/8/90 : MIRU, and RIH w/broaching tool. Broached nodes and tagged top of sand at 12667' MD. POOH. Rigged down. 1/15/90 : Cement Cap Dump was completed as follows: MIRU, and PT equipment to 4000 psi. Loaded wellbore w/275 bbls of seawater. RIH w/CT and tagged top of sand at 12638' MD. Pumped 10 bbls of cement on top of sand. POOH while displacing CT w/60 bbls of 60/40 Meth - Water. Rigged down. 1/26/90 : MIRU, and RIH to tag top of cement cap at 12682' MD. POOH. Rigged down. Returned well to production and obtained valid production test. Perforation Summary: Perforations remaining open and uncovered: 12440 - 12470' MD Ref. Log: BHCS 12/2/84. 12506 - 12528' MD 12562 - 12574' MD 12626 - 12656' MD 12674 - 12682' MD Perforations covered with Sand / Cement Cap: 12682 - 12684' MD Ref. Log: BHCS 12/2/84. 12700 - 12806' MD ARCO Alaska, Inc. Prudhoe Bay ~ .=lineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 20, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 11-12, Permit No. 84-195 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/JMH/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 11-12)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA .~-,. ALASK,a --'L AND GAS CONSERVATION C~, MISSION APPLICA 'ION FOR SUNDRY APPROVA S 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. Abandon Suspend Operation shutdown Alter casing Repair well Plugging Change approved program Pull tubing 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 136' FNL, 107' FEL, Sec.33, T11N, R15E, UM. At top of productive interval 1971' FNL, 2226' FEL, Sec.4, T10N, R15E, UM. At effective depth Re-enter suspended well Time extension Stimulate Vadance Perforate At total depth 2559' FSL, 2410' FEL, Sec.4, TION, R15E, UM. 12. Present well condition summary Total depth: measured true vertical 5. Type of Well Development Exploratory Stratigraphic Service Effective depth: measured true vertical Casing Length Conductor 110~ Surface 2471' Production 9260' Liner 4003' Other X 6. Datum of elevation(DF or KB) 58' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 11-12 9. Permit number 84-195 10. APl number 50 - 029-21212 11. Field/Pool Prudhoe Bay Oil Pool 13032 feet Plugs(measured) 9175 feet 12995 feet 9153 feet Junk(measured) Size Cemented Measured depth Tr'"l~:':~'l'~il ~lepth 20" 1950 # Poleset 110' 11 O' 13-3/8" 2520 Sx PF 'E' & 400 Sx PF 'C' 2529' 2504' 9-5/8" 500 Sx CI 'G' & 300 Sx PF 'C' 9318' 6793' 7" 450 Sx CI 'G' 13032' 9175' Perforation depth: measured 12440 - 12470'; 12506- 12528'; 12562- 12574'; 12626- 12656'; 12674- 12684'; 12700 - 12806' true vertical 8825 - 8844'; 8867 - 8880'; 8901 - 8908'; 8940 - 8958'; 8969 - 8975'; 8985 - 9047' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8907' MD; 3-1/2", 9.2#, J-55, PCT @ 11963' MD. Packers and SSSV (type and measured depth) Baker FB-1 Packer @ 11871' MD; Camco Bal-O SSSV @ 2172' MD. 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation November, 1989 16. If proposal was verbally approved [ Name of approver Date approvedI Service 17. I herel~f certify th~ the foregoing is true and correct to the best of my knowledge. Sig ned ,~7~,~ _/~~ Title Operations Engineering Manager FOR COMMI~RION HgI= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10----~J/~> z.). ORIGINAL SIGNED BY LONNIF C. SMITH Approved by order of the Commissioner I15. Status of well classification as: Oil X Gas Suspended Date [Approval No. Approved CoPY Returned Commissioner Date Form 10-403 Rev 06/15/88 .11 II IF: I~! I-IF:I SUBMIT IN TRIPLICATE Well 11-12 Sand/Cement Plug Gas Shut Off Preliminary Procedure Objective: Set a sand plug with a cement cap to cover the lower two sets of perforations to shut off gas production from a Tango shale underrun. 1. Make a gauge ring run and tag PBTD. 2. RIH with coiled tubing. 3. Place +_250t of sand in the wellbore, covering the bottom two sets of perforations: 12674'-12684' and 12700'- 12806'. 4. Tag top of sand. Top should be at +12670' MD. 5. With coiled tubing, place approximately l0t of cement on the sand. 6. Allow the cement to set up and tag cement top. Top should be at +12660' MD. 7. Bring the well on production. Test the well. Other well information: Current well status: Producing Expected static bottom hole pressure: 3608 psi ,5 4 2 COILED TUB~Ni3: UNIT BOP EOU ! PHE NT 1. ~:)00 PSI 7" WELLHEAD CONNECTOR 2. 5000 PSI 4 1/16" PIPE RAJAS 3. ~)00 PSI 4 1/6" HYD~ULK~ SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. ~)00 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 2 N~IRELINE BOP EOUIPMENT _ 1. 5000 PSI ?" WELLHEAD CONNECIOR FLANGE 2. 5000 PSI WIRELINE RAIDS (VARIABLE SIZE) ,3. ~,0OO PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-DFF ARCO ALASKA, INC. F'.O. BOX iOnS60 ANCHORAGE, ALASKA 995i ¢~ __ DATE' i 0-;~:~.-89 REFERENCE' ARCO CASED HOLE FINALS i-4 t,;.~-t¥-89 F'RODUCTION F'ROF'ILE RUN t, 5' CAMCO i-6 t0-22-89 CNL-GR RUN t, 5" A'FI_A$ i-6- i 6,-'-~t.. -89 F'DK-~ 6,0/GR/CCL RLJN i , 5" A-FL.A;S' ~i-t6 ~¢-i6-89 F'RODUCTION PROFILE RUN t, 5' CAMCO i-i7 i~-t9-89 F'ERF RECORD RUN ~, 5" SCH t'2S ~-2~-89 CNL-GR RUN ~ , 5" ATLA,? -~_, t¢-t~--8e~ , PRODUCTION PROFILE RUN i, j~' CAMCO ~-26 ~-t5-89 PRODUCTION PROFII_E RUN ~, 5" CAMCO 1-29 ~-~4-89 F'RODUCTION F'ROF'ILE RUN t, 5' CAHCO 2-5 ~8-i8-89 CNL RUN 2, 5' SCH 2-t° t8-i6-89 TEMF' SURVEY RUN t, 5' ~" ...... ~. .,AMUU 2-25 t 6,-25-89 CNL-GR RUN ~ , 5' A'I'I_A~ 4-32 ~'8-23-89 CNL-GR RUN t, 5' ATLAS ~4-32 -t~-2S-89 PDK-1erD/GR/CCL RUN ~ , 5' ATLAS ~7-~; t~-t6-89 F'RODUCT]:ON PROFILE RUN ~, 5' CAMCO ~9-5 ~(D-~-89 PRODUCTION PROFILE RUN ~ , 5' CAMCO 9-t6 ~-~i-89 INJECTION PROFILE RUN i, 5' CAMCO t~-t2 ~¢-7-89 PRODUCI'ION PROFILE RUN t, 5' CAMCO 11-~5 Jt~-~3-89 TEMP RUN ~, 2'&5' CAMCO t4-23 ~(D-i4-89 COMPLETION RECORD RUN ~, 5' SCH . ~"} ~ t6-ii te-~-89 LEAK DETECTION RUN t, ~ CAMCO ~6-2~) te-4-89 TEMP RUN t, 5' CAMCO t7-4 t6,-t4-89 F'RODUCTION PROFILE RUN 1, 5' CAMCO ~8-t6 9-t8-89 PITS RUN I , 5" CAMCO F'LEASE SIGN AND RETURN THE ATTACHED COPY RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER ATO-t529 AS RECEIPT OF DAi"A DISTRIBUTION ~ CENTRAL FILES .~ PHILLIPS ~ CHEVRON F'B WELL F'ILES D & M R & D ~ EXTENSION EXPLORATION ~ BPX ~- EXXON ~- STATE OF ALASKA MARA I'FION · ~ TEXACO · TFIE CORRECTED. .. API¢ FOR 2-25 IS 5)-e,9-,~766.."~ '" ' "" · · · * THE CORRECTED AF'I~ FOR i4-2S IS 5e-029-2e757 .~. THE CORRECTED API~ FOR t6-ii 1S 5(~)-(D29-2~5i6. ARCO ALASKA, F'.O. B-OX i00360 ANCHORAGE, ALASKA 995 J O DATE' 9-27-89 REFERENCE' ARCO CASED HOLE FINALS 2-24 9-i 8-89 3-2 9-i 5-89 4-J 9-7-.89 5-- i i '?-8-89 6-2J 9-J 4-8? '~ '~-~ 7-20-89 J J -i 0 ?-24-89 J J-J 2 ?-23-8? i i -i 7 9/i i -i 2/89 i 2-t3 9-i 7-89 i 4-3i 9-i i -89 COLLAR/PERF COLLAR/PERF NOISE SPINNER SURVEY CNL-GAMMA PERF RECORD PERF RECORD PERF RECORD COLLAR/F'ERF COLLAR/PERF COLLAR/PERF ~-~ F'LEASE SIGN AND RETURN THE ATTACHED COPY RUN t, 5' RUN t, 5' RUN t, i ' RUN t, 5" RUN t , 5' RUN t, 5' RUN t, 5" RUN 1 , S ' RUN i, 5" RUN J , 5' RUN J , 5' AS RECEIPT OF DATA~ ATLAS Al'LAS HLS A TEAS I-ILS HLS ATLAS Al'LAS ATLAS HAVE A NICE DAY! SALLY HOFFECKER Anchomg~ APPROVED .~__ 'FRANS~ DISTRIBUTION CENTRAL FILES CHEVRON EXTENSION EXPLORATION EXXON MARATHON MOBIL F'IqlLLIF'S F'B WELL FILES R & D BF'X STATE OF ALASKA TEXACO STATE OF ALASKA Al. \ OIL AND GAS CONSERVATION COMk 3N REPOR OF SUNDRY WELL OPERAi'IONSU 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 5. Type of Well: Development Exploratory Stratigraphic Service . Location of well at surface 136' FNL, 107' FEL, Sec. 33, T11N, R15E, UM At top of productive interval 1971' FNL, 2226' FEL, Sec. 4, T10N, R15E, UM At effective depth 2589' FSL, 2403' FEL, Sec. 4, T10N, R15E, UM At total depth 2559' FSL, 1420' FEL, Sec. 4, T10N, R15E, UM 6. Datum elevation (DF or KB) 58' RKB feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DSl1-12 9. Approval number 9-619 0. APl number 50-029-21212-000 1. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary: Total depth: measured I 3 0 3 2 feet true vertical 9175 feet Effective depth: measured true vertical Plugs (measured) I 29 7 5 feet Junk (measured) 91 5 3 feet Casing Length Size Cemented Measured depth Conductor 1 I 0' 20" 1950# Poleset I 1 0' Surface 2529' 13-3/8" 2520 sx PF "E" 2529' 400 sx PF "C" Production 9318' 9-5/8" 500 sx Class G 9318' 6794' 300 sa PF "C" Liner 4003' 7" 650 sx Class G 9029-13032' 6636-9176' True vertical depth 110' 2504' 13. 8941-8959', MD Camco BaI-O SSSV @ 2195' MD Baker FHL Packer @ 11921' MD Perforation depth: measured 12440-12475', 12506-12528', 12562-12574', 12626-12656', 12674-12684', 12700-12806' true vertical 8826-8848', 8867-8881', 8902-8909', 8970-8976', 8985-9048' Tubing (size, grade, and measured depth): 5-1/2", L-80, 0-8971' MD 3-1/2", J-55, 8971-12004' Packers and SSSV (type and measured depth): Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 2601 17998 644 N/A 3814 18530 1028 N/A Tubing Pressure 1675 1201 15. Attachments Copies of Logs and surveys run Daily Report of Well Operations 6. Status of well classification as: Oil x Gas __ Suspended __ Service 17. I hereby/~ertify that the foregoing is true and correct to the best of my knowledge. Signed['//,~_,~~Z~j Title/~ ~ /'/lf~,, Date Form 10-404 Rev 10/01/88 -/ ~ ~' SUBMIT INDUF~.IC,~TE DAILY REPORT OF WELL OPERATIONS ARCO Alaska, Inc. re-perforated DS 11-12 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 7/23/89 (12440'-12475' MD, Ref Log: BHCS 12/2/84). This well was perforated approximately 500 psi underbalanced and flowed to clean-up. The wellbore fluid at the time of perforating was the produced fluids; oil, water, and gas. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. The SSSV was installed at the conclusion of the perforating and clean-up operation. A short summary of the work is given below. - Began perforating operation on 7/23/89. - RU perforating unit and pressure tested equipment to 3500 psig. RIH w/ gun #1, tied-in, and shot 12440'-12450' MD @ 0.13 SPF. SI well. POOH. All shots fired. - RIH w/ gun #2, tied-in, and shot 12450'-12475' MD @ 0.13 SPF. - SI well. - POOH. All shots fired. - Secured well. RD. ARCO f:'.','[..A:i':'KA, INC,. i::' ,. 0, BOX i (') (') ~?; 6 (') ANCHORAGE: AI..A£'KA 99.~5'i (~) D A T E: ' '? -' 2 ~2 -- 8 9 R iii: I::' 1:::1:;..' E N C I::: · A R C 0 M A G N E: T I C 'I"A P f:i: ( 5' ) W I 'T' I--i i... :t: .'.:-:,"i" I N (:.;. ( $ ) i 'i .... ,~ 9 ,-'-~ .... ::":::' F'NI /"I"EHF' ..JUFI:-~'''~ ........ ';" , ,_ '"' ,.., ......... ,' .3-.~ I:.', di';~ U N i i i -.-'21:.!; 7-i 2-.89 C:NL .... JOP,:,~:-,:'::5::~;':?7 i:,.:LJN i F'L. EA,?E ;~,7I(;N AND i:~.:IE]"UF,:N TH, E A'T'"!,"AUHF'D COF'Y A;'-:: i:;.'.iZCli:I'!::'F OF DA'FA,. !'-.': I.:.: C E ]: V E D B Y HAVE A NICE DAY! ;!i:A i..i... Y HOF:'FI!i. CK E A 'i" 0 - i '5 2 9 DIS'TRIBUI'iON CENi'RAL FILES (CH) CHEVRON TAMHAS' BROWN (OH) EXXON MARATHON MOBIL P Fi I 1_ L I F' $ F'B WELl_ FILE5' R & D · ,,-" BPX ,~TAI"E: OF ALASKA 'i"E:XACO ARCO ALA;~'KA, INC. ~-' I::'.O. BOX J <~S6(') ANCHORAGE, ALA~'KA 99~0 DAI'E: '7-i i -89 REFERENCE' ARC(] CA~'ED HOLF F'INAL,$' 4-t 6-29--89 CNI. 4-4 6-29-89 CNI. t t--t 2 '7-'t-89 TEMP t i-t 2 7-t-89 CNL. RUN 7, 5" I;:UN 6, i::.'.UN t, 2'&D" I-:I. JN i, 5" I:'LEA~'F ~?IGN ANI) REI'URN I'HE Afl'ACHED COPY AS' RECEIFI1' OF DATA, - RECEIVED BY . , _~,___~ .. D I $' T R I B U T I 0 N CENTRAL F!LE.~ CHEVRON D & M EXI'EN~'ION EXPLORATION EXXON MARAI'HON- MOBIL -,,- F'HI LL I P,S' F'B WELL F'ILEi3' R & D · ,,--" BF'X ~- ~"I'ATE OF ALA~'KA ~ TEXACO N' tS H SCI'.I .':.; C H STATE OF ALASKA ,. ~'--' Al,~- ..... ~ OILAND GAS CONSERVATION COM~ .... 3N " ' A PLI TION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Change approved program ~Pull tubing Time extension Stimulate Variance Perforate x Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510 . 5. Type of Well: Development x Exploratory Stratig raphic Service ~ Location of well at surface 136' FNL, 107' FEL, Sec. 33, T11N, R15E, UM At top of productive interval 1971' FNL, 2226' FEL, Sec. 4, T10N, R15E, UM At effective depth At total depth 2559' FSL, 1420' FEL, Sec. 4, T10N, R15E, UM 6. Datum elevation (DF or KB) 58' RKB 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 11-12 9. Permit number 84-195 10. APl number 50-029-21212-000 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary: Total depth: measured I 01 20 feet Plugs (measured) true vertical 9019 feet Effective depth: measured 1 0 0 6 0 feet Junk (measured) true vertical 8982 feet Casing Length Size Cemented Conductor I I 0' 2 0" 1950# Poleset Measured depth True vertical depth 110' 110' Surface 2529' 13-3/8" 2520 sx PF "E" 2529' 2504' 400 sx PF "C" Production 9318' 9-5/8" 500 sx Class G 9318' 6794' 300 sx PF "C" Liner 4003' 7" 650 sx Class G 9029'-13032' 6636'-9176' Perforation depth: measured 12674-12684', 12700-12806' true vertical 8826-8848', 8867-8881', 8902-8909', 8970-8976', 8985-9048' Tubing (size, grade, and measured depth): 12440-12475', 12506-12528', 12562-12574', 12626-12656', Packers and SSSV (type and measured depth): 8941-89~'E C E IV 5-1/2", ,-80, 0-8971' 3-1/2", J-55, 8971-12004' MD JUL 1 8 §8-3 Camco BaI-O SSSV @ 2195' MD Baker FHL Packer @ 11921' MD Alaska 0ii& Gas Cons. 13. Attachments: Description summary of proposal x Detailed operations program BOP sketch 14. 16. Estimated date for commencing operation 3Q '89 If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas__ Suspended__ Service 17. I hereby/'pertify that the foregoing is true and correct to the best of my knowledge. Signed '~gP"~/',~~/~~~ Title ,~.i~r ~'/~,~/t. ~/~~ate ~/~o~,~, FOR COMMISSION USE ONLY/ IApproval No. ? _~/~ Approved COPYl Returned ~ . '~-~.-;~) CONDITIONS OF APPROVAL: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner ORIGINAL SIGNED BY LONNIE C. -~MITu Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE issi0~ SUMMARY OF PROPOSAL ARCO Alaska, Inc. proposes to re-perforate DS 11-12 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit. This well will be perforated approximately 500 psi underbalanced and flowed to clean-up (the expected static bottom hole pressure is 3700 psia). The wellbore fluid at the time of perforating will be the produced fluids; oil, water, and gas (currently 5000 STBO, 4600 SCF/STB, and 5% Water) All wireline work will be done through a 5000 psi WP BOP/Lubricator (see attached schematic) tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed perforation interval(s): 12440'-12470' MD Ref Log: BHCS 12/7/84 Alaska Oil & Gas Cons, rSorr~rnissior~ Anchorage 1. 'S000 PSI ?" WELLHr. AD CONN[C10R IrLAN0[ 2, ~)00 PSI WIRI[LIN£ RAMS (VARIABLE SIZ[) 3. SOO0 PSi 4 1/6" LUEIRICATOR 4. 5000 PS1 4 1/6" FLOW TUB[ PACK-Orlr 2 NIRELIN~ 80P EGUIPHENT · ARCO ALASKA, INC. F'.O. BO.X 100360 ANCHORAGE, ALASKA DATE: 3-2-89 REFERENCE: ARCO CASED HOLE FINALS 3-t2 4-2 4-t2 t ~-2 t t-3 t t-3 tt-4 tt-5 t t-'7 tt-~2 tt-t5 t 2-3t t 2-3t t4-t8 t4-i9 t 4-28 t 4-29 t4-33 t5-22 ~8-4 ~8-~7 PLEASE SIG 2-2t-89 PRODUCTION PACKER RUN 2-tG-89 PRODUCTION PROFILE RUN 2-ii-89 PRODUCTION PROFILE RUN 2-3-89 INJECTION PROFILE RUN 2-t-89 PRODUCTION PROFILE RUN 2-2-89 TEMF' SURVEY RUN ~ ~-89 PRODUCTION PROFILE RUN 2-6-89 F'RODUCTION PROFILE RUN 2-3-89 INJECTION PROFILE RUN 2-3-89 TEMP SURVEY RUN ~-~-89~ ~ TEMF' SURVEY RUN 2-i 7-89 CBT RUN 2-i?-89 CET RUN o-no-no CNL-GAMMA RUN 2-~o-no CNL-GAMMA RUN 2~5-89 TEMP RUN o_oo_m~ CNL-GAMMA RUN 2-22-89 CNL-GAMMA RUN t t-23-89 PRODUCTION -PROFILE RUN 2-i2-89 PRODUCTION PROFILE RUN i 2-i3-B? PRODUCTION PROFILE RUN i N AND RETURN THE ATTACHED COPY AS 'RECEIPT OF DATA RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-i529 TRAN$ ~89~9 APPROVED '.~h~ DISTRIBUTION ATLAS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO $CH SCH ATLAS ATLAS CAMCO ATLAS ATLAS CAMCO CAMCO CAMCO CENTRAL FILES. CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS PB WELL FILES R & D SAF'C STATE OF ALASKA TEXACO ~r',,..,~ ALA,?KA, IN'~ F'.O. BOX t0"3S&0 ANCHORAGE, ALA£KA 99"~'i(') CA~E~, HOLE F'T F,, E F.,-,-, :- =,,", ~- -' TI ~_. . ~_r.:_:~-,r_: ARCO NAL&' PLEA&'E SiGN AND RETURN 'i'HE A'i-'Y'ACi4ED "":""~:'Y A;:'.." RECEIVED BY ._.. QFc-2 7-I988--- HAVE A NICE .... ..~,~_ ~ _--~-: Z. ALLY HOFFECKER ATO-~ ~ ---'...%. ! DiZTRIBUTION R E C E I F' 'i' 0 i:: D A'r A ,, ~"' ' IAi C,...N FRM,-- F-, I LE.'-7, CHEYRON · "' EYTEN$1.ON E;,.F,_ORHTION · ~- ..--; EXXON M A F: A T H 0 N "' H 0','---: l L "'~- · ~ F'HiLLIF'$ F'B WELL FILE:? R & D ,~ ~AF'C :$ ZT'ATE OF' ALA~'KA · ~ T~vACO ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 7, 1988 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Comission 3001 Porcupine Drive Anchomge, AK 99501 Dear Mr. Chatterton: RE: DS 11-12 Approval Number: 8-654 Enclosed is the Report of Sunch-y Well Operations detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/RLP:sd Enclosures cc: Standard Alaska Production Company JoAnn Gruber, ATO 1478 File PI(DS 11-12)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C ~ STATE OF ALASKA -~---. AL ,A OIL AND GAS ~SERVATION COMb ,ON REPORT OF SUNDRY WELL OPERATIONS 1. Ci,~erations performed: Operation shutdown~ Stimulate~ Plugging Pull tubing ~ Alter Casing ~ Repair well ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 136' FNL, 107' FEL, Sec. 33, T11N, R15E, UM At top of productive interval 1971' FNL, 2226' FEL, Sec. 4, T10N, R15E, UM At effective depth 2589' FSL, 2403' FEL, Sec. 4, T10N, R15E, UM At total depth 2559' FSL, 1420' FEL, Sec. 4, T10N, R15E, UM Perforate Other 6. Datum elevation (DF or KB) 58' RKB feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS11-12 9. Approval number 8-654 0. APl number 50-029-21212-000 1. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary: Total depth: measured 1 3 0 3 2 feet true vertical 9175 feet Effective depth: measured 1 2 97 5 feet true vertical 9153 feet Plugs (measured) Junk (measured) Casing Length Size Cemented Measured depth Conductor I 10' 20" 1950# Poleset I I 0' Surface 2529' 13-3/8" 2520 sx PF "E" 2529' 400 sx PF "C" Production 9318' 9-5/8" 500 sx Class G 9318' 6794' 300 sa PF "C" Liner 4003' 7" 650 sx Class G 9029-13032' 6636-9176' True vertical depth 110' 2504' Perforation depth: 12674-12684', 12700-12806' true vertical 8826-8848', 8867-8881', 8902-8909', 8970-8976', 8985-9048' Tubing (size, grade, and measured depth): 5-1/2", L-80, 0-8971' MD 3-1/2", J-55, 8971-12004' MD Packers and SSSV (type and measured depth): Camco BaI-O SSSV @ 2195' MD Baker FHL Packer @ 11921' MD measured 12440-12475', 12506-12528', 12562-12574', 12626-12656', 8941-8959', 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Productionorlniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 4195 21130 1500 0 5000 21110 955 0 Tubing Pressure 645 630 15. Attachments 116. Status of well classification as: Copies of Logs and surveys run ~ Daily Report of Well Operations __~ Oil x Gas ~ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 10/01/88 Service Date /~/'~/~ ~ SUBMIT IN DUPLICATE DALLY REPORT OF WELL OPERATIONS Began perforating operation on 9/17/88. RU perforating unit and pressure tested equipment. RIH w/ gun #1, tied-in, and shot 12440'-12470' MD @ 1/10 SPF. SI well. POOH. All shots fired. Secured well. RD. RLP ARCO ALASKA, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 995t0 DATE:- 9-2S-88 REFERENCE: ARCO CA£ED HOLE FINAL 8-i Q-88 8-28-88 8-2?-88 8- f 2-88 8-5-..~38 -9-t 6-88 9-i 6-88 9- i 5.-88 9- i 8-88 9-i '7-88 9-i 7-88 9-4-88 8-~i -88 8-8-88 9- i 6-88 9- l 6-88 8-6-88 '~-:COLLAR/PERF COLLAR/PERF SF'INNER/TEMP COLLAR/PERF COLL. AR/F'ERF VERTILOG COLLAR/F'ERF COLLAR/F'ERF COLLAR/PERF COLLAR/PERF COLLAR/PERF COLLAR/PERF COLLAR/PERF COLLAR/PERF CBT CET COLLAR/PERF PLEASE SIGN AND RETURN 'i'HE AT-t"ACIdED COPY AS RECEIF'T OF RUN RUN RUNS RtJN F:,'U N.S' RUN RUN RtJN R U N RIJN 2, RUN RUN RUN RUN RUN RUNS DATA, GEAR GEAR OTIS GEAR ~. ATLAS' ATLAS A"f'I_AS A ! L.~ Al'LAS ATLAS GEAR GEAR GEAR SCH $CH GEAR RECEIVED BY HAVE A NICE DAY! ~ALLY HOFFECKER AT0-t529 TRANS ~8858~ ARPROVED - DISTRIBUTION CENTRAL FILES ~ PHILLIPS CHEVRON PB WELL FILES D & M R & D EXTENSION EXPLORATION ~ SAF'C EXXON ¢ STATE OF ALASKA MARA"£HON ~'~ TEXACO MOBIL STATE Of ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION W LL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO A1 aska, I nc. 84-195 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21212 4. Location of well at surface 9. Unit or Lease Name 136' FNL, 107' FEL, Sec.33, TllN, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1971' FNL, 2226' FEL, Sec.4, T10N, R15E, UM 11-12 At Total Depth 11. Field and Pool 2559' FSL, 2410' FEL, Sec.4, T10N; R15E; UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 58'I ADL 28328 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 11/16/84 12/06/84 12/28/84'I N/A feet MSLI 1 ., 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ FVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 13032'MD/9175'TVD 12995'MD/1953'TVD YES [~] NO []I 2173 feetMD 1900' (Approx) 22. Type Electric or Other Logs Run DIL/BHCS/GR/SP; GR/CCL, G~yro, C~B~b 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 110' 13-3/8" 72,0# L-80 Surf 2_~29' 17-1/?" 9-5/8" 47.0# L-80 Surf 9318' 12-1/M' 7" 29.0# L-80 9029' 13032' 8-1/2" 450 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) 5~2"/3&" 11963 ' 11871 ' 12506'-12528'MD/8867'-8880'TVD (1 spf) 1 2562'-1 2574'MD/8901 '-8908'TVD (1 spf) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12626'-12656'MD/8940'-8958'TVD (1 spf) DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12674 '-12684 'MD/8969'-8975 'TVD ( 1 spf) N/A 12700'-12806'MD/8985'-9046'TVD (4 spf) 27. PRODUCTION TEST - Di~te First Production I Method of Operation (Flowing, gas lift, etc.) ctober 1985 F1 owing I Date of Test Hours Tested 'PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 10726/85 6.0 TEST PER lCD I~ 1 759 4029 0 61 2291 Flow Tubing Casing pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-APl (corr) Presls.193 .... 24-HOUR RATE I~ 7035 16115 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None · - "J. C3u C~ · NOTE: Drilled 12/14/84. Perforated well 10/6/85. Workover performed 7/18/88. ~nc~0rag~ Form 10-407 (Dani) WC5/031 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include'interval tested, pressure data, all fluids r~over~ and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadler~h~ - ..120~3~ . _ 8859~ N/A- OWC 12861 ~-1287~ ~ 9078 ~ -9086 31. LIST OF ATTACHMENTS , I Rone _ 32. I hereby certify that the for~oin~ i~trUe and correct to the best Of I Signed ~ , I 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 · ARCO ALASKA, F',O. BOX ANCHORAGE, ALASKA 995i0 DATE' 8-26-88 REF'ERENCE ' ARCO F'RE2$URE DATA BHF'--$'TAT IC GRADiEN'I' BHP---2TATIC GRADIENT BHF ....~I"AT iC GI'RAD IEN'I' BHF ....2TATIC GRADIENT BHP--,%"I'A'T I C GRADIENT BHP---5'TAT IC i~RAD ]:ENI' BHF'--FLOW ING GRADIENT BHF ..... PRE~;'2LJRE BU]:LD-UP RETURN THE ATTACHED COPY CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO A'S RECEiF'¥ OF DATA. RECEIVED BY HAVE A NICE DA?'! SAi_t.Y HOFFECKER ATO-~ 529 Tt:;.' A N ~~ 4'88547 AF'PROYED Alaska 0ii & (?as Cons. Cornmissior~ ~ ........................... Anchorage D 13' TR l BU'I- I ON CENTRAL FI LES' CHEVRON I) & M EXTEN2ION EXPLORATION '"- EXXON HARATHON ~ HOBIL AR'CO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager August 25, 1988 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservati on Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Re' DS 11-12 Permit Number' 84-195 Enclosed is the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/RLP' sd Enclosures cc' Standard Alaska Production Co. JoAnn Gruber, ATO 1478 File P1(11-12)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALAS,..-, OIL AND GAS CONSERVATION COM,,.,$SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ..~ Plugging ~ Perforate ~ Pull tubing Alter Casing ~ Other/~ 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 136' FNL, 107' FEL, Sec.33, T11N, R15E, UM At top of productive interval 1971' FNL, 2226' FEL, Sec.33, TllN, R15E, UM At effective depth 2589' FSL, 2403' FEL, Sec.4, TION, R15E, UM At total depth 2559' FSL, 2410' FEL, 5ec.4, T10N, ELSE, UM WORKOVER 5. Datum elevation (DF or KB) RKB 58' 6. Unit or Property name Prudhoe Bay Unit 7. Well number 11-12 8. Approval number 8-499 9. APl ~number 50--029-21212 10. Pool Prudhoe Bay Oil Pool Feet 11. Present well condition summary Total depth' meaSured true vertical 13032 ' MD 9175 ' TVD feet feet Plugs (measured) None Effective depth: measured 12995 true vertical 9153 ' TVD Casing Length Size Conductor 80' 20" Surface 2529' 13-3/8" P roducti on 9318' 9-5/8" Liner 4003' 7" feet feet Junk (measured) 29' E-line tool & 3800'+ 7/32" cable Cemented Measured depth True Vertical depth 1950 # Poleset 1lO'MD 110'TVD 2520 sx PF E & 2529'MD 2504'TVD 400 sx PFC 500 sx Class G & 9318'MD 6793'TVD 300 sx PFC 600 sx Class G 9029'-13032'MD 6636'-9175'TVD Perforation depth: measured 12674 ' -12684 'HD, 12700 '-12806 true vertical 8867 ' -8880 'TVD, 8901 ' -8908 'TVD, 8940 ' -8958 'TVD Tubing (size, grade and measured 8o~e61~t'l'[)~975'TVD' 8985 '-9046 'TVD 5½"/3½", L-80, tbg w/tail ~ 11963' Packers and SSSV (type and measured depth) Baker FB-1 pkr (~ 11871'_. Camco Bal-O SSSV (~ 2173' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) 12506'-12528'MD, 12562'-12574'MD, 12626'-12656'MD Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel 1 ,H.istory) Daily Report of Well Operations~ Copies of Logs and Surveys Run I~, 15. I hereby certify that the foregoing is true and correct to the best of my knowledge _ ,~_ ,~ Signed ~ ~[~)j¥,.... ~.~ ~ Title Form 10-404 Rev. 12-1-85 Associate Engineer (Dani) SW03/024 Date Submit in Duplicate~ ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARco Alaska, Inc. Field PRUDHOE BAY FIELD Auth. or W.O. no. AS2394 Operator ARCO ICounty, parish or borough NORTH SLOPE-PRUDHOE BAY Lease or Unit ADL: 28328 Title WORKOVER API: 50-029-21212 IState AK i Well no. DS 11-1~ ARCO W.I. 22.0000 Prior status if a W.O. Spudded or W.O. begun ACCEPT Date and depth I Date 07/07/88 IH°ur Complete record for each day reported 1600 HRS as of 8:00 a.m. 07/08/88 ( TD:13032 PB:12995 SUPV:RO 07/09/88 ( TD:13032 PB:12995 SUPV:RO 07/10/88 ( TD:13032 PB:12995 SUPV:RO 07/11/88 ( TD:13032 PB:12995 SUPV:RO 07/12/88 ( TD:13032 PB:12995 07/13/88 ( TD: 13032 suPv: RO WESTWARD RIG 1 CIRC AND KILL WELL MW: 8.3 SEAWATER MOVE RIG F/ DS 7-12 TO DS 11-12. RIG ACCEPTED AT 1600 HRS, 7/7/88. RIG UP AND PULL BPV. BULLHEAD DOWN TBG & ANN W/ 775 BBLS OF 8.3 PPG SEAWATER. BLEEDOFF ANN AND CIRC. SHUT DOWN. OBSERVE WELL. NO FLOW. DAILY:S45,462 CUM:$45,462 ETD:S45,462 EFC:$603,000 TIH WITH SPEAR MW: 8.6 SEAWATER BULLHEAD SEAWATER TO KILL WELL. OBSERVED WELL - NO FLOW. SET BPV. ND TREE. NU BOPE AND TESTED TO 5000 PSI. PULLED TEST PLUG. BACKED OUT L0CKDOWN SCREWS AND PULLED HANGER. HANGER PARTED OFF THE TUBING. NU TRI-STATE 5-1/2" SPEAR & RIH WITH SAME. DAILY:S30,837 CUM:$76,299 ETD:S76,299 EFC:$603,000 OBSERVED WELL MW: 9.0 SEAWATER MU TRI-STATE SPEAR BHA AND TIH. TAGGED FISH @ 385'. POOH W/1 STD - WELL STARTED FLOWING. CIRCULATE OUT THROUGH CHOKE. OBSERVED WELL. BULLHEAD 550 BBLS DOWN THE ANNULUS @ 2 BPM (1200 PSI). OBSERVED WELL. ATTEMPED TO BLEED OFF PRESSURE. CIRCULATE DOWN DP. OBSERVED WELL. WEIGHT UP FROM 8~6 PPG TO 9.0 PPG. BULLHEAD DOWN TUBING WITH 9.0 PPG. BLEED OFF ANNULUS. PUMPED 275 BBLS DOWN TUBING. OBSERVED WELL. BULLHEAD DOWN ANNULUS WITH 9.0 PPG. OBSERVED WELL (DP -200 PSI; ANNULUS - 250 PSI) DAILY:S28,070 CUM:$104,369 ETD:S104,369 EFC:$603,000 LD 5-1/2" TUBING MW: 8.3 SEAWATER OBSERVED WELL (ANNULUS - 200 PSI; TUBING - 200 PSI). BULLHEAD DOWN TUBING & ANNULUS. OBSERVED WELL (ANNULUS AND TUBING - 0 PSI). TOH WITH FISH. LAY DOWN TRI-STATE SPEAR. CIRCULATE BOTTOMS UP @ 11951'. CUT WEIGHT BACK TO 8.3 PPG. POOH WITH 5-1/2" TUBING. DAILY:S61,257 CUM:$165,626 ETD:S165,626 EFC:$603,000 TIH WITH RET TOOL MW: 8.3 SEAWATER POOH LD 5-1/2" TUBING. RU TO RUN 3-1/2" DP. CHANGE RAMS FROM 5-1/2" TO 3-1/2". TEST BOPE TO 5000 PSI. MU BAKER PBR RETRIEVING TOOL BHA AND TIH. DAILY:S39,139 CUM:$204,765 ETD:S204,765 EFC:$603,000 TIH WITH SPEAR MW: 8.3 SEAWATER TIH WITH BAKER RET TOOL. TAG FISH @ 12191'. LATCH ONTO FISH AND PULL UP TO 12151'. CIRC. PULL 2 STANDS. CBU. POOH WITH FISH. LAY DOWN TRI-STATE TOOLS AND FISH. MU WL WITH SPEAR. DAILY:S28,253 CUM:$233,018 ETD:S233,018 EFC:$603,000 The above is correct For form preparation a~¥ distribution, see Procedures Manuak/Section 10, Drilling, Pages 86 and 87. Date I Title AS,,ROOIATE ENGINEER ARCO Oil and Gas Company,~,," Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number aH drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reporled on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out bul not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting ol oil strin§ until completion. District Field Date and deptl~ as of 8:00 a.m. I County or Parish ARCO Alaska, Inc. I NORTH SLOPE-NORTH SLOPE I Lease or Unit PRUDHOE BAY FIELD I DS 11-12 Complete record for each day while drilling or workover in progress WESTWARD RIG 1 07/14/88 ( TD:13032 PB:12995 SUPV:MD/RB 07/15/88 ( TD:13032 PB:12995 SUPV:MD/RB 07/16/88 ( TD:13032 PB:12995 SUPv:MD/RB 07/17/88 ( TD:13032 PB:12995 SUPV:MD/RB 07/18/88 ( TD:13032 PB:12995 SUPV:MD/RB 7) 8) ,0) State AK TIH WITH WL SPEAR MW: 8.3 SEAWATER TIH WITH WL SPEAR. TAGGED LINER WITH STOP RING. COULD NOT GET BELOW 9015'. POOH. RIH WITH POLISH MILL AND REAM LINER TOP. POOH. RIH WITH WL SPEAR. DAILY:S35,324 CUM:$268,342 ETD:S268,342 EFC:$603,000 CBU MW: 8.3 SEAWATER FIN W/ ROPE SPEAR. WORK TO BOTTOM. POOH. RECOVERED E-LINE AND LOGGING TOOL. TIH W/ BIT AND SCRAPER. CBU TO CLEAN HOLE. DAILY:S43,656 CUM:$311,998 ETD:S311,988 EFC:$603,010 ND BOPE MW: 8.3 SEAWATER POOH. RUN GR/JB TO 12000' MU RETRIEVABLE BP. RIH SET SAME AT 11989'. SET STORM PKR. ND BOPE. DAILY:S43,540 CUM:$355,538 ETD:S355,538 EFC:$603,000 DISPL W/ SEAWATER MW: 8.3 SEAWATER CHANGE 9-5/8" PACKOFF. NU BOPE AND TEST SAME. RIH AND RETRIEVE STORM PKR. RIH AND RETRIEVE BRIDGE PLUG. MU BAKER FB-1 PKR AND TAILPIPE~AND RIH TO 11900' MD DROP BALL AND SET PKR AT 11900' MD~TE~T PKR TO 2500 PSI F/30 MIN. DISPLACE HOLE W/SEAWATER TREATED W/C-193. DAILY:S39,173 CUM:$394,711 ETD:S394,711 EFC:$603,000 RIH W/PROD TBG MW: 8.3 SEAWATER DISPLACED HOLE W/ SEAWATER. POOH, LD DP. MU BAKER LOCATOR SEAL ASSEMBLY AND RIH W/SAME ON 3-1/2" AND 5-1/2" PROD TBG. DAILY:S32,213 CUM:$426,924 ETD:S426,924 EFC:$603,000 IWell no. The above is correct Signature /. . 'Date ~'; ~' ~..~- · [=or form preparation ancl//~stribution see Procedures Manual Se~%tion 10, Drilling, Pages 86 and 8~j ITitle ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History-Final Report Inslructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO Alaska, Inc. Field PRUDHOE BAY FIELD Auth. or W.O. no. AS2394 County or Parish NORTH SLOPE-PRUDHOE BAY Lease or Unit ADL: 28328 Title WORKOVER IAccounting cost center code State AK J Well no. DS 11-~2 API: 50-029-21212 Operator Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 07/19/88 ( 1 TD:13032 PB:12995 SUPV:MD/RB A.R.Co. W.I. 22,0000 Date Iotal.number of wells (active or inactive) on this ost center prior lo plugging and I bandonment of this well I our l Prior status if a W.O. 1600 HRS I 07/07/88 Complete record for each day reported WESTWARD RIG 1 RIG RELEASED MW: 8.3 SEAWATER FIN RUNNING 5-1/2" PRODUCTION TBG. DISP TOP OF TBG AND ANNULUS W/DIESEL . LAND HGR AND TEST SAME. ND BOPE. NU TREE. TEST TREE. RD. RIG RELEASED AT 2400 MRS, 7/18/88. (NOTE: CAMCO 'BAL-O' SSSV @ 2173', BAKER 'FB-i' PACKER @ 11871', & TBG TAIL @ 11973') DAILY:S216,970 CUM:$643,894 ETD:S643,894 EFC:$603,000 Old TD New TO Released rig Date P8 Deplh Kind of r g Classifications (oil, gas, etc.) J Type completion (single, dual, etc.) I Producing method J Official reservoir name(s) I Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparationt/aJnd distribution, see Procedures Man~l, Section 10, Drilling, Pages 86 and 87. JTitleASSOCIATE ENGINEER STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ,~ Operation Shutdown .~ Re-enter suspended well ~ Alter casing C Time extension C Change approved program C Plugging ~,' Stimulate ~ Pull tubing ~ Amend order :~ Perforate .~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 136'FNL, 107'FEL, Sec. 33, T11N, R15E, UM At top of productive interval 1971'FNL, 2226'FEL, Sec. 4, TION, R15E, UN At effective depth 2589'FSL, 2403'FEL, Sec. 4, TION, R15E, UM At total depth 2559'FSL, 1420'FEL, Sec. 4, TION~ R15E~ UM 11. Present well condition summary Total depth: measured 13032 feet true vertical 9175 feet Plugs (measured) 5. Datum elevation (DF or KB) 58' RKB feet 6. Unit or Property name Prudhoe Ba,y Unit 7. Well number DS 114~-Iz 7~-- 8. Permit number 84-195 9. APInumber 50-- 029-21212-000 10. Pool Prudhoe Bay 0il Pool Effective depth: measured 12975 feet true vertical 9153 feet Junk (measured) Casing Length Size Cemented Measured depth True Vertical depth Conductor 110' 20" 1950# Poleset 110' 110' Surface 2529' 13-3/8" 2520 sx PF "E" & 2529' 2504' 400 sx PF "C" Production 9318' 9-5/8" 500 sx Class G & 9318' 6794' 300 sx PF "C" Liner 4003' 7" 650 sx Class G 9029-13032' 6636-9176' Perforation depth: measured 12506-12528' 12562 12574' 12626-12656' 12674-12684' 12700-12806' true vertical 8867-8881' 8902-8909' 8941-8959' 8970-8976' 8985-9048' Tubing (size, grade and measured depth) ~" J-55 847' 12004 'MD 5-~'' L-80 0'-8971 'MD; 3~ , , 2 ~ ~ -- Packers and SSSV (type and measured depth) Camco Bal-O SSSV @ 2195'MD; Baker FHL Packer @ 11921'MD 12.Attachments Description summary of proposal ~ Detailed operations program ,~ BOP sketch 13. Estimated date for commencing operation 14. If proposal was verbally approved Su~r_:eq~ze',.:d-'VV(~r:~. 'Ret~o~tcJ ,~!, Name of approver Date approved 15. I hereby/'pertify that,,the..,foregging is true and correct to the best of my knowledge Signed//~(~'///~~//.~//~4.4.~.~- Title Operations Engineering Manager Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. © Plug integrity ~ BOP Test [] Location clearance I Date Approved by ~tI!GINAL SIGNED · qY CONNIE C. SMITH A. pproved Copy Returned Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 11-12/STAT17 R. L. Payne (263-4487) , ~/-/'~ .. Submit in triplicate Summary of Proposal ARCO Alaska, Inc. proposes to perforate DS 11-12 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit. The well is currently flowing with an estimated static bottom hole pressure of 3820 psia. This well will be perforated approximately 500 psi underbalanced and flowed to cleanup. The wellbore fluid at the time of perforating will be the produced fluids; oil, water and gas (currently 3950 scf/stb GOR and 14% watercut). All wireline work will be done through a 5000 psi WP BOP/Lubrication (see attached schematic) tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operati on. Proposed Perforation Intervals: 12440'-12475'MD 1/6 spf Ref: BHCS 12/?/84 4 ! 1 I 1. '5000 PS1 ?" WELLH~ CONNECTOR FLANGE 2. 5000 PSI WIRELIN£ RAMS (VARIABLE .SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PS1 4 1/6" FLOW TUBE PACK-OFF Id I REL I NE BOP EOU I PHENT _ ~I:,U.) ~,LA~,KA, INC. - F' O, BO;( i00366, ANCHORAGE, Ai._ASKA 9951O DATE' 8-i 6-88 REFERENCE' ARCO CASED HOLF F'INAL 3--2t 7-28-88 LEAK DETECTION l--II::'F'i'-t -f'EMF' RUN 3-24 7-28-88 LEAK DETECTION I'ENP F;.'.tJN ;5-24 7--Se-88 LEAK DtFTI::jC]'I ON RUN 7-t9 7-29-88 PRODUCTION F'ROFILE .... RUN ') =:' 9 c? .. 8 7'-.-._,' 7-,.., 8 PRODUCTION PROFILE RUN 9-~ 2 -,._~'? -":,o_c ;- . , ,-., ,,,..,.-, 8U TN,JECTION PROF'[LE F;'tJN t i-6 6-27-88 COLL. AR/PERF RUN ~ ~ - ~ 2 '7-30'-88 COLLAR I:~tJN i .4-o~'':' '"' '"A '-';'" ,_._, ~-.z,~:-'oo DATA FRAE: ]'kEMP RUN i 5-~ '2 6-24-88 COLEAi~.'/I::'E-R!z RUN i6-'i j 8-i-88 IN,JECTIrjN PROFILE I:k'.UN F'~EASE Sit]hl AND F,.:ETURN 'f'HFA1-]"A[Z:iED CUF'Y AS RfZCE'[I::"i" 01':' i)A'f' '"'~" Nas~ I)11 & Gas Cor~ Come. Ion ~'~~ CK FF;.: - RECE]:VED BY HAVE 'A NICE SALLY HOF'F'E A'l-O--t ~29 .. TRAN. S ~:885.3 i APPROVED ......... D :[ $-f'R I BUT .[ ON A · 2' 5" 5' 5" i'"' I~ .J '.5 ' b" CAHCO CAHCO CAMCO CAMCO CAMCO CAMCO GEAR CAhCO C A i'-i C 0 hEAl:;: C A r,i C 0 '* CE:NTRAL.. F ILE:'S ¢: F:'HII_LIPS ~ CHEVF;:.ON 'F'B WI"-I_L. I':' .[ L F" 3' D & H R & I) :~ EX'FEN:~CION IEXPt_OI';:.A'f'ION ~ :~: SAI"C ~I: EXXON ~: S:'f'A'rF OF' AL.A~'KA HARA'¥H'ON ~ ]'EXACO :."': i"1 (] El I L . X-i o ~'._--.,,~_oo ~ FF.~( i'J!::'T~-f-.'TTJlN I-~'! !N i ~- .:' .- .t. ~ ! ~ .~ , . i... . · --~' -- .t' .- -*' i i i-I ..... i . i . _ . · ~_. '-~ o ~'. _ '-, ,'~ _ :2, ,c), F' T T :~ Fi' !.1N t ; .'i .:.. ~ . .. ~: .~.. i. .i. i ,.-, . · .1: .,- : / , I~ ~ . · - .... 4-" t ~ ~' - 'j t -- ,m .o 'F N. I F' F: T '[ F1N I::' F: i-,' F' T 1 r.. F~' I ! N I ..:, ..-. , I~ ! ...... ~ -- · - '-, 4-:'P----RR C. Ftt I F:;R' ;;.~Ne, I:'F~;FF,,F,:;h-f"FNL.-, I F If.] I;:I. IN t -~~. .. . . ~ ..... · ~-~ ,--: ~-- -'~ ,:, ,.~,.~ t::, q, '-I i'" ~ i i": T T ;'~ i9 I::' ,q; f'l I-- I' i iN- I;: I I N %.- ~. ... ..-.~ .- I.-;~¢ .,~-~~ ~ . , :, _ i.~ . ~ ~ - · t i-i'') 4 '-' '-":' F.,~:',MM;~; F:Ay/:~PI'NNF!;:/NYT)F~:F] !F1C RIlNI i . ,% '~ '1..' ~ i"'l;, . .- ; i '') -- o 'I':; ,~' ' 'z ._ o o . . .. : ..... - 1 ...... i').;:'.',T;h F:'F:.:P,I"'.'/","'!':'MF-.'F,r-;:~-T! !Ii'!:' I I"lf., 17115t 'i., i ,'.'~',-- '~' ~'. '"r'-- "~:' '"~"--OClt~.I ".' 'Tc';''4c',. , ,, .... /r-:'l I']L,Ji',iFTFt-';.'/I F;.~ k' T:,FT -r:f]T'r !-Ii9, F~'I II',l t : i ICl - :'~ ~- _. ,-., -,-r ._ o c, r.:, T -r- ;:..- Fi' I I N i .. z ..-.. i i~ls ! ! . · i l"'),--i 'i ~'._']-i _.r:..,,.-:, m'r4'F'li-;! ~F':'T"I",'-',N F'F,:F',FTI r. RI IN . . .. .~. , ~ ~I ~ i ,. ~ ~:. I . ~ N ff.,. 'F -- 5 '~._,-.~/~_o~ TN.IF:"T'I'FiN F'I.~'FiFTI I::' RllN . .: ._-.~ ~..* ... ~. ~ . * .. F't. I.--.,'~RF :?-.:T!-.;NI ,,:~k.ti~ RFT!!F,'N Ti-~"- ~'~"FT,';:i""tJL-,'['I F]F',PY A~ ~'Fr'[-[TF'T F1F DA'T~ I-]. A H Fi fi 12AMF:Fi P. AMf':f! C ~ M P. fi F,F AFl' fi A M F: F1 f'; F ,'~ F;.' C A M f": F1 P. A H f": F't f':. A H, f-: fi F~. :.~:, i¥-i f": F'i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ?i Suspend ~ Operation Shutdown [] Re-enter suspended well ~ Alter casing ,~. Time extension [] Change approved program © Plugging ~ Stimulate ~ Pull tubing '~,' Amend order ~_ Perforate ,~, Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 58' feet 3. Address 6. Unit or Property name P, O. Box 100360, Anchorage, AK 99510-0360 Prudhoe Bay Unit 4. Location of well at surface 136' FNL, 107' FEL, Sec. 33, T11N, R15E, UM At top of productive interval 1971' FNL, 2226' FEL, Sec. 33, TllN, R15E, UM At effective depth 2589' FSL, 2403' FEL, Sec. 4, TION, R15E, UM At total depth 2559' FSL, 2410' FEL, Sec. 4, TION, R15E~. UM 11. Present well condition summary Total depth: measured true vertical I 3032 'MD feet 91 75 ' TVD feet Effective depth: measured I 2995 ' MD true vertical 91 53 ' TVD Casing Length Size Conductor 80 ' 20" Surface 2529 ' 1 3-3/8" feet feet 7. Well number 11-12 Production 9318' 9-5/8" Liner 4003' Perforation depth: measured 8. Permit number 84-1 95 9. APl number 50-- 029-21 21 2 10. Pool ; Prudhoe Bay 0il Pool Plugs (measured) None Junk (measured) Cemented 1950 # Pol 2520 sx Pe & 400 sx Pe 500 sx C1 & 300 sx Pe 29' E-line tool & 3800'~ 7/32" cable Measured depth ~ue Verticaldepth eset 1lO'MD 110'TVD rmafrost E 2529'MD 2504'TVD rmafrost C ass G 9318'MD 679~'TVD rmafrost C 7" 600 sx Class G See Attached Sheet 9029'-13032'MD/6636'-9175'TVD true vertical TU_bling (size, grade and measured depth) /2", 17#, L-80 tubing f/surface - 8971' & 3-1/2", 9.2#, J-55, Packers and SSSV (type and measured depth) Baker FHL packer @ 11,921', Camco Bal-O SSSV L~ 2195' tubing f/8971 '-12,004' 12.Attachments Description summary of prop°sal~,. 13. Estimated date for commencing operation Detailed operations program BOP sketch September 20_.1988 _ _ 14. If proposal was verbally apRrqved ~. ~ _~, ~.,~, JUN Name of approver ~o~ ~o.~~ea~/~~k~ 0it & Gas 15. I hereby certify that the foregoing is true and correct to the best of my ~nowle~ge Signed Conditions of approval Title Associate Engineer Commission Use Only (SA3/0004) Approved by Notify commission so representative may witness I Approval No. tD Plug integrity [] BOP Test [] Location clearanceI Approved Copy Date ~- ~,.,&.~ ORIGINAL SIGNED BY LONNIE C. SMITH Returned Commissioner by order of the commission Date Form 10-403 Rev 124-85 Submit in triplicate DS 11-12 Application for Sundry Approvals B1 ock 11 Perforation Depths MD 12,506'-12,528' 12,562'-12,574' 12,626' -12,656' 12,674'-12,684' 12,700' -12,806' TVD 8867'-8880' 8901'-8908' 8940'-8958' 8969'-8975' 8985'-9046' RECEIVED JUN ~- 7 19BB Ata. sY,~. 0i~ & Gas Cons. Commission Anchorage APPLICATION FOR SUNDRY APPROVAL DS 11-12 PRODUCER WORKOVER PROCEDURE SUMMARY OBJECTIVE: Retrieve existing 5-1/2" x 3-1/2" completion assembly and replace with new plastic coated 5-1/2" x 3-1/2" tubing and 7" permanent packer. Recover 29' E-line tool and +3800' 7/32" cable. The 9-5/8" emergency pack-off will be replaced and the 7" liner cleaned out to PBTD. A 7" isolation packer will be installed above Romeo perfs. 1) MIRU WW1. ND tree. NU BOPE and test. 2) Pull BPV. Check well for flow. 3) POOH w/5-1/2" tubing (tubing parted at 370'). 4) RIH w/3-1/2" DP and overshot. Engage 5-1/2" tubing and PU to shear PBR seals at _+40,000 lbs over string weight. POOH, LD 5-1/2" tubing and seal assembly. 5) RIH w/3-1/2" DP and PBR retrieving tool. 6) Engage PBR and release Baker FHL packer. POOH w/packer and PBR. 7) Fish for 7/32" cable and E-line tool string if fish is not recovered wi th tubing and packer. 8) MU 6" bit and 7" 29# casing scraper on 3-1/2" DP and RIH. Clean out 7" liner to PBTD or minimum depth of 12,900' MD. POOH. 9) RIH w/7" test packer and test 9-5/8" x 7" casing to 2500 psi. POOH with DP and 7" test packer. 10) Change 9-5/8" emergency pack-off and test same to 3500 psi. 11) MU new 7" permanent isolation packer on DP and RIH and set same at +12685' MD. POOH. 12) MU new 7" permanent packer on DP and RIH and set same at -+12,200' MD. POOH, LDDP. 13) RIH w/new 5-1/2" x 3-1/2" completion assembly. 14) Lane tubing. Set BPV. ND BOPE. NU 5-1/2" 5M tree and test. Test tubing and annulus to 3000 psi and 2500 psi, respectively. 15) Release rig. Turn well over to Production. BHP: 3730 psi @ 8858' TVD (8.1 ppg) Workover Fluid: Seawater (8.5 ppg) DSC/O03.3 ~ REEEIVED JUN 2 7 1988 A~ask~ Oil A Gas Cons. Commission Anchorage ANNULAR PREVENTER § TUBIN6 HEAD ;5 1. 1~5-:5/8" CASING HEAD 2. 9-5/8" CASING HEAD :5. 5000 PSI TUBING HEAD 4, 1:5-5/8" - 5000 PSI BLIND RAHS 5. 1:5-5/8" - 5000 PSI PiPE RAMS 6. 1:5-5/8" - 5000 PSi ANNULAR ACCUHULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS $000 PSI WITH 1500 PSI DOWNSTREAM OF THE RE6ULATOR. :5. OBSERVE TIME, THEN CLOSE ALL UNITS SIHULTANEOUSLY AND RECORD THE TIHE AND PRESSURE REHAININ6 AFTER ALL UNITS ARE CLOSED WITH CHAR61N6 PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSIN6 TIME AND 1200 PSI REMAININ6 PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED, PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. ;5. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE HANIFOLD, 4, TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES, 5, INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. §. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAHS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES, 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES, BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED i'IANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAI"I OF VALVE AND WITH ZERO PSI DOWNSTREAM, BLEED SYSTEI"I TO ZERO PSI, g. OPEN PIPE RAHS. BACKOFF RUNNING JT AND PULL OUT OF HOLE, CLOSE BLIND RAHS AND TEST TO 5000 PSI FOR 10 MINUTES, BLEED TO ZERO PSI, 10. OPEN BLIND RAHS AND RECOVER TEST PLUG, HAKE SURE I"IANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVE5 ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI. 12, TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP, 1:5, RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM, SIGN AND SEND TO DRILLING SUPERVISOR, 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY iV £ D JLIN 2 7 1988 ' Alaska Oil & Gas Cons. Commission Anchoraoe dG NOVEMBER 21,1986 ARCO ALASKA, INC. F'.O. BOX t883&0 ANCHORAGE, ALASKA 995~t 0 DATE: t-t~-88 REFERENCE ARCO CASED HOLE FINAL -t5 tt-28-87 CN/GR/MUL. TI-$PACE/SNDETNE MATRIX RUN ~, ! !i ~ ~-3(~-87 CNP/GR MULTISPACE RUN,, tt-t4-87 F'DK - tG~ RUN ~, t2-t~-87 DIFFERENTIAL/TEMPERATURE RUN t , t~-~5-87 PDK - ~88 RUN t, 6-~6 tt-27-87 CN/GR/MULTI-~PACE/SND2TNE MATRIX RUN t ~ ~-2 t ~-22-87 PFC RUN ~ , ~-3 t 2-4-87 PFC RLIN t, ~~~ t~-~8 ii-5~-87 CN/GR HULTIEPACE RUN i, 5-t7 tt-2~-87 CN/GR HUI_TIEPACE RUN i~ 5-22 t t-25-87 PFC R[IN t , 6-2e ii-t4-87 PDK - t~ RUN t, RECEIVED B Y~~_u~O l~i~___~_ _ H A v E A ~.~ D n~ ,_~,.~ oil & Gas. Cons. commis~t~ ~.E~~ ...... ~~ - PEGGY ATO- 1 TRANE ¢8882? APPROVED ..... DISTRIBUTION WAI WAI WAI WAI WAI WAI WAI WAI WAI WAT WAI WA7. WAI CENTRAL FILES CHEVRON D&M EXTENSION EXPLORATION EXXON MARATHON MOBIL ~. PHI'LL_IF'$ PB WELL FIL.E2 R & D ~ SAPC -~ STATE OF ALASKA ' TEXACO -, D ]: 2 'r K" ]' B I. I 'lr' ]' ¢l N ., 'l ARC[. Ala.ska, Inc I::' ~ O ~ Box Anchorage, A Las-ka 9951 0 DATE' February t 9, I°8"?, REFERENCE' ARCO Cased Hote F ina~ ~ :3-.S2 .."_z,-..t t -.86 C;C'l" D i rec t: iona L ~;urvey -'--~-~4--2.!7 4-t .:~....1:.6 CBI... Var' i ab I.e? Den~' i ty ."'--"-' ':~""5 4-t S'"'86 CH CNI... t t-2& 2-2""87 ACBL/VDL./5'ICN/i;;R % t .4-32. t .."~"-"~'~'"' 86,,... ,.. F'DK"" 1 00 F:'l. ea~e .~ign an(:l return Received By HAVE A NICE R o.,..." a n'n e Peel{ DAY! the attached copy as' receipt of data, 1987 ~ka Oil & Gas Cons. Commission ~ Anchorage :".: Phi L L i p~ PB WeLL Fi Le~ R & I) · "' .,":;oh io '~ ~'ta~e of"~Le~k~ · .-'"' T (-'.~ X i..! (;: 0 ARCO AI.a~ka, Inc. P.O. Box ~00360 Ariel')or age, Alaska DATE' OcS. obey 9, i986 REFERFNCE' ARCO M~_~gnetic Tapes w/lis'ting 4-..t3-86 Tape $7i736 FDIT L. IS',~"HCNL Run 9 6-.86 Tape ,~:7t7S7 EI>I'[ LIS~WCNL Run ~ I::'lease ~ign and <;~ Rece ired By_ ~-~i;~ HAVE A NICE Rosa nile F-'ee k ATO- i 529F 0ii & G-u~J'C~s:'~°mmlssi°n Anchorage TRANS ~86630 S c h I) I $'¥R I BUI'I ON ..-'"' F'hi llips PB We l l F'i Les R & D '"'-.- $ohio · " State of Alaska Texaco ARCO Alaska, Inc. P.O. Box t0{)380 Anchorage, Alaska 995t ~) DATE: REFERENCE: DS 9-27 DS 9-28 DS i t-8 ~DS tt-tt ~DS tt-t2 ~DS ii-t3 DS i5-t3 ~S t7-t4 March ti, i986 ARCO Pressure Data t-6-86 F'BU Ot i $ i-3-86 F'BU Ot i s 2-5-86 Static F'ressure Otis 2-i0-B6 BHP Static Otis 2-t0-86 Initial BHP Static Otis -9-86 F'BU Go t-9-86 PBU Go 2-5-86 Static Pressure Otis t-i-86 Stat i c Ot i s i-t2-86 Gas Lift Mandrel Otis 1-5-86 F'BU Otis Please sign and return the attached copy az receipt of data. HAVE A NICE DAY Irma Cmr [ in '~j~Y-- C:, & ,k:.-: ~_ ~ ............... ATO-i 429F TRANS ~86t99 DISTRIBUTION Central Fi [es Chevron Exter~sion Exploration Ex xon Marathon Hob i t Phi llips F'B Well Fi les R & D Soh i o ?~"~'-Sta te-of Alaska ...... Texaco ARCO Alaska, Inc. F'.O. Box t~)8360 Anchorage, Alaska DATE' March tt, ~986 REFERENCE' ARCO Cmsed Hole Final 9-20 t-~-86:~ Spi nner ~"~ 9-22 t -23-86 Spi nner/Inj. 5" 9-24 tt-t-85 ACBL/VDL/~ i g/GR Run t 5" 9-27 ~t-~-8D Prod. Logging Svc. Run t 5" 9-27 t -5-86 GR/~p inner 5 ' 9-28 t -3-86 GR/~p inner 5' 9'29 t~- ~ t3-85 PDK tOG Run t 5' 9-36 t ~-2-85 ACBL/VDL/~i g/GR Run t 5" tt-t2 t-9-86 CF~ Run t 5' t2-29 t t-3G-84 CCL/Perf Record Run t 5" Otis Otis DA DA Otis Otis DA DA Go $ch PLease sign and return the attached copy as receipt of data. TRAN$ ~86t97 DISTRIBUTION Central Fi [e~ Ch err or, D&M Extension ExpLoration Ex xon Marathon Mob i [ Phi [lips F'B Well Fi le~ R&D Sohio St te'°f Ataska Texaco ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 4, 1985 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 2-4 DS 11-12 DS 11-15 Permit 70-17 Permit 84-195 Permit 84-205 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/dp Enclosures cc: SOHIO Alaska Petroleum Co. File PI(DS 2-4)W1-3 File P1 (DS 11-12)Wl-3 File Pi(DS 11-15)Wl-3 ARCO Alaska. Inc. is a Subsidiary o! AtlanticRichfieldCompany ' i' STATE OF ALASKA ALASKA (. .AND GAS CONSERVATION CC. ]ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well OIL]~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] -- 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-195 3. Address 8. APl Number Post Office B~x 100360, Anchorage, AK 99510 50-029-21112 ..... 4. Location of well at surface 9. Unit or Lease Name 136' FNL, 107' FEL, Sec. 33, TllN, R15E, UM ~ Bay Unit At Top Producing Interval 10. Well Number 1971'FNL, 2226' FEL, Sec.4, T10N, R15E, L~4 DS 11-12 At Total Depth 11. Field and Pool 2559' FSL, 2410' FEL, Sec.4, TlC~]; R15E, UM. Prcz:lb~ Bay Field 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. Prl3dhoe Bay Oil Pool 58' RKBI ADL 28328 12. Date Spudded 13. Date T.D. Reached 14. Date Comp.. Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 11/16/84 /2/06/84 11/28/84 N/A feet MSLI 17. Total Depth (MD+TVD) 13,032'MD 9175'TVD 18. Plug Back Depth (MD+TVS) 12995'1VD, 1953'TVD YES19' Directional.Survey[~ NO [] I 20. Depth where SSSV set2195 feet MD I21' Thickness Of PermafrOst1900, __ 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-40 ,qzrf~-~ 11Q' 30" 1 qr~r~, po!~_et / 13-3/8" 72~ L-80 ~zrfac~ 2529' 17~" 2q2g .~w 1~ "~.' + ~ ~ r__~ "¢"' 9-5/8" 47# L-RO .q~rF~r~. q~IR' 12%" ~ ~ Pl~,, G + 300 ~ ]~ "C" 7" 29~ L-80 9029' 33032' 8~" RR(3 .~z C'I~ 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) 12506.12528'tVD lSPF 3%" & ~,nr~, 11,907' 12562-12574'bD 1SPF 5-z~,, - 12626-12656'MD 1SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. /2674-12684'1VD 1SPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12700-12806'MD 4SPF · Perf'd on 10-6-85 ~ c~: Per'F~: RR~7-~' 27. PRODUCTION TEST Date First Production / Method of Operation (Flowing, gas lift, etc.) ! ~ 1985 t~1~ Date of Test Hours Tested PRODUCTION FOR OIL~BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO I 10-26-85 6.0 TEST PER IOD I~ 1759 4n2q 0 61° ~ 2291 Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press.il93 __ 24-HOUR RATE "F 7035 1611 q O 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIV[D Alaska 0il & Gas Cons. Commission Ant:horaoe Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . NAME Include interval tested, pressure data, all fluids recover~ and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and-time of each phase. .. " ~ ~]~t ~3, :' 8559' ~ ~~t ~32' ~8 ~ . : . 31. UST OF ATTACHM[~TS . -- . : , .. 32. I herebg certif~ that the f~re~oin~ is true ah~~ c~r;~dt to the ~.e,t of mg knowledge . . Signed -. Title Opers. Engr. Mgr. 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 1 O-4¢17 ARCO Alaska, Inc. Post Office B~.. 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 30, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 2-4 Permit No. 70-17 6-1 75-49 6-15 80-32 9-27 85-28 11-12 84-195 11-15 84-205 Enclosed are the "Subsequent" Sundry Notices detailing work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/dp Attachments CC: SOHIO Alaska Petroleum Co. File PI(DS 2-4)W1-3 Pi(DS 6-1)Wl-3 P1 (DS 6-15)W1-3 Pi(DS 9-27)Wl-3 Pi(DS 11-12)Wl-3 P1 (DS 11-15)Wl-3 Alaska Oil & Gas Cor~s, Cor¢lrnissior~ ~,nchoraoe ARCO Alaska. Inc. is ~, Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Surface: 136' FNL, 107' FE~, Sec. 33, TllN, R15E, UM 5. Elevationinfeet(indicateKB, DF, etc.) 58' RKB 12. I 6. Lease Designation and Serial No. ADL 28328 7. Permit No. 84-195 8. APl Number 50-- 029-21212 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 11-12 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). fired. fired. fired. fired. fired. fired. fired. fired. Began perforating operation on 10-6-85. RU perforating unit and pressure tested equipment. RIH w/gun #1 to shoot 12786-12806' MD (4SPF). SI well, POOH, all shots RIH w/gun #2 to shoot 12756-12786' MD (4SPF). SI well, POOH, all shots RIH w/gun #3 to shoot 12730-12756' MD (4SPF). SI well, POOH, all shots RIH w/gun #4 to shoot 12700-12730' MD (4SPF). SI well, POOH, all shots RIH w/gun #5 to shoot 12674-12684' MD (lSPF). SI well, POOH, all shots RIH w/gun #6 to shoot 12626-12656' MD (1SPF). SI well, POOH, all shots RIH w/gun #7 to shoot 12562-12574' MD (lSPF). SI well, POOH, all shots RIH w/gun #8 to shoot 12506-12528' MD (lSPF). SI well, POOH, all shots Secured well, RD. Ref: BHCS 12-7-84 14. I hereby(,q)ertify th~/~,r,~e f~re,,g°~g is t~ue a: correct to the best °f mY kn°wledge' Signed ~t~ ~~~[ ~ Title Operations l~.ngirloering Mgr o The space below for Commission use Conditions of Approval, if any: Approved by Form 10-403 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, inc. Post Office Box 100360 Anchorage. Alaska 99510 Teiephone 907 276 1215 Date: October 30, 1985 Reference: ARCO Pressure Report 4-5 Static Gradient 10-5-85 Otis 11-12 Initial Static BHP 10-8-85 Otis 11-15 Static Gradient 10-7-85 Otis 14-10 Flowing Pressure Gradient Survey #1 10-19-85 Camco #2 10-19-85 Camco #3 10-19-85 Camco Please sign as receipt of data. Received by' - Pam Lambert ATO 1429C Trans 390 Atas~,a Oil & 6as Cons. Commission A,'~c~horage Chevron Expl. Services' Ext. Exploration ~xo~.-. Hara=hon PB We22 Fi2es ARCO Alaska, inc. Post Office £ 100360 Anchorage. A,,,.oKa 99510 Telephone 907 276 1215 Date: October 21, 1985 Reference: 'ARCO CE Finals 2-10~' CET Log 3-2~- CET '~6-10 ~CET 7-2--' CET 9-16 ~ Gamma Ray 11-12*'CBL 13-4 ~CCL/Perf 13_25~EPL 13_98~CNL 14-2~ CET 14-4j CET ~/14-7J CCL 14-34 ~CET 15_12~1~ET ~'~! 7' 1 i~CET ~ ~-17-13~CET 17-14~CET 6-30-85 3-11-85 3-6-85 3-8-85 4-27-85 12-13-~4 5-8-85 4-13-85 8-14-85 8-14-85 6-29-85 6-29-85 4-5-85 3-10-85 3-9-85 3-23-85 3-4-85 3-3-85 Run 5" Sch . 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1 5" $ch 1~ 5" Sch 15 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1: 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch (Recomputed) (Epithermal-Recomputed) (Thermal-Recomputed?. Please sign as receipt of da~ f-c para Lambert ~nchorage ' °°mrnissiort ' · ATO 1429C Trans 365 -. Chevron ExB1. S~rvices" Ex=. Explora=ion ~ Exxon Mara=hom Mobil Phillips PB Well Files R&D Sohio Texaco - ARCO Alllkl. Inc. ,I t S,.,ua, s,Ollry ot Atl,,nl~cRi~:hlielCIComl)ln¥ ARCO A!aska, Inc. Post Office B_.. 100360 Anchorage, Alaska 99510 Telephone 907 '276 1215 September 19, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 11-15 DS 11-12 Permit No. 84-205 Permit No. 84-195 Enclosed are the "Intention" Sundry Notices detailing work proposed on the above-mentioned well(s). Very truly yours, D. F. Scheve DFS/JEB/cb Attachments CC: SOHIO Alaska Petroleum Co. File PI(DS 11-15)W1-3 P1 (DS 11-12) Wl-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well At Surface 136' FNL, 107' FEL, Sec. 33, TllN, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 58' RKB 6. Lease Designation and Serial No. ADL 28328 7. Permit No. 84-195 8. APl Number 50-- 029-21212 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 11-12 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate Well 11-12 at selected intervals within the Sadlerochit Sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator tested to 1.5 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 12506-12528'MD 12562-12574'MD 12626-12656'MD 12674-12684'MD 12700-12806'MD Ref: BHCS 12-7-84 Work Reported <ECEIVEE) Alaska 0il & Gas Cons. C0r:~missi0r~ 14. i hereby~tify that the,~ego~g is t~L~e and correct to the best of my knowledge. I/ //// // ? .... Regional Operations EngineerDate The space below for Commission use ! Conditions of Approval, if any: Approved by ~J=prOved Copy ~~.~turned By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate Form 10-403 and "Subsequent Reports" in Duplicate Rc.v 7-1 -~0 ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephon.e 907 276 1215 Date: July 16, 1985 Reference: ARCO TVD Logs .__~11-12 DIL 12-7-84 Run 1- 2"&5" Sch 11-1~- - BHCS_ 12-7284 1 2"&5" Sch 11-12 Ggmma--Ray in Casing 12-7-85 1 2"&5" Sch 12-21 BHCS 12'-21 FDC/CNL 12-21 FDL 12-21 DIL 4-29-85 Run 1 2"&5" Sch 4-29-85 1 2"&5" Sch 4-29-85 1 2 "&5" Sch 4-29-85 1 2"&5" Sch 12-21 Gamma Ray in Casing 4-29-85 1 2"&5" Sch ~l~~~e sign as receipt of data. REceived by Pam Lambert ATO 1429C ~iasXa Oil & Gas Oons. Oomm~ss~on Trans 210 Chevron D&M Expl. Services Ext. Exploration Exxon Marathon Mobil Phillips PB Well Files R&D Sohio State of Alaska Texaco ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: Apr il 23, 1985 Reference: ARCO CH Finals 3-8 w/ Perf Log 1-9 6-5 ~,~ Collar Log 1- 6-11~/ Collar/Perf 1 DT 3 l~-~'~/S p i n ne r/Temp 12-25 "Collar/Per f 12-26/Collar/Per f 12-29'~' Collar/Per f 14-35G/ Collar/Per f 17 - 10 '/ S ginn nae sr Received by Pam Lambert -85 Run 1 5" Sch 12-85 1 5" Sch 2-25-84 1 5" Sch -20-85 1 5" Sch 4-8 85 1 5" Camco 12-7-84 1 5" Sch 12-2-84 1 5" Sch 12-10-84 1 5" Sch 3-33-85 1 5" 'GO 4-4-85 1 5" GO · ,. receipt of data. ATO 1429C Trans 081 Chevron Mobil E & P D & M Phillips Expl. Services PB Well Files Ext. Exploration R & D Exxon Sohio Marathon ~a~e~'~f.'Alaska Mobil Texaco ARCO Alaska, Inc. Post Office Bo.. ,00360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 20, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 11-12 Dear Mr. Chatterton- Enclosed are the Well Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, ~]. Gruber Associate Engineer JG/tw GRU4/L161 Enclosures RECEIVED FEB 2 ! 198.5 Alasl~ 0il & G~s Cons. Commisstm~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany '-i'-- STATE OF ALASKA ALASKA:~ ...AND GAS CONSERVATION CC ~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-195 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21212 4. Location of well at surface 9. Unit or Lease Name 136' FNL, 107' FEL, Sec.33, TllN, R15E, UN ~~-T,~,~,T,.~_ Prudhoe Bay Unit . _ At Top Producing Interval I%,~[~., i~J,',~o i 10, Well Number FNL, 2226' FEL, Se¢.4, T10N, R15E, UM t¥'F~,Fi~D i 11-12 1971' Surf At Total Depthz ~- .I Surf. \~ ~ 1 1. Field and Pool 2559' FSL, 2410' FEL, Sec.4, T10N, R15E, UM IB'H'-~-~-~ Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oi 1 Pool 58' RKB ADL 28328 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 11/16/84 12/06/84 12/28/84 N/A feet MSL 1 17. TotalDepth(MD+TVD) 18.PlugBackDepth(MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 13,032'MD,9175'TVD 12995'MD, 9153'TVD YES [] NO [] 2195 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run D IL/BHCS/GR/SP, GR/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT, PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 110' 30" 1950# Pol eset 13-3/8" 72.0# L-80 Surf 2529' 17-1/2" 2520 sx PF "E" + 400 sx PF "C" 9-5/8" 47.0# L-80 Surf 9318' 12-1/4" 500 sx Class "G" + 300 x PF "C" 7" 29.0# L-80 9029' 13032' 8-1/2" 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) None 3-1/2" & 12,004' 11,907' 5-1/2" 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. ~' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27.N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~! 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED Alask~ 0il & Gas Cons. commission Aritho[age Form 10-407 JMM/WC35 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Top Sadl erochit OWC Base Sadl erochit MEAS. DEPTH . 12,043' 12,861'-12,87 12,932' : TRUE VERT: DEPTH 8559' 9078' - 9086' 9118' .. Include interval tested, pressure data, all fluids recovered and gravity, GOR, and-timeofeach phase. NONE I32' I:erebycertify~halthef°reg°in/~istrleandc°rrectt°thebest°fmykn°wledge ' I Signed Title 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 (G L) 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". ::-:: ::. :t: :: : '~' PrudhOe Bay . Auth'~ o~ W.O. no. ~' · A~E 703443 Parker #176 Operator Wall History- Initial Report- Dally flint Wednesday aftra a well i8 spudded or workov~r operation8 are ~tartad. ~summlri~ed on the form giving Inclusive dates only. ICount~, ~ or bOrough North Slope Borough Lea~e or Unit ~t,. ADL #28328 Drill, Complete & Perforate State Alaska Well no. 11-12 AP1 50-029-21212 IDate I Hour 0800 Hrs. 11/16/84 ARCO W.,. 21.66% · IPrlor status If a W,O. ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth aa of 8:00 a.m. 11/15/84 11/16/84 11/17/84 thru 11/19/84 11/20/84 11/21/84 Complete record for each day reported The above is correct General RU. Accept rig @ 1800 hrs, 11/15/84. 20" @ 110' NU diverter system & function test. Spud well @ 0800 hrs, 11/16/84. 13-3/8" @ 2529' 2445' PBTD, (2440'). Drlg on 13-3/8" cmt plugs Wt. 8.5 (Fresh Wtr) Drl, jet & surv 17½" hole to 2550', cond hole f/csg, POH. RU & rn 63 jts, 13-3/8", 72#, L-80 csg w/FS @ 2529', FC @ 2449'. M&P 2520 Perm "E" cmt @ 12.3 ppg @ ±10 BPM, followed by 400 sx PF "C" cmt @ 15.6 ppg/5-6 BPM. Drl & surv to 2445'. 1671' 4.3° S19W 1671 10 9.97S 3.06W 1885' 6.1° S10W 1884 29 27.10S 9.25W 2100' 11.8° S 2096 61 59.76S 12.08W 2285' 16.4° S 4W 2276 104 104.94S 13.32W 2468' 23.3° S 2448 165 167.11S 16.47W 13-3/8" @ 2529' 4060' PBTD, (1615'), Chg BHA Wt. 8.7, PV 3, YP 2, PH 8, WL NC, Sol 2 DO cmt to 2560', FC, FS + 10' new formation. Conduct formation tst to 11.0 ppg EMW. Drl & surv 12¼" hole to 4060'. POH & change BHA. 2726' 25.8° S12W 2682 270 273S 29W 2974' 30.7° S13W 2901 387 388S 54W 3411' 42.1/4° S16W 3246 654 646S 125W 3654' 42.1/2° SI4W 3424 819 805S 169W 13-3/8" @ 2529' 6489' PBTD, (2429'), Drlg Wt 9.4, Vis 33, PV 5, YP 7, PH 8, WL NC, Sol 7 RIH, drl & surv 4060' to 6489'. 4676' 52.2° S14W 4084 1597 5169' 52.2° S14W 4386 1986 5657' 53° S14W 4683 2373 1561S 355W 1939S 450W 2315S 543W RECEIVED F 2 1 19B5 Al~.~ka Oil & 6as Cons. Commission' Anchora. ga Signature D [=or Fo p -p ' -'~'-~ ~"'d~a~'~but~on, Drilling, Pages 86 and 87. Date I Title 12/21/84 Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheels until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin~ until completion. District Field Alaska County or Parish Lease or Unit North Slope Borough Prudhoe Bay ADL #28328 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. IStale Alaska IWe~ no. 1-12 11/22/84 thru 11/26/84 11/27/84 11/28/84 11/29/84 11/30/84 12/01/84 thru 12/03/84 13-3/8" @ 2529' 11,097' PBTD, (4608'), TOH f/BHA Wt 9.8, Vis 47, PV 25, YP 21, PH 8.5, WL 10, Sol 13 Drl & surv 6237'-11,097', TOH f/BHA. 6123', 52°, Sl6W, 4966.23, 2742.34 VS, 2672.28S, 638.98W 7457', 55.9°, S17W, 5743.35, 3825.53 VS, 3716.68S, 928.93W 8511', 55°, S20W, 6342.13, 4692.82 VS, 4537.28S, 1209.75W 9228', 56°, S20W, 6748.24, 5282.81VS, 5092.84S, 1411.85W 10,286', 51-1/4°, Sl8W, 7371.30, 6137.25 VS, 5902.43S, 1685.27W 10,847', 47-1/4°, Sl7W, 7737.49, 6562.23 VS, 6307.75S, 1813.06W 13-3/8" @ 2529' 11,666' PBTD, (653') Drlg Wt 9.9, Vis 47, PV 19, YP 17, PH 8.5, WL 10, Sol 13 Drl & surv f/11,097' - 11,750'. 11002', 46 1/2°, S17W, 7843.45, 6675.36, 6415.93S, 1846.14W 11490', 45 3/4°, Sl7W, 8181.68, 7027.13, 6752.34S, 1948.99W 13-3/8" @ 2529' 12,035' , (285'), Rn'g 9-5/8" Wt. 10, PV 20, YP 16, PH 8.5, WL 10, Sol 13 Drl 12¼" hole to 12,035', 15 std short trip, CBU, TOH. RU & begin rn'g 9-5/8" csg. 11,995', 45-1/2°, S17W, 8534.85 TVD, 7388.09 VS, 7097.53S, 2054.52W 13-3/8" @ 2529' 12,035' , (0'), Wrk'g stuck csg Wt. 10.0, PV 13, YP 9, PH 8.3, WL 11, Sol 12 Rn 228 its, 9-5/8" csg; pipe stopped @ 9318'. Wrk stuck csg, circ w/rig pmps, spot 70 bbls crude oil in ann w/60 bbls in csg. 9-5/8" @ 9318' 9316', Drlg cmt & FS Wt. 9.9, PV 16, YP 18, PH 9, WL 9.8, Sol 12 Wrk stuck csg, circ. M&P 500 sx C1 "G" w/l% CFR-2 & .15% HR-7. Displ w/rig pmps, bump plug. CIP @ 1000 hrs, 11/29/84. ND 20" Hydrl, NU BOPE & tst pack-off to 5000 psi. PU 8-1/2" BHA, RIH to FC @ 9236'. Drl FC, cmt & FS. 9-5/8" @ 9318' 11,820', Rm'g Wt. 10.6, PV 19, YP 8, PH 10, WL 4.2, Sol 14 Fin drlg flt equip, wsh to 9339', pull into csg, CBU. Conduct formation tst to 12.0 EMW. Wt sys up to 10.4 ppg, wsh & rm tight hole 9339'-9527'. RIH, circ w/mud @ 10,604', lost ret's, pull 40 stds slow, C&C thick mud. RIH to 10,416', circ. (Lost 350 bbls mud while att'g to circ.) Wsh & rm f/10,742'-11,850'. The above is correct Signature IDate 12/21/84 Title For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 8§ and 87 Drillin~ S..u p~e rin. t .e n.d e_nt KI'L IVI:U FEB 2 1 1985 Alaska 0ii & Gas Cons. Commission Anchorage 'ARCO Oil and Gas Company Daily Well History--Interim Instructlone: This form is used duHn'g drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem lests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheels until final completion. Report official or representative test on "Finel" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and t'ollowing setting of oil strin§ until completion. District Field Alaska I County or Parish IState North Slope Borough ILease ADL #28328 or Unit Complete record for each day while drilling or workover in progress Alaska Prudhoe Bay 12/04/84 Date and deptl~ as of 8:00 a.m. 12/05/84 12/06/84 12/07/84 thru 12/10/84 9-5/8" @ 9318' 11,884', (64'), Wsh & rm @ 11,884' Wt. 10.7+, PV 20, YP 7, PH 10, WL 4.2, Sol 16 Rm & wsh to 11,884', lost 800 psi pmp press, POH; bit had wsh'd out nozzle. TIH, wsh & rm f/11,839'-11,884'. 9-5/8" @ 9318' 12,670', (784'), Drlg 8½" hole Wt. 10.7+, PV 19, YP 8, PH 9.4, WL 4.2, Sol 19 Wsh & rm to 12,035', drl to 12,670'. 9-5/8" @ 9318' 12,950', (280'), Drlg Wt. 10.5+, PV 19, YP 8, PH 9.5, WL 4.5, Sol 18 Drl to 12,846', POOH lk'g f/wsh out. Chg bit, TIH, rm 11,870'-11,901' & 12,424'-12,454', break circ. Rm 12,734'-12,780'; losing fluid. C&C mud back to 10.5 ppg, pmp med LCM, rm to 12,846', drl to 12,950'. Lost 400 bbl to formation. Appears to be hole in 9-5/8" csg high up. 7" @ 13,032' 8840' TOC, (0'), TOH, monitor well Wt. 10.5, PV 20, YP 9, PH 9.4, WL 4.4, Sol 16 TOH, chg rams to 7" & tst doors to 3000 psi. Rn 134 jts, 7" AB Mod 29# csg + mkr jt w/FC @ 13,000.33', FS @ 13,032.00'. M&P 450 sx C1 "G" w/5% KC1, .% CFR-2 & .3% Halad-24. Displ using rig pmps, bump plug. Full rtns thruout job. CIP @ 0330 hrs, 12/9/84. TIH, wsh & rm 12,760'-13,032', CBU, TOH. RU Schl, rn DIL/BHCS/SP/GR f/13,032'-11,960', rn GR f/13,032'-2529',-rn CET w/o success. Rn CCL; csg appears to be parted @ connection @ ±590', POOH, RD Schl. RIH, CBU @ 9-5/8" shoe, rm 12,732'-12,790' & 12,978'-13,032', CBU, pmp 50 bbls LCM/Soltex pill in open hole. Chg rams to 5", tst doors to 3000 psi; OK. TIH w/9-5/8" EZ Drl, set @ 8926'. Est IR @ 3 BPM/1550 psi, pmp 200 sx C1 "G" w/5% KC1, 1% CFR-2 & .3% Halad-24. Displ cmt. RU to circ DP; well flowing, monitor well. Isolate stdpipe & SI well w/SIDP @ 75 psi. Circ thru choke, open well & monitor. Circ & observe well; still flowing. SI, bleed off press, open well & observe; well barely flowing. TOH w/20 stds, observe well. Cont POOH. no, ~-12 The above is correct Signature Drilling, Pages 86 and 87 IDate ITiUe 12/2o/84 Drilling Superintendent RECEIVED FEB 2 1 19B5 Alaska 0il & Gas Cons. commission ARco Oil and Gas Company ~, Daily Well History--Interim · · ' I'n, or workover operations If testing coring, or perforating, show format on name in describing work performed. In.trucUons: This form is used du.rjn..g d~!.~ ..... :-"-n of all core~ Work ne~'formed by Produc ng Section will be reported on "Interim" sheets until final Number all dri stem tests sequent~auy: .~?a~.r~ uu=~.,,,?,-.~_ ......... ~ ~,,~,,~', ~ "~-ter m" ,hne. tS when filled out but not less frequently than every 30 days, or (2) completion. Report official or representa,ve test on Fiilill! ~uH,. ~1 .................... on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish IState Alaska North Slope Borough Alaska Field [Lease or Unit ]Well no. Prudhoe Bay ADL #28328 I 11-12 Date and deptl~ as of 8:00 a.m. 12/11/84 12/12/84 12/13/84 Complete record for each day while drilling or workover in progress 7" @ 13,032' 8840' TOC, (0'), ND stack Wt. 10.5, PV 20, YP 3, PH 9.4, WL 4.4, Sol 16 TOH, monitor well, LD cmt stinger. Chg lower rams to 9-5/8", tst doors to 3000 psi. PU Tri-State spear, TIH to 604', RU Gearhart & APR, shoot string shot @ 676', back out csg, LD 15 its 9-5/8" & spear. MU 9-5/8" screw-in sub w/skirt. Rn 16 jts, 9-5/8", screw into 9-5/8" csg. ND stack, set csg slips, cut off 9-5/8" & dress stub. NU BOPE. 7" @ 13,032' 9029' TOL, Tag TOL @ 9029' Wt. 10.0, PV 12, YP 7, PH 12, WL 6.2, Sol 16 Fin NU BOP stack, tst pkoff & ring gasket to 5000 psi; OK. Rn wear ring, tst csg to 3000 psi; OK. Clr rig flr, LD stab, roller reamer. PU Bit #14 & BHA. TIH to 8508'. Brk circ, wsh 8508'-8615'. Circ out flocculated/contaminated mud. Wsh to 8868'. Tag firm cmt@ 8868'. Drl hard cmt 8868'-8926'. Chg out swivel pkg. Drl cmt ret (EZ drl) & hard cmt to TOL. 7" @ 13,032' 12,995' PBTD, Prep to Chg Over to 9.2 NaC1 Wt. 10, PV 16, YP 10, PH 12, WL 6.6, Sol 17 CBU, POH, LD 8-1/2" BHA. MU 6" BHA, RIH, tag cmt@ 12,8327~ DO cmt. tst 7" ins & 9-5/8" csg tp 3000 psi; OK. POH, PU csg scpr, RIH. Tho above is correct Signature For for~ ~reparation and ~l~tribu~i(~n see Procedures Manual S~ction 10, Drilling, Pages 86 and 87 IDale ITitle 12/20/841 Drilling Superintendent RECEIVED FF B 2 1 1985 Alaska Oil & Gas Cons, commission asCompany ,*' Daily Well History-Final Report and submit the '~Finat Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold, be submitted also whea operations.are suspended for an indefinite or appreciable length of time. On workovers when an official test is not )letion, report completion and representative teat data in blocks provided. The "Final Repo~' form may be used for reporting Ihe entire if SPace is available. _ :': Dl~trict Alaska Field - Prudhoe Bay Auth. or W.O. no. AFE 703443 Parker #176 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date"and depth as of 8:00 a.m. ICounty or Parish Lease or Unit North Slope Borough ITitle ADL #28328 Drill & Complete Accounting cost center code 12/14/84 Slate Alaska IWell no. 11-12 AP1 50-029-21212 A.R.Co. W.I. rrotal number of wells (active or inactive) on this Icost center prior to plugging and I 21.66% labandonment of this well i Date IHour I Prlor status if a W.O, 0800 Hrs. / 11/16/84 Complete record for each day reported 7" @ 13,032' 12,995' PBTD, RR Rn CBL; tl failed. Chg out same & rn CBL 12,995'-11,790'. Pull to rn CBL across 9-5/8" shoe & lnr lap; computer failed. POH. RU & rn 94 its, 3-1/2", 9.2# N-80 BTC + 214 its 5-1/2", 17#, L-80 8RD w/shear out sub @ 12,004' (TT), Bkr FHL Pkr @ 11,907', Bal-o-Valve @ 2195'. Tst pkoff to 5000 psi. ND BOPE. NU X-mas tree & tst. RR @ 2400 hrs 12/14/84. Old TD Released rig New TD Date I PB Depth 12,995' Kind of rig Rotary Classifications (oil, gas, etc.) O±l Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing .................. IJ Er r" Il /~-~,~ Well no. Date R ..... ir Producing Interval Oil or gas Tes~'ti~nL ~'~ F'r°luc~n ~ U Oil on test Gas per day FE 1 1985 Gravity Allowable Effective date Pump size, SPM X length Choke size T.P. C.P. Water % GO. A/ask ~co~te& Gm Cons. C0mmi~',si0~ Anc, The above is cornet Signature For form preparation a~d distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. JOate 12/20/84 JTit,e Drilling Superintendent ! January 30, 1985 Directional Services Pressure Services Chemical Transmission Systems Mr. Randy Ruedrich ARCO Alaska, Inc. P. 0. Box 360 Anchorage, Alaska 995 i 0 Re: Our Boss Gyroscopic Survey Job No. AK-BO-40098/LB-4~)100 Well: 11-12 (SEC 33 1~IIN R15E) Field: Prudhoe Bay Alaska Survey Date: December 28, 1984 Operator: McGuire Mr. Ruedrirh: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Multishot Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures NL Sperry-Sun/NL Industries, Inc. P.O. Box 6207, Anchorage, AK 99502'0207 (907) 563-3430 RECEIVED FE~ 2 1 ]985 Alaska 0il & Gas Cor~s. Commission Anchorage ARCO ALASKA, INC. 11-12 (SEC33 TllN R15E) PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA VERTICAL SECTION CALCULATED ALONG CLOSURE TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEPTH DEG MIN COMPUTATION DATE dANUARY 2, 1985 COURSE DIRECTION DEGREES DOG-LEG SEVERITY DEG/100 PAGE 1 DATE OF SURVEY DECEMBER 28, 1984 BOSS GYROSCOPIC SURVEY ........ dOB NUMBER AK-BO40098/LB40100 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR-MCGUIRE TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERTICAL SECTION 0 0.00 -58.00 0 0 100 100.00 42.00 0 10 200 200.00 142.00 0 15 300 300.00 242.00 0 11 400 400.00 342.00 0 5 500 500.00 442.00 0 10 600 600.00 542.00 0 15 700 700.00 642.00 0 19 800 799.99 741.99 0 13 900 899.99 841.99 0 19 1000 999.99 941.99 0 21 1100 1099.99 1041.99 0 19q 1200 1199.99 1141.99 0 19 1300 1299.99 1241.99 0 25 1400 1399.98 1341.98 0 30 1500 1499.97 1441.97 I 19 1600 1599.86 1541.86 3 30 1700 1699.62 1641.62 4 19 1800 1799.30 1741.30 4 56 1900 1898.81 1840.81 6 13 2000 1997.99 1939.99 8 22 2100 2096.49 2038.49 11 24 2150 2145.37 2087.37 12 51 2200 2193.94 2135.94 14 33 2250 2242.29 2184.29 14 58 2300 2290.43 2232.43 16 21 2350 2338.17 2280.17 18 11 2400 2385.37 2327.37 20 18 2450 2431.94 2373.94 22 18 2500 2477.93 2419.93 23 52 O. 0 E 63.89 E 34.50 E 25.50 E 18.19 E 27.69 E 0.89 E 18.89 E 15.80 E 38.19 E 31.60 E 37.30 E 19.30 E S24. OE 11.10 E 9.69 W 20.80 W 24.19 W 23.60 W 12.80 W 6.89 W 2.89 W 2.60 W 4.80 W 4.80 W 5.19 W 5. OW 4.80 W 4.39 W 4.89 W O. O0 O. O0 O. O0 0.18 0.07 S 0.14 E 0.13 0.32 S 0.41 E 0.07 0.65 S 0.60 E 0.10 0.87 S 0.70 E 0.09 1.09 S 0.79 E 0.12 1.44 S 0.87 E 0.11 1.92 S 0.96 E 0.09 2.38 S 1.11 E 0.14 2.79 S 1.34 E 0.05 3.27 S 1.67 E 0.05 3.76 S 2.00 E 0.10 4.25 S 2.26 E 0.10 4.86 S 2.51 E 0.14 5.63 S 2.74 E 0.87 7.21 S 2.63 E 2.22 11.22 S 1.35 E 0.85 17.52 S 1.28 W 0.61 24.91 S 4.56 W 1.66 34.15 S 7.48 W 2.26 46.66 S 9.56 W 3.11 63.77 S 10.'73 W 2.88 74.26 S 11.44 W 3.56 86.08 S 12.21 W 0.84 98.77 S 13.28 W 2.79 112.22 S 14.46 W 3.66 127.01 S 15.78 W 4.22 143.42 S 17.18 W 4.03 161.53 S 18.64 W 3.14 181.07 S 20.23 W 0.00 0.03 0.19 0.45 0.64 0'82 1.14 1.58 1.97 2.31 2.67 3.04 3.44 3.96 4.63 6.18 10.38 17.17 25.19 34.87 47.47 64.27 74.49 86.04 98.52 111.76 126.32 142.47 160.26 179.46 ARCO ALASKA, INC. 11-12 (SEC33 TIlN R15E) PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE dANUARY 2, 1985 VERTICAL SECTION CALCULATED ALONG CLOSURE PAGE DATE OF SURVEY DECEMBER 28, 1984 BOSS GYROSCOPIC SURVEY .... dOB NUMBER AK-BO40098/LB40100 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR-MCGUIRE TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEPTH DEG MIN COURSE DIRECTION DEGREES DOG-LEG SEVERITY DEG/IO0 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT I CAL SECTION 2600 2569.16 2511.16 24 30 2700 2659.85 2601.85 25 18 ~00 2749.66 2691.66 26 51 2900 2837.96 2779.96 29 6 3000 2924.49 2866.49 31 1 3100 3008.66 2950.66 34 18 3200 3090.00 3032.00 36 48 3300 3168.77 3110.77 39 14 3400 3244.93 3186.93 41 31 3500 3318.94 3260.94 42 59 3600 3391.63 3333.63 43 45 3700 3464.58 3406.58 42 32 3800 3536.48 3478.48 45 30 3900 3604.98 3546.98 48 1 4000 3670.19 3612.19 50 34 4100 3732.40 3674.40 52 28 4200 3793.30 3735.30 52 29 4300 3854.25 3796.25 52 24 4400 3914.83 3856.83 53 0 4500 3975.37 3917.37 52 28 4600 4036.07 3978.07 52 46 4700 4097.07 4039.07 52 2 4800 4158.48 4100.48 52 11 4900 4219.61 4161.61 52 26 5000 4280.86 4222.86 52 1 5100 4341.71 4283.71 53 0 5200 4402.47 4344.47 52 9 5300 4463.94 4405.94 51 58 5400 4525.30 4467.30 52 19 5500 4586.27 4528.27 52 32 6.39 W 9. OW 10.10 W 11.30 W 11.39 W 13.10 W 14.89 W 16.60 W 16.69 W 17.50 W 17.69 W 15.69 W 14.89 W 14.19 W 13.60 W 13.69 W 13.89 W 14.69 W 14.69 W S15. OW 15.19 W 15.89 W 15.89 W S16. OW 15.50 W 15.39 W 16.80 W 16.69 W 16.19 W 15.89 W Om 1. 1. 2. 1. 3. 2. 2. 2. 1. O. 1. 3. 2. 2. 1. O. O. O. O. O. O. O. O. O. O. 1. O. O. O. 88 221.84 S 24.27 W 219.72 36 263.55 S 29.92 W 261.34 61 306.90 S 37.23 W 304.99 33 352.99 S 45.95 W 351.67 92 402.10 S 55.81W 401.58 41 454.83 S 67.30 W 455.42 71 511.25 S 81.39 W 513.52 65 570.52 S 98.14 W 575.10 28 632.57 S 116.70 W 639.88 57 696.84 S 136.47 W 707.11 78 762.30 S 157.24 W 775.76 83 827.79 S 176.90 W 844.14 O1 894.81S 195.22 W 913.61 57 965.32 S 213.51W 986.42 60 1038.91S 231.72 W 1062.16 89 1114.97 S 250.19 W 1140.35 16 1192.00 S 269.11W 1219.58 64 1268.82 S 288.69 W 1298.82 60 1345.77 S 308.88 W 1378.34 58 1422.71S 329.28 W 1457.91 33 1499.43 S 349.98 W 1537.36 92 1575.76 S 371.22 W 1616.58 15 1651.67 S 392.84 W 1695.50 26 1727.76 S 414.59 W 1774.64 57 1803.84 S 436.05 W 1853.69 97 1880.32 S 457.18 W 1933.03 39" 1956.62 S 479.20 W 2012.44 20 2032.15 S 501.~3 W 2091.31 52 2107.88 S 524.29 W 2170.27 32 2184.05 S 546.20 W 2249.53 ARCO ALASKA, INC. 11-12 (SEC33 TllN R15E) PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE dANUARY 2, 1.985 VERTICAL SECTION CALCULATED ALONG CLOSURE PAGE 3 DATE OF SLIRVEY DECEMBER 28, 1.984 BOSS GYROSCOPIC SURVEY dOB NUMBER AK-BO400.98/LB40100 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR-MCGUIRE TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEPTH DEG MIN COURSE DOG-LEG DIRECTION SEVERITY DEGREES DEG/100 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERTICAL SECTION 5600 4646..98 4588..98 52 41 5700 4707.5.9 464.9.5.9 52 41 5800 4768.30 4710.30 52 31 5.900 482.9.27 4771.27 52 20 6000 48.90.23 4832.23 52 32 6100 4.951.36 48.93.36 52 5 6200 5012.71 4.954.71 52 13 6300 5073.83 5015.83 52 25 6400 5134.30 5076.30 53 8 6500 51.94.38 5136.38 53 0 6600 5254.50 51.96.50 53 6 6700 5314.46 5256.46 53 12 6800 5373.81 5315.81 53 58 6.900 5431..93 5373..93 54 56 7000 548.9.41 5431.41 54 52 7100 5546..93 5488..93 54 52 7200 5604.16 5546.16 55 18 7300 5661.01 5603.01 55 24 7400 5717.58 565.9.58 55 40 7500 5773..90 5715..90 55 46 7600 5830.25 5772.25 55 37 7700 5886..91 5828..91 55 21 7800 5.944.22 5886.22 54 42 7.900 6001.73 5.943.73 55 4 8000 605.9.1.9 6001.1.9 54 46 8100 6116.50 6058.50 55 18 8200 6173.38 6115.38 55 22 8300 6230.05 6172.05 55 35 8400 6286.71 6228.71 55 22 8500 6343.50 6285.50 55 23 16.1.9 W 0.28 16.10 W O. 08 15.80 W 0.2.9 16. I0 W O. 30 16. 0 W O. 21 16.10 W O. 46 16.6.9 W 0.4.9 16.80 W 0.22 17. OW 0.74 17.1.9 W 0.22 17.10 W O. 13 17.6.9 W 0.4.9 18.1.9 W 0.87 18.3.9 W 0..98 18.60 W O. 18 18.50 W 0.08 1.9.60 W 1.00 1.9.3.9 W 0.20 1.9.69 W 0.37 19.89 W O. 19 20.50 W O. 52 20.80 W O. 37 21.3.9 W 0.81 21.80 W 0.4.9 22.3O W 0.51 22.60 W 0.58 22.50 W 0.11 22. 0 W O. 47 21.89 W 0.23 21.8.9 W 0.02 2260.41S 568.17 W 2328..9.9 2336.82 S 590.30 W 2408.53 2413.21S 612.13 W 2487..99 248.9.43 S 633..91W 2567.25 2565.61S 655.83 W 2646.52 2641.66 S 677.71W 2725.66 2717.42 S 700.01W 2804.62 2793.21S 722.82 W 2883.77 286.9.41S 745..97 W 2.963.41 2.945.82 S 76.9.48 W 3043.34 3022.18 S 7.93.04 W 3123.25 30.98.54 S 816.97 W 3203.26 3175.11S 841.78 W 3283.71 3252.96 S 867.33 W 3365.03 332.9.96 S 8.93.2.9 W 3446.80 3407.51S .91.9.31W 3528.54 3485.02 S .946.08 W 3610.45 3562.57 S .973.54 W 36.92.59 3640.27 S 1001.13 W 3774..91 3718.02 S 1029.13 W 3857.40 3795.55 S 1057.65 W 3.939.82 3872.66 S 1086.71W 4021..98 3.94.9.11S 1116.21W 4103.64 4025.17 S 1146.32 W 4185.10 4101.02 S 1177.05 W 4266.54 4176.76 S 1208.34 W 4348.02 4252.72 S 1239.88 W 4429.78 4328.98 S 1271.08 W 4511.73 4405.41S 1301.88 W 4593.73 4481.77 S 1332.58 W 4675.b4 ARCO ALASKA, INC. 11-12 (SEC33 T11N R15E) PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA VERTICAL SECTION CALCULATED ALONG CLOSURE TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEPTH DEG MIN COMPUTATION DATE dANUARY 2, 1985 COURSE DIRECTION DEGREES DOG-LEG SEVERITY DEG/IO0 PAGE 4 DATE OF SURVEY DECEMBER 28, 1984 BOSS GYROSCOPIC SURVEY dOB NUMBER AK-BO40098/LB40100 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR-MCGUIRE TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT I C:AL SECTION 8600 6399.73 6341.73 56 10 8700 6455.35 6397.35 56 15 8800 6510.36 6452.36 57 0 8900 6564.94 6506.94 56 50 9000 6619.52 6561.52 57 0 9100 6673.99 6615.99 57 0 9200 6728.45 6670.45 57 0 9300 6783.21 6725.21 56 35 9400 6838.40 6780.40 56 25 9500 6894.31 6836.31 55' 35 9600 6951.36 6893.36 54 50 9700 7009.07 6951.07 54 40 9800 7067.37 7009.37 54 0 9900 7125.85 7067.85 54 25 10000 7184.68 7126.68 53 30 10100 7244.86 7186.86 52 30 10200 7306.37 7248.37 51 35 10300 7369.00 7311.00 50 50 10400 7432.49 7374.49 50 20 10500 7496.54 7438.54 50 0 10600 7561.48 7503.48 49 0 10700 7627.30 7569.30 48 40 10800 7693.78 7635.78 48 0 10900 7761.23 7703.23 47 10 11000 7829.69 7771.69 46 25 11100 7898.99 7840.99 45 50 11200 7968.77 7910.77 45 40 11300 8038.85 7980.85 45 20 11400 8108.94 8050.94 45 40 11500 8178.97 8120.97 45 25 21.39 W 20.89 W 20.80 W 20.50 W S 20. OW 19.39 W 18.80 W 18.50 W 18.19 W 17.69 W 17.19 W 17.19 W 16.10 W 16.39 W 14.89 W 14.80 W 15.80 W 15.39 W 15.50 W 15.80 W 14.80 W 16.19 W 15.89 W 15.50 W 15.60 W 15.10 W 13.60 W 13.89 W 13.80 W 13.30 W O. O. O. O. O. O. O. O. O. O. O. O. 1. O. 1. 1. 1. O. O. O. 1. 1. O. O. O. O. 1. O. O. O. 87 42 75 30 45 50 50 48 30 93 86 17 12 49 52 O0 20 81 51 41 26 10 71 88 75 68 09 39 34 44 4558.63 4636.14 4714.18 4792.58 4871.19 4950.15 5029.40 5108.68 5187.83 5266.70 5345.05 5423.06 5500.89 5578.77 5656.62 5733.81 5809.86 5884.94 5959.41 6033.36 6106.70 6179.24 6251.03 6322.10 6392.32 6461.84 6531.23 6600.52 6669.78 6739.17 1363.09 W 1393.07 W 1422.79 W 1452.34 W 1481.34 W 1509.61W 1537.06 W 1563.81W 1590.07 W 1615.62 W 1640.25 W 1664.40 W 1687.68 W 1710.38 W 1732.19 W 1752.66 W 1773.46 W 1794.43 W 1815.01W 1835.72 W 1855.79 W 1875.91W 1896.56 W 1916.54 W 1936.08 W 1955.16 W 1972.92 W 1989.87 W 2006.95 W 2023.67 W 4757.98 4840.79 4924.04 5007.59 5091.18 5174.90 5258.67 5342.27 5425.61 5508.48 5590.60 5672.25 5753.49 5834.61 5915.45 5995.29 6074.12 615-'. 06 6229.31 6306.10 6382.12 6457.39 6532.09 6605..92 6678.80 6750.88 6822.47 6893.73 6964.99 7036.29 ARCO ALASKA, INC. 11-12 (SEC33 TllN R15E) PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE dANUARY 2, 1985 VERTICAL SECTION CALCULATED ALONG CLOSURE PAGE 5 DATE OF SURVEY DECEMBER 28~ 1984 BOSS GYROSCOPIC SURVEY JOB NUMBER AK-BO40098/LB40100 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR-MCGUIRE "' TRUE MEASURED VERTICAL DEPTH DEPTH SUB-SEA COURSE COURSE DOG-LEG TOTAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES DEPTH DEG MIN DEGREES DEG/100 NORTH/SOUTH EAST/WEST VERTICAL SECTION 11600 8249.11 8191.11 45 30 S 13.19 W 0.11 6808.55 S 2040.01W 11700 8319.15 8261.15 45 35 S 13.69 W 0.37 6877.97 S 2056.61W 11800 8389.85 8331.85 44 25 S 15. 0 W 1.49 6946.47 S 2074.13 W 11900 8460.08 8402.08 46 20 S 15. 0 W 1.92 7015.21 S 2092.55 W 12000 8529.43 8471.43 45 50 S 14.80 W 0.52 7084.84 S 2111.07 W 12100 8598.84 8540.84 46 .15 S 13. 0 W 1.36 7154.71 S 2128.36 W 12200 8667.36 8609.36 47 15 S 14.19 W 1.33 7225.49 S 2145.49 W 12300 8734.26 8676.26 48 45 S 14. 0 W 1.51 7297.56 S 2163.59 W 12400 8799.59 8741.59 49 40 S 13.69 W 0.95 7371.07 S 2181.71 W 12500 8862.96' 8804.96 51 40 S 14. 0 W 2.01 7446.16 S 2200.23 W 12600 8924.29 8866.29 52 40 S 14. 0 W 1.00 7522.79 S 2219.34 W 12700 8984.58 8926.58 53 10 S 14. 0 W 0.50 7600.20 S 2238.64 W 12800 9043.34 8985.34 54 50 S 13.69 W 1.69 7678.75 S 2258.00 W 12900 9100.34 9042.34 55 40 S 13.60 W 0.83 7758.60 S 2277.39 W 13000 9156.73 9098.73 55 40 S 13.60 W 0.00 7838.86 S 2296.81 W 13032 9174.78 9116.78 55 40 S 13.60 W 0.00 7864.55 S 2303.02 W 7107.46 7178.75 724~.41 7320.56 7392.59 7464.50 7537.25 7611.50 7687.14 7764.40 7843.32 7~23.03 8003.86 8085.93 8168.42 8194.82 HORIZONTAL DISPLACEMENT = 8194.82 ~EET AT SOUTH 1~ DEG. 19 MIN. WEST AT MD = 13032 THE CALCULATION PROCEDURES ARE BASED ON THE USE O~ THREE DIMENSIONAL RADIUS O~ CURVATURE METHOD. ARCO ALASKA, INC. 11-12 (S£C33 TIlN R15E) PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE dANUARY 2, 1985 PAGE 6 DATE OF SURVEY DECEMBER 28, 1984 dOB NUMBER AK-BO40098/LB40100 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR-MCGUIRE MEASURED DEPTH INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 0.00 -58.00 0.00 0.00 0.00 1000 999.99 941.99 3.27 S 1.67 E 0.01 0.01 2000 1997.99 1939.99 46.66 S 9.56 W 2.01 2.01 3000 2924.49 2866.49 402.10 S 55.81 W 75.51 73.50 4000 3670.19 3612.19 1038.91 S 231.72 W 329.81 254.30 5000 4280.86 4222.86 1803.84 S 436.05 W 719.14 389.33 6000 4890.23 4832.23 2565.61 S 655.83 W 1109.77 390.62 7000 5489.41 5431.41 3329.96 S 893.29 W 1510.59 400.82 8000 6059.19 6001.19 4101.02 S 1177.05 W 1940.81 430.21 9000 6619.52 6561.52 4871.19 S 1481.34 W 2380.48 439.67 10000 7184.68 7126.68 5656.62 S 1732.19 W 2815.32 434.84 11000 7829.69 7771.69 6392.32 S 1936.08 W 3170.31 354.99 12000 8529.43 8471.43 7084.84 S 2111.07 W 3470.57 300.26 13000 9156.73 9098.73 7838.86 S 2296.81 W 3843.27 372.70 13032 9174.78 9116.78 7864.55 S 2303.02 W 3857.22 13.95 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. ARCO ALASKA, INC. 11-12 (SEC33 TllN R15E) PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE dANUARY 2, 1985 PAGE 7 DATE OF SURVEY DECEMBER 28, 1984 dOB NUMBER AK-BO40098/LB40100 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR-MCGUIRE MEASURED DEPTH INTERPOLATED VALUES FOR EVEN 100 FEET OF otB-oEA DEPTH . TRUE VERTICAL DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 58 158 258 358 458 558 658 758 858 958 1058 1158 1258 1358 1458 1558 1658 1758 0.00 58.00 158.00 258.00 358.00 458.00 558.00 658.00 758.00 858.00 958.00 1058.00 1158.00 1258.00 1358.00 1458.00 1558.00 1658.00 1758.00 -58.00 0.00 0.00 0.00 0.00 0.01S 0.03 E 0.00 100.00 0.17 S 0.30 E 0.00 200.00 0.52 S 0.54 E 0.00 300.00 0.81 S 0.68 E 0.00 400.00 0.97 S 0.73 E 0.00 500.00 1.26 S 0.87 E 0.00 600.00 1.70 S 0.89 E 0.00 700.00 2.22 S 1.06 E 0.01 800.00 2.61S 1.19 E 0.01 900.00 3.06 S 1.53 E 0.01 1000.00 3.57 S 1.86 E 0.01 1100.00 4.02 S 2.18 E 0.01 1200.00 4.58 S 2.38 E 0.01 1300.00 5.26 S 2.67 E 0.02 1400.00 6.26 S 2.79 E 0.02 1500.00 8.85 S 2.24 E 0.06 1600.00 14.66 S 0.00 W 0.26 1700.00 21.65 S 3.13 W 0.55 O. O0 0.00 O. O0 O. O0 0.00 O. O0 O. O0 O. O0 O. O0 O. O0 O. O0 O. O0 O. O0 O. O0 0.01 O. 04 O. 2O O. 29 ARCO ALASKA7 INC. 11-12 (SEC33 TllN R15E) PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE dANUARY 2~ 1985 PAGE 8 DATE OF SURVEY DECEMBER ~b~ 1984 dOB NUMBER AK-BO40098/LB40100 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR-MCGUIRE MEASURED DEPTH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE VERTICAL DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 1858 1959 2060 2162 2266 2370 2478 2587 2697 2809 2922 3039 3160 3286 3417 3553 3691 3830 3980 1858.00 1958.00 2058.00 2158.00 2258.00 2358.00 2458.00 2558.00 2658.00 2758.00 2858.00 2958.00 3058.00 3158.00 3258.00 3358.00 3458.00 3558.00 3658.00 1800.00 29.82 S 6.49 W 0.94 1900.00 40.83 S 8.85 W 1.58 2000.00 56.44 S 10.48 W 2.81 2100.00 77.16 S 11.57 W 4.96 2200.00 103.00 S 13.64 W 8.27 2300.00 133.60 S 16.35 W 12.91 2400.00 172.32 S 19.48 W 20.22 2500.00 216.78 S 23.70 W 29.74 2600.00 262.69 S 29.79 W 39.95 2700.00 311.05 S 37.97 W 51.34 2800.00 363.93 S 48.14 W 64.94 2900.00 422.35 S 60.03 W 81.38 3000.00 488.48 S 75.48 W 102.29 3100.00 562.15 S 95.67 W 128.14 3200.00 643.65 S 120.02 W 159.45 3300.00 731.67 S 147.47 W 195.48 3400.00 821.97 S 175.27 W 233.07 3500.00 916.30 S 200.89 W 272.93 3600.00 1024.63 S 228.25 W 322.91 0.39 0.64 1.23 2.15 3.31 4.64 7.31 9.52 10.21 11.39 13.60 16.44 20.90 25.85 31.31 36.03 37.5? 39.87 49.97 ARCO ALASKA, INC. 11-12 (SEC33 TllN R15E) PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE dANUARY~, ~ 1985 PAGE DATE OF SURVEY DECEMBER 28, 1984 ..lOB NUMBER AK-BO40098/LB40100 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR-MC:GU I RE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH MEASURED DEPTH TRUE VERTICAL DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 4142 4306 4471 4636 4799 4962 5127 5290 5453 5618 5783 5947 6'110 6'274 6'439 66,05 6'773 6--,945 7119 3758.00 3858.00 3958.00 4058.00 4158.00 4258.00 4358.00 4458.00 4558.00 46'58.00 4758.00 4858.00 4958.00 5058.00 5158.00 5258.00 5358.00 5458.00 5558.00 3700,00 1147.35 S 258.09 W 384.03 3800.00 1273.54 S 289.93 W 448.15 3900.00 1400.86' S 323.42 W 513.48 4000.00 1527.28 S 357.55 W 578.25 4100.00 16'51.07 S 392.67 W 641.21 4200.00 1775.62 S 428.22 W 704.85 4300.00 1901.17 S 462.93 W 769.07 4400.00 2024.88 S 499.75 W 832.36 4500.00 2148.59 S 536.09 W 895.54 46'00.00 2274.30 S 572.21 W 960.18 4700.00 2400.28 S 6'08.47 W 1025.06 4800.00 2525.22 S 644.24 W 1089.04 4900.00 2649.85 S 680.07 W 1152.80 5000.00 2773.50 S 716.87 W 1216.04 5100.00 2899.64 S 755.21W 1281.51 5200.00 3026.6'4 S 794.41W 1347.84 5300.00 3154.45 S 834.99 W 1415.12 5400.00 3287.62 S 879.06' W 1487.3~ 5500.00 3422.43 S 924.31 W 1561.24 61.12 64.13 65.33 64.76 62.97 63.64 64.'22 63.29 63.18 64.64 64.88 63.98 63.76 63.23 65.48 66.32 67.28 72.28 73.84 ARCO ALASKA, INC. 11-12 ¢$EC33 TllN R15E) PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE dANUARY 2, 1985 PAGE 10 DATE OF :SURVEY DECEMBER 28, 1984 dOB NUMBER AK-BO40098/LB40100 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR-MCGUIRE MEASURED DEPTH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE VERTICAL DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 7294 7471 7649 7823 7997 8172 8349 8525 8704 8887 9070 9254 9435 9611 9784 9955 10121 10282 10439 5658. 5758. 5858. 5958. 6058. 6158. 6258. 6358. 6458. 6558. 6658. 6758. 6858. 6958. 7058. 7158. 7258. 7358. 7458. O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 5600.00 3558.45 S 972.09 W 1636.70 5700.00 3696.05 S 1021.17 W 1713.73 5800.00 3833.51 S 1071.86 W 1791.12 5900.00 3967.23 S 1123.31 W 1865.86 6000.00 4099.46 S 1176.41W 1939.93 6100.00 4232.15 S 1231.36 W 2014.94 6200.00 4366.79 S 1286.35 W 2091.44 6300.00 4501.27 S 1340.42 W 2167.53 6400.00 4639.84 S 1394.49 W 2246.77 6500.00 4782.63 S 1448.62 W 2329.31 6600.00 4926.93 S 1501.44 W 2412.64 6700.00 5072.39 S 1551.66 W 2496.17 6800.00 5215.87 S 1599.29 W 2577.43 6900.00 5354.05 S 1643.04 W 2653.54 7000.00 5488.50 S 1684.10 W 2726.06 7100.00 5621.72 S 1722.85 W 2797.09 7200.00 5750.36 S 1757.04 W 28~3.58 7300.00 5871.91 S 1790.84 W 2924.57 7400.00 5989.07 S 1823.23 W 2981.98 75.46 77.04 77.39 74.73 74.08 75.00 76.50 76.09 79.24 82.54 83.33 83.53 81.26 76.11 72.52 71.03 66.49 61.00 57.40 ARCO ALASKA, INC. 11-12 (SEC33 T11N R15E) PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE dANUARY 2, 1985 PAGE 11 DATE OF SURVEY DECEMBER 28, 1984 dOB NUMBER AK-BO40098/LB40100 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR-MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASURED VERTICAL D£PTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD D£PTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 10594 7558.00 7500.00 6102.83 S 1854.77 W 3036,70 10746 7658.00 7600.00 6212.71 S 1885.62 W 3088.44 10895 7758.00 7700.00 6318.74 S 1915.61 W 3137.25 11041 7858.00 7800.00 6420.97 S 1944.07 W 3183.06 11184 7958.00 7900.00 6520.52 S 1970.33 W 3226.59 11327 8058.00 8000.00 6619.33 S 1994.53 W 3269.24 11470 8158.00 8100.00 6718.46 S 2018.78 W 3312.12 11612 8258.00 8200.00 6817.35 S 2042.07 W 3354.68 11755 8358.00 8300.00 6916.25 S 2066.07 W 3397.36 11896 8458.00 8400.00 7013.11 S 2091.98 W 3438.99 12041 8558.00 8500.00 7113.29 S 2118.58 W 3483.01 12186 8658.00 8600.00 7215.68 S 2143.01 W 3528.21 12336 8758.00 8700.00 7323.82 S 2170.14 W 3578.00 12492 8858.00 8800.00 7440.07 S 2198.71 W 3634.01 12655 8958.00 8900.00 7565.80 S 2230.06 W 3697.68 12825 9058.00 9000.00 7698.97 S 2262.93 W 3767.45 13002 9158.00 9100.00 7840.67 S 2297.25 W 3844.25 13032 9174.78 9116.78 7864.55 S 2303.02 W 3857.22 54.72 51'75 48.81 45.81 43.54 42.65 42.88 42.55 42.68 41.63 44.02 45.20 49.79 56.01 63.68 69.77 76.80 12.97 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS mm ARCO ALASKA~ INC. 11-12 (SEC33 TllN R15E) PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE dANUARY 2, 1985 PAGE 12 DATE OF SURVEY DECEMBER 28, 19:B4 JOB NUMBER AK-BO40098/LB40100 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR-MCGUIRE MEASURED DEPTH INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH NORTH/SOUTH EAST/WEST MARKER 10048 7213.23 7155.23 5693.91 S 1742.12 W K-lO 11076 7882.27 7824.27 6445.21 S 1950.68 W K-5 11834 8414.13 8356.13 6969.46 S 2080.29 W BASE HRZ 11874 8442.13 8384.13 6997.05 S 2087.68 W LCU 11902 8461.46 8403.46 7016.61S 2092.92 W TOP SAG RIVER 11952 8495.99 8437.99 7051.54 S 2102.28 W TOP SHUBLIK A 11972 8509.92 8451.92 7065.41 S 2105.94 W TOP SHUBLIK B 11992 8523.86 8465.86 7079.29 S 2109.61 W TOP SHUBLIK C 12043 8559.39 8501.39 7114.66 S 2118.95 W TOP SADLEROCHIT 12260 8707.89 8649.89 7268.38 S 2156.32 W TOP ZONE 3 12337 8758.66 8700.66 7324.55 S 2170.32 W TOP ZONE 2 12806 9046.80 8988.80 7683.52 S 2259.16 W TOP ZONE lB 12806 9046.80 8988.80 7683.52 S 2259.16 W H.O.T. 12817 9053.13 8995.13 7692.25 S 2261.29 W H.O.T. 12861 9078.34 9020.34 7727.29 S 2269.82 W OIL/WATER CONTACT 12874 9085.67 9027.67 7737.73 S 2272.34 W OIL/WATER CONTACT 12900 9100.34 9042.34 7758.60 S 2277.39 W SURVEY DEPTH 12932 9118.38 9060.38 7784.28 S 2283.61 W BASE SADLEROCHIT 12995 9153.91 9095.91 7834.85 S 2295.84 W PLUG BACK TD ARCO ALASKA~ INC. 11-12 (SEC33 TllN R15E) PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAOE ALASKA COMPUTATION DATE dANUARY 2. 1985 PAGE DATE OF ._LiRVEY DECEMBER ~, 1984 dOB NUMBER AK-BO400~8/LB40100 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR-MCGUI RE INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MARKER 13032 9174.78 9116.78 7864.55 S 2303.02 W TOTAL DEPTH DRILLER ARCO ALASKA, INC. 11-12 (SEC33 T11N R15E) STRATIGRAPHIC SUMMARY DERIVED USING DIL DEPTHS AND SPERRY SUN SURVEY DATA MARKER ....... MEASURED DEPTH --TVD THICKNESS BKB BKB SUB-SEA VERTICAL K-lO K-5 BASE HRZ LCU TOP SAG RIVER TOP SHUBL IK A TOP SHUBLIK B TOP SHUBLIK C TOP SADLEROCHIT TOP ZONE 3 TOP ZONE 2 TOP ZONE lB H.O.T. H.O.T OIL/WATER CONTACT OIL/WATER CONTACT BASE SADLEROCHIT PLUG BACK TD 10048 7213.23 7155.23 11076 7882.27 7824.27 11834 8414.13 8356.13 11874 8442.13 8384.13 11902 8461.46 8403.46 11952 8495.99 8437.99 11972 8509.92 8451.92 11992 8523.86 8465.86 12043 8559.39 8501.39 12260 8707.89 8649.89 12337 8758.66 8700.66 12806 9046.80 8988.80 12806 9046.80 8988.80 12817 9053.13 8995.13 12861 9078.34 9020.34 12874 9085.67 9027.67 12932 9118.38 9060.38 12995 9153.91 9095.91 9174.78 9116.78 TOTAL DEPTH DRILLER 13032 COORDINATES WITH REF. TO WELLHEAD (ORIGIN- 136FNL ,107FEL) SEC 33 T11N R15E 5693.91S 1742.12W ) 6445.21S 1950.68W 6969.46S 2080.29W 6997.05S 2087.68W 7016.61S 2092.92W 7051.54S 2102.28W 7065.41S 2105.94W 7079.29S 2109.61W 7114.66S 2118.95W 7268.38S 2156.32W 7324.55S 2170.32W 7683.52S 2259.16W 7683.52S 2259.16W 7692.25S 2261.29W 7727.29S 2269.82W 7737.73S 2272.34W 7784.28S 2283.61W ) 7834.85S 2295.84W . 7864.55S 2303.02W 1) FROM LINEAR EXTRAPOLATION BELOW DEEPEST STATION. 2) OOMPUTER PROORAM - SPERRY SUN THREE DIMENSIONAL RADIUS OF CURVATURE. DATA CALCULATION AND INTERPOLATION BY RADIUS OF CURVATURE COMPUTATION DATE dANUARY ~ ~, 1985 DATE OF SURVEY DECEMBER 28, 1984 JOB NUMBER AK-BO400~8/LB40100 KELLY BUSHING ELEV. = 58.00 FT. O. CO 2CCC. CC ~CGC. CO .CCOO. CO~ 9t74. it~ 5CqLE ' 'NC~ -C 2:,:C. :2 . _.21 : _ . qK-5C4C,:5~/' :4C'C: VEqTiCRL SF. CT:2N :$ 9194.~2 q['ZWO qz. 4.48 200O. CC 4CCC. CC 5CCC. CC 8COO. CC OCCO. C: 5cq!.E :- 'Neb -0 2C3-.CC / 2OCS.~ q~-EC40098/L~40'20 I I -2000. CC ,C--2ooo. co I L-4000. CO ~13032 --6000.00 u-8000. CO 50RrZONTqL P°OjFCTiCN: ~ _ Suggested~form to be insertcd in each "Active" well folder to , ~for timely ccmpliance with · Reports and Materials to be received by: ;/-- ~ Date Reguired Date Received Remarks .. , · · · Registered S~ey Plat ~, , , · , , , , , , ~ , , , .J ARCO Alaska, Inc. Post Office b_x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 5, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive .~ Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - Revised DS 11 (Wells 8-13, A, B, C) Dear Elaine, Enclosed is a revised as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer J G/tw GRU4/L125 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RE. NUMSER CONDUCTORS 8 &t2 AS t2 & ~ RESPF. CTIVELY PER ARCO DRILLING, ANCHORAGE. -. --~-..~ LEGEND ,,/,, NOTES 81 ASSOCIATES, ~ % A~ CO0.~N~TES SHOW" 13~ ZONE 4, /// 1t-9 y~5,952,869.2 2 X~ 707,141.49 11'10 Y'$,952,752.49 Xt 707,170.07 Y: 5,952,6 56 · X~ 707, 197 t- ,/~ 11'8 -- X= 707,225.76 ~-~ !1't3 y' $,952,402.50 ~'~ X= 707,253.79 II-A Y-'5,952,169,22 X- II'B Y= 5~9 52,05 2.86 X: 707,338.11 II'C Y' 5,9 51,9;56,30 X: 707,566,04 WITHIN PROTRACTED SEC'S. 28 & $3,TWP. lIN., RGE.15 E., UMIAT MERIDIAN. NOTE' NO NUMERICAL DESIGNATIONS HAVE BEEN ASSIGNED TO WELLS A,B ~C I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS-BUILT SURVEY " MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER DETAILS AT THIS TIME 8'( ARCO DRILLINB. ARE CORRECT, AS OF:OCT. 9~I984. DES, J,B. CHK. j, B, DS.II VI ClNITY MAP NO ~C&L£ LAT. t?OOi6'?..8.SZ24' 1155' F. SL. LONG.: 148eig'27.$BO'' $77' F.E.L. LAT--70o16'~.7,6669" 1038' F.S.L. LONG,,I4BO19'26.642'' 552' F.E.L LAT.= 70° 16'26. 5155" LONer;148© I9'Z §.92:7" LAT.,70~16' ?. $.$$74" LONG.= 148°19' ?.5.205" LAT.= ~ 16'24. Z 0;53" LONG.= 148° 19' ?.4,486" LAT,: 70°16'Z 1.8 944" LONG." 148°19, 25.0?.7" LAT. c 70°16' ?.0,742 g" LO NG.' 148°19' ~. 2. :512" 921' ES, L, ~5Z8' F E,L,~ ~6' F. $,L.i 279~ F. EL.i 461' ES, L. ~29' E E,L.: 334' ESL LAT.,70°I 6' 19, 5893" P. 17' FSJ.. LONG,* I48019' 21. 59 3" I80'FE.L. LAT.~ 70°16~1 ?.~784'' 18' F.N.L. LONG.=I48019'20.1 $9'' 13i' F.E.L- LAT.= 70o16' 16. I P. 42" I;~6' FN.L. LONG., 148Ol9'19,450? 107' F.E.L. '. eec.eeC' ~ O.$.II-COND. 8-1$,IS, A,B,C AS-BUI ARCO Alaska. Inc. OF ARCO Alaska, Inc. Post Office r''r "00360 Anchorage,. ~=t<a 99510 Telephone 907 276 1215 Date: February 4, 1985 Reference: ARCO OH Finals 11-12 Gamma Ray in Casing Run 1 5" Sch I1-12 DIL Run 1 2"&5" Sch 11'12 BHCS Run 1 2"&5" Sch 11-12 Collar Log Run 1 ~&5" Sch · Please sign and return the attached copy as receipt of data/ Received by Pam lambert ATO 1429C Trans #019 Chevron D & M Exploration Services Extension Exploration Texaco Marathon Mobil. MmbiL_ E & p Phillips Prudhoe Bay Well Files R & D Sohio State Of. Alaska ARCO Alaska, Inc. is a Subsidiary ©! AtlanticRichfleldCompany ARCO ALas'ka, Inc, F:'..O. Box '1(~3;6-0 Anchor'age, ALa.'.¢ka DATE' Jan~a'r'y 'I '~: '1°° .... : ! / ~.3 ~.-' Rli-[F:'ERENCE' ARCO Magne'~ic ...... R~ I''~ .... ON i] .L S T R .~ .... ,_., z (only :.,,,, C h e v 'r o n i'.i o I':, i L i) & H Hob i I. E & I::' E x I::' L o'r a ,i: i o n ;}? e'r' v i c e s' P h i L L i p s' Ex'tens'ion Exp Lo~-a't.'ion F:"r'ucll"~oe Ba'y I,,](.-..-, I. I. [il x x o n 6: ,:!-,. Get ~,: y $oh Jo F~a'r'a'l:hc, n ,~' ~' a ~' e of F:' i I.e.'..i: ( Ni'} An.-.:.':we'r' ) ARCO Alaska, Inc. Post Otfice Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 14, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports - December, 1984 Dear Mr. Chatterton' Enclosed are the December monthly reports for the following wells' DS 6-11 (Workover) 2C-15 1Q-12 DS 11-12 2C-16 2W-9 DS 11-15 2D-13 2W-10 DS 15-16 (Workover) 2E-10 2W-11 DS 15-17 (Workover) 2E-11 2W-12 DS 17-13 2E-12 CPF-1A DS 17-14 2E-13 WSP-3 2X-9 2X-10 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L68 Enclosures RF.rSIVED Gas Cons. Comnd&doa Anchorage ARCO Alaska, Inc. is a Subsidiary o! AllanticRichfieldCompany '~-'. STATE OF ALASKA " ALASKA O,- AND GAS CONSERVATION CO~..ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well I-~X Workover operation [] 2. Na~p~r~t~ka' Inc. 7. Per~i/~_N~)~)5 3'Ad~re. sso. Box 100360, Anchorage, AK 99510 8'APINu0q~r-21212 50- FEL, Sec 33, T11N, R15E, UM 9. Unitor Lease Name · Prudhoe Bay Unit 4. LocationofWel1136, FNL, 107' at surface 10. Well No. 11-12 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool December 84 For the Month of. , 19__ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well (~ 0800 hrs, 11/16/84. Drld to 2550'. Ran 13-3/8" csg. Drld 12-1/4" hole to 12,035'. Ran 9-5/8" csg. Stuck csg w/FS @ 9318'. Wash & ream through 12-1/4" hole. Drld 8-1/2" hole to 13,032'TD (12/06/84). Ran OH logs. Ran 7" liner. Discovered leak in 9-5/8" csg. Repaired same· PBTD = 12,995'. Ran 5-1/2" & 3-1/2" tbg w/tail ~ 12,004', pkr (~ 11,907', & SSSV ~ 2195'. Secured well & RR ~ 2400 hrs, 12/14/84. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 20", 94.0#/ft, H-40, weld conductor set ~ 80'. Instld w/1950# Poleset. 13-3/8", 72.0#/ft, L-80, BTC csg w/FS ~ 2529'. Cmtd w/2520 sxs PF "E" + 400 sxs PF "C". 9-5/8" 47.0#/ft, L-80, BTC csg w/FS @ 9318'. Cmtd w/500 sx Class "G" cmt. 7", 29.0#/ft, L-80 AB-MOD csg f/13,032'- 9029'. Cmtd w/650 sx Class "G" cmt. 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/BHCS/SP/GR f/13,032' - 11,960' GR f/13,032' - 2529' 6. DSTdata, perforatingdata, showsofH2S, miscellaneousdata NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Alaska 0il & Gas Cons. Commission Anchoraoe NOTE--Repo on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with theAlaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Fnrm 10-404 .......... Submit in duplicate ARCO Alaska, In( Post Office ~,.. 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 4, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive AnChorage, AK 99501 SUBJECT- DS 11-12 Dear Mr. Chatterton- Enclosed is a Subsequent Sundry Report for the subject well. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU2/L120 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION G~J~v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL~I~ COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 136' FNL, 107' FEL, Sec.33, T11N, R15E, UH 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 7. Permit No. 84-1 g.~ 8. APl Number 50-- 029-__7! ?__! 2 9. Unit or Lease Name Pr,Jdhee B~¥ Unit 10. Well Number 11-12 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool 12. 58' RKB Perforate stimulate Repair Well A_nL 28328 ^LK 2323 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: Pull Tubing {Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] Perforations [] Altering Casing [] Abandon [] Stimulation [] Abandonment [] Change Plans [] Repairs Made [] Other [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The well name designation has been officially changed from DS 11-8 to DS 11-12. () C 0 j 1984. Alaska 0ii 6. bas CN~s. (_;eumissi0n Arich;; 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. q , /-'. ' . 1-. . Signed 6(.(P, t0L_/ M:~;Lu..LJ~/~.~'._~-.4~:r¢.~ T,tle Area Drilling Engineer The space ¢1o~ for Commission use ¢ .~:J.~~/~' Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 ~v 7-1 an GRU2/SN43 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION L,O'MMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 136' FNL, 107' FEL, Sec.33, T11N, R15E, UN 7. Permit No. 84-195 8. APl Number 50-- 029-21 212 9. Unit or Lease Name Pr~dhn~ R~y /In~ 10. Well Number 11-8 11. Field and Pool Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i l Pool 58' RKB J ADI_ ?R'~?R Al 14 ~23 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stim u lation [] Aba ndonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to change the well name designation for this well from DS 11-8 to DS 11-12. Subse?~e~,t Work ttenorted RECEIVED Alaska Oil &,Gas. COns. Commission ~nChorage f/~going is true and correct to the best of my knowledge. 14. I hereby certify that the The space below for Commission use Date Conditions of Approval, if any: Approved by Form 10-403 [iRI~N~L St~X£[i ~pproved Com" Returned By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate I~pv 7-1-Rtl GRU2/SNA0 and "Subsequent Reports" in Duplicate ARCO Alaska, In Post Office aox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 19, 1984 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' DS 11-8 Sundry Notice Dear Mr. Chatterton- Enclosed is our proposal to change the well number designation of DS 11-8 to DS 11-12. If you have any questions, please call Jo Ann Gruber at 263-4944. Sincerely, D T. L. Fithian Area Drilling Engineer TLF/JG/tw GRU2/LI02 Enclosure RECEIVED Nov 2 ? Alaska Oil & Gas Cons. C · omrnJssion Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany MEMORAiq'DUM State of Alaska TO: FROM: ALASKA OIL AND GAS CONSERVATION COMMISSION C.V.~~~terton DATE: November 21, 1984 Cha~. ~-'.' - FILE NO: /? ~-" D 1I 40 / Lonnie C. Smith ,' ~-' C o'[~lI.~J,, s s i o1'1 e r 0 ~ TELEPHONE NO: Ben LeNoman SUBJECT' - ' Witness Petrole~ Inspector BOPE Test on ARCO's Prudhoe Bay Unit DS 11-12, Sec. 33, TllN,Ri5E,L~{, Prudhoe Bay Unit. Friday, No>~ember. _1.6, 1984: I departed my home at 5:45 am for a 6:15 am Sho~=ap and 7 i15 '~m departure via Alaska Airlines, Flt. #55 for Deadhorse arriving at 9:45 am. Weather: 14°F , - , clear blowing S~OW. BOPE tests on ARCO's Kuparuk 2X-!2 were completed, the subject of a separate report. p~tu_r, day_,.. November 17~,. 1984: Standing by on DS 11-12. Sundal, November 18, 1984: BOPE test on ARCO's DS 11-12 began at Mondaz~_November 19, 1984: . . . and were completed at 12:30 am. ~ inspe-~~n repow~-'~'is attached. Tuesday, November 20, 1984: BOPE tests on ARCO's Kuparuk 2W-8 were -c~mpiet~d';'' t~h~ ~ub']eet o~ a separate report. I departed Deadhorse at 5:40 pm via Alaska Airlimes, Flt. #56, arriving in A~-_chorage at 7:20 pm and at my home at 7:50 pm. In summary, I witnessed successful BOPE test on ARCO's DS 11-12 Atttachment 02-00IA(Rev. 10/79) o&c tt~ 5184 Operator /~_ ~.~ Well D ~ 77- /~ STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Location: Sec ~ TIff~R/~'M CfM ' Drillin8 Contractor~,~f,~ Representative Permit f! /~6'asing Set @ ~'~q ft. -. Rig ~//7~ Representative CO. Location, General ~/< Well SignzQ~ General Housekeeping_~_~_Rig Reserve Pit Mud SYstems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H. C.R. Valve Kill Line Valves Check Valve Test Pressure Test Results: Failures ACCUMULATOR SYSTEM Full Charge Pressure ' Pressure After Closure Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: Controls: Master ~/~ Remote ~)/~ Blinds switch cover ~- Kelly and Floor Safety Valves Upper Kell~ Test Pressure Lower Kelly Ball Type Inside BOP Choke Manifold No. Valves psig ~.. ~' 0 ~ psig 1~0 0 min .~ sec. ~ min ~ ~- sec. psig Test Pressure Test Pressure ~ Test Pressure Test Pressure No. flanges Adjustable Chokes ~ Hydrauically operated choke Test Time / ~//~hrs. Repair or Replacement of failed equipment to be made within days and Inspector/ CommiSsion office notified. Remarks: ~'~-?~ ~~~ Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector October 29, 1984 Mr. T..L. Fithian Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-036 Re: Prudhoe Bay Unit DS 11-8 ARCO Alaska, !nc. Permit No. 84-195 Sur. Loc. 136'F~IL, 107'FEL, Sec. 33, TllN, R15E, UM. Btmhole Loc. 2795'FNL, 2661'FEL, Sec. 4, T10N, R15E, UM. Dear Mr. Fithian: Enclosed is the approved application for permit to drill, the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Sables of well cuttings and a mud log are not required. A continuous directional survey ts required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter suz-veys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. PollUtion 'of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Cont.ol Act, as amended. Prior to commencing operations'you may be contacted by a representative of the Department of Environmental Conservation] ~ To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Mr. T. L. Fi thian Prudhoe Bay-Unit DS 11-8 -2- ~ctober 29, ~.984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. %~nere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the'event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, ~. .... -,...i~ . ~.-- / / C. V. ~natterton Alaska Oil and Gas Conservation BY ORDER OF THE COMMISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office Bo,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 25, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 11-8 Dear Mr. Chatterton' Enclosed is our application for Permit to Drill DS 11-8 and the required $100 filing fee. Attachments to the application include plats detailing the section and plan views of the proposed wellbore; proximity plats showing the subject wellbore's position to the nearest wells drilled; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Since we anticipate spudding this well on November 5, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4610. Sincerely, T. L. Fithian Area Drilling Engineer TLF/JG/tw GRU2/L37 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Alaska Oil & Gas Cons. Commission STATE OF ALASKA ~'"' ALASKA Iu,L AND GAS CONSERVATION CO~MISSION I:RMIT TO DRILL 2O AAC 25.0O5 la. Type of work. DRILL [~]X REDRILL [] DEEPEN [] lb. Type of well 2. Name of operator ARCO Alaska, Inc. EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC L.~ SINGLE ZONE ~ MU LTl P L E ZONE i--I'~1~, ¢~ 9. Unit or lease name %~¢;}¢ % ~ ' Prudhoe Bay Unit ~;~ ~ ~ 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 136' FNL, 107' FEL, Sec.33, T11N, R15E, UH At top of proposed producing interval 2540' FNL, 2580' FEL, Sec.4, T10N, R15E, UM (~ Target) Attotaldepth2795, FNL, 2661' UM FEL, Sec.4, T10N, R15E, 5. Elevation in feet (indicate KB, DF etc.) / 6. Lea~J~l~j~l~t~6n and serial no. RKB 58' ~ ADL ~laJ'2~' ALK~'~"'"' 2323 10. Well number 11-8 11. Field and pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool 12. Bond information (see 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 6-1/2 mi. N of Deadhorse 11-7 well 60' @ 2195'TVD feet 16. Proposed depth (MD & TVD) 13035'MD, 9114' TVD 19. If deviated (see 20 AAC 25.050) ~112 KICK OFF POINT 1500 feet. 4020 14. Distance to nearest property or lease line miles 2740' FSL @ Target feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 52 o (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program 18. Approximate spud date 11/05/84 psig@ -- Surface psig@ 911/~ ft. TD (TVD) SIZE Hole I Casing 30" _20" !17-1/2" 13-3/8" i12-1/4" 9-5/8" 8-1/2" . 7" Weight 94.0# 72.0# 47. O# Arct 29.0# 22. Describe proposed program: CASING AND LINER Grade Couplin_c H-40 Weld L-80 I BTC L-80 I BTC ic Pack ~r-5/8,, x iL-80 | RTC Length MD 80' 2506' 12101 ' 3-3/8" nnulus 1206' SETTING DEPTH TOP TVD 30' I 30' I 29' 29' I 28' ~ 28' I 11829' I 8374' MD BOTTOM TVD 110~ 110' 2535 '1 2500' 12129'1 8558' I 13035'11 9114' QUANTITY OF CEMENT (include stage data) 2000# Poleset 2300sxPerm. E+400sx Perm C 580 sx Class G & 300 sx Permafrost C 410 sx Class G ARCO Alaska, Inc., proposes to directionally drill this well to 13,035'MD (9114'TVD) to produce from the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8", 5000#, RSRRA BOP stack will be installed and tested. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17#, L-80 tubing and packer will be run. The packer will be set above the Sadlerochit. The well will be perforated with tubing conveyed casing guns with the rig on location. A sundry notice will be submitted detailing the exact perforation intervals when selected. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A surface diverter will be installed and operationally tested prior to spud. DS 11-7 will be 12~0' from DS 11-8 at the surface. DS 11-3 is 9~22' from DS 11-8 at 4140'TVD. DS 1~ is 186' from DS 1~-8 at 2661'TVD. DS 11-..__6 is 12--8' from DS 11-8 at 2456'TVD. DS 11-7 is 60' from DS 11-8 at 2195'TVD. There are no other wellbores closer than 200' anywhere along the proposed well-~ourse. (see attached sheet). 23. I hereby certify that the ~lregoing is true The space below for Commission use and correct to the best of my knowledge TITLE Area Drilling Engineer DATE CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required APl number []YES [~-NO []YES ~O J~YES SEE COVER LETTER FOR OTHER REQUIREMENTS Permit number APPROVED BY tj/~~ Form 10-401 G~~PDIF O--,, -'; I on Approval date ,COMMISSIONER DATE October 29, 1984 by order of the Commission Submit in triplicate PERMIT TO DRILL DS 11-8 Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus of this well. The 9-5/8" x 13-3/8" annulus will be left with a non-freezing fluid during any interruption in the disposal process (i.e., rig move or shutdown of disposal for an extended period of time). lO00 2000 3000 4000 5000 6000 7000 8000 9000 lO000 ilO00 D811-8 0 tO00 2000 3000 4000 5000 6000 7000 8000 9000 KOP ~VD -- 1600 AL SKA, 7.$ 22.5 ' 27.~3-:U8' CSG TV) = 2500 MC ' 25as OEF ' 2aO ~- 136' ~ ~ 107' ~ of :__.IEOC ~;) ' 3308 M( -- 3684 DEF ' 884 +'% 807~ F~(TO TAReET) 52 DGG6 MIN ~ K-lO TVD=7208 MI =9932 DEl =5893 K-5 ~D-- 7873 MD- 11014 DEP ' ~ LC:U TVD ~ 84~8 MD -- 119C 1 DEP - 7441~~ SAG RlVl;R ~D 84~13 MD - 119~ '4 DEP - 75( SHUBLICK ~D -- 8488 MD -- 12( '31 DEP -- 75 t0 9-6/8' C:SG TVD -- 81i58 MD - 12 29 DEP ' 7e TOP SAD ~D-- ~568 MO-- 1: :146 DEP - 7 139 ~ ~ ~ I'ARGET ~1) - 8905 MC -- 12684 DE) -- 8072 BASE SAD ~D - 9053 MD - 12~35 DEP - 8262 ~ TVD - 9114 MD- 13036 DEP -- 8340 ........................................................................................... 1000 2000 3000 9000 5000 6000 0 ! 000 2000 3000 ~tO00 5000 6000 7000 8000 9000 VERTICAL SECTION tO000 0 7000 8000 9000 10000 11000 10000 z SCALE 1 IN. -' 1000 FT. DS11-8 - N COOROINRTF. S o -6000 -5000 -4000 -3000 -2000 -6000 ARCO ALASKA, INC. - t 000 0 l 0 OD SHL- 156' FNL ~ 107' FEL of Sec. 35, T/iN, R15E, [lq E '3 THL- 2540' FNL ~ 2580' FEL of Sec. 4, T10N, R15E, · , . Targ~t- TVD 8905 ' MD lZ694 ' ~ 8072 ' - ooo - ooo - ooo - ooo /I/aska Oil & Cas Cons. A~.r.~,.. Commission ......... SCALE 1 IN. -- 1000 FT. DSll-8 E - W COOROIN~TE~S ARCO ALASKA, INC. -6000 -5000 -4000 -3000 -;2000 - i000 0 1000 ~ 5c.£ ) 051~/37~ i 5936 I '6: 9 so4 · 88~ 511-3 -8 m OCT' ~ , , ~ , , , , , , , , , , , , , , , ,, , , , , , , , , , , , , , , ~[~ _, , , , ~ , , , , I · -6000 -5000 -4000 -3000 -2000 -1000 Oil & O~OCoR.:,. COfilmJssion ~ - W COOROINRTES ~,~.':::~-~ ...... :,~ DS11-8 -400 Z -300 -200 SCALE 1 IN. "1OO FT. - P4 COORDINATES -100 0 ARCO ALASKA, INC. 100 200 300 o \ ~ , 1{8 I ~769 578 - / / .' / 2558 2731 ~__ ' ,, I OCT ~ / , OS 11-8 -~'~' m ' ' ' ' ' ' ' ' ' ' ~ ' ' ' ' ' ' ' ' A'~ i -~00 -300 -200 - 100 0 100 ~n~'~'O' ~ 300 ~ - ~ CO0~DI~T[S W SCALE 1 IN. -- 100 FT. DSll-8 - N OOOROINF~T~S ARCO ALASKA, INC. -400 -300 -200 - 1.00 0 1.00 200 300 n,' I I I ,, · ~ ~996 ,~q45 ,, ~731 / 29~ C CT 2 6 1~84 Alaska Oil ~ ~.:ts C~.,~u-; (;on mission -~00 -300 -200 - 1 O0 0 ~ O0 200 300 - N COOROINflTES SCALE 1 IN. = 100 FT. ~~ DSll-8 E - H C00ROINRT£$ ARCO ALASKA. INC. -~00 -300 -200 - ~00 0 ~ O0 200 300 0 z i ,,i . i i i i i i i ]996 19 / / 2558 ,_.------3-~_~~'~94 30,q8/ 2973 , 3120 )9 - i i i i i i i i i - 400 -300 -200 - ! O0 0 1 O0 200 - N COOROINRTES D 300 Z DSll-8 [ - H CO0~OlNflT~5 ARCO ALAOKA. INC. o - lo0o -900 -800 -700 -600 -500 -~00 -300 I I I I I I I I I I I I I I I I I I I I I 0511-: [laska Oil & Ga, Cons. CornmWs - 1000 -900 -800 -700 -600 -500 -400 -300 E - N COOROIN~TES ~NNULiq~ .PREVENTOR PIPE R~MS BLIND P. RM$ DRILLINg SPOOL PI'PE RRM$ 11. 1£ 1~. iS. 16. 17. 18. 15-5/8" BOP STACK DIAGRAM Accumulator Capacity Tes_t_ 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the tim~ and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-5/8" BOP Stack Test 1. Fill BOP stack and .manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predetermined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and upstream valves. 4. Functionally test chokes. -5. -In each of the following tests, first hold a 250 psi low pressure test for a ~ of 3 minutes, then test at the high pressure. 6. Increase pressure to 3000 psi and hold for a mimimum of 3 minutes. Bleed pressure to zero. 7. Open ~mular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pressure to zero. 8. Close valves directly upstream of chokes and open chokes.. Increase pressure to 5000 psi and hold for at least 3 initiates. Bleed pressure to zero. 9. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to S000 psi below the bottom set of pipe rams and hold for at lemst 3 min- utes. 10, Test reamining untested manifold valves (if any) wit. h 5000 psi upstream of valve and zero pressure downstream. Bleed pressure to zero. Open bottom set of pipe. rams. Back off running joint and pull out of hole. Close blind rams and test to SO00 psi for at least 3 minutes. Bleed pressure off all equipment. Open blind rams. ~ake sure manifold and lines are full of non- freezing liquid and all valves are set in drilling position. Test standpipe valves to 5000 psi. Test Kelly cocks and inside BOP to $000 ps{ with Koom~y pump. Check operation of Degasser. Record test information on blowout preventer test form. Sign and send to Drilling Supervisor. Perform complete BOPB test once a week and func- tionally operate BOPB daily. RECEi'VE OCT'2 ]984 Anchor~e Revised 2/21/84 SURFACE HOLE DTVERTER SYSTEM SCHEMATTC ARCO ALASKA ]'NC'. lO" HYD. OPR. BALL VALVE V~LL BORE (SEE DETAIL) I0" HYD. OPR. BALL VALVE ALL 90' TURNS ARE "TEE" CUSHION _l oWELL BORE RESERVE PIT AREA NOTE · FLOWL INE DRILLING RISER F 20" 2000 PSI WP ANNULAR PREVENTOR Valves on diverter lines open automati- cally when the annular preventer is closed. 20" )ONDUCTOR PIPE "DETA[L" 2026O 10203 ARCO Alaska, Inr---.. Post Offk Jox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 22, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - DS 11 (Wells 8-13, 15, A, B, C) Dear Elaine, Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU2/L26 Enclosure ARCO Alaska, Inc. is a Subsidiary of AllanllcRIchfieldCompany ,., L_EGEND/_ NOTES. [~ EXIST. WELL 9l / ~] FUTURE WELL · IOe ~ ~CATIONS ARE eASED ON ~N'S. I I-A I~ AND FS.2-A PER H.V. LOUNSBU~Y I~ · ASSOCIATES. ALL COORDINATES SHOWN ARE I~ ZONE 4. 7 11'9 Y-- 5,952~869.22. X: 707,1~1 Il-lO Y;5,952~?§2.4.9 X-" 707~170 I1-11 X; 707, 19 ? 11-12 LAT. ·70015'~8. B224" 1155' F.~L, I t')NK,148c'Ig'27.~80" ~'77' RE,L, LA'r,;70°16'27. 66 69" 1058' E~3. L. LONG.=I48°I9'26.642' ~5P' F.E.L, LAT.-' 70° 16'26. § 15;~" LONG.'-148° Ig'25.g2-7" LA1'.=70°16' LONG.'- 148019'~'5.2.08" 921' ES.L. 528' F.E.L BO5' ES.L, $03' RE.L. 6 - X= 707,?-2 5.76 [] 11-13 Y--5~95~,402.50 LAT.-'70 16 24.2035 686 F.$.L. X-- 707,2:53.79 LONG." 148c'19' 2-4.486" 279' F.E.L. ~1-~ ¥~.57J~, 169.~2 LAT.-'70°IG'~-1.8944'' 4§1' ..0 u~ -' X"- 707,:.9 10.35 LONG.'.I48 19 Z~5.0~? 229 F.E.L. i :: 0' "' ~1-0Y.'5,95~'~052.86LAT,--70 16 ~.0.7429 5~ ES,L. X-- 707~558,1! LONG,--148oig'22.$i2" 205~F.E.I. . II-C Y--5~9 51~$6,$0 LAT.=70ei6't9.5895'' 217' ES.t., "" ' X-- 707,~66,0~ LONG.:I48 192:1.595 180 FEE I1-1§ Y-'5,951,702,80 LAT,"70 16 17,2-784 ~ F,N,L, X= 707~4~.4~ LONS.--148°t920.159 I$1 F.E,L ]~:-- ~,// '. . ,~,- ~....-,.....~_ i i HEREBY CERTIFY THAT'-I AM . W~T.~. ..OTR~CT~-O S~C'S. ~ PaOP~RLY ~E~ISTE~ED'AND I ~s8~:~:~,TWP, IIN.,R(~E.I-SE,t LICENSED TO PRACTICE LAND · UMIAT ~ERIDIAN. ' SURVEYING IN THE STATE OF ~'";'"""~' .... ALASKA AND THAT THIS PLAT ~ NOTE: NO NUh~-r-RtCAL REPRESENTS AN AS-BUILT SURVEY Og$1(;NATiONS HAVE BFEN ' MADE BY ME, AND THAT ALL i AS$1GNi~O TO 'WELLS A,B 6 {3 DIMENSIONS AND OTHER DETAILS ~,,~.,, AT THiS TIME BY ARCO O~ILLING. ARE CORRECT, ASOF:OCT. 9,1984. L.. --- . .....~ [_ .. _s_ .. . '--~:-.~'. ..... I"~ ' '" '"' "-~"~' - ~.s. ~ ~-c6~~. ,- ~i ~ ~, ~-i~,c ;CHK ..... = - ' ' : '_~,,.________. I~?~1 ~.' o.. cc,.,,,,,,, I ~-~~ I ARCO Alaska', Inc. ! I o~ -- ARCO Alaska, I,x~'' Post Offim= ~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 22, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - DS 11 (Wells 8-13, 15, A, B, C) Dear Elaine, Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU2/L26 Enclosure ARCO Alaska, Inc. is a Subsidiary oi AtlanticRichfieldCompany FROM I~Sc'~c~ -~t~ -'--- 107!E;/84 !El: !6 P, ? , ~.£.GEND /_ NOTES,. · CONDUCTOR AS- BUILT 9· D EXIST. WELL ,o._. LOCATIONS ARE BASED ON MON'S. I I-A IIt AND ES.2-A PER H.V. LOUNS~IUR¥ 1~ & ASSOCIATES. ALL COORDINATES SHOWN ARE A.$.P. I$l ZONE 4. IFil i,i · 4 r~ 1l'13 Y=§~952~402.50 ~'J X'- 707,2:53,.79 1[:3 II'A Y;5~958,169.P-P-. X= 707~310,35 Y'-5,95~-,519, IZ X= 707~I~2§.76 II'B Y= 5,9 5 2~,05 2.86 X'- 707~$$8.11 II-C Y'-5,9 51~956.$0 X-- 707,366.04 I1-1§ Y= 5,9 51~ 702 .80 X' 707~422:.42 LONG.-'I48°tg'20.139' tSJ' RE,L, t , ,, , ,,-~ ~,~,~ / V~.~o,~ ,~.~,,~ ,~ ~..L. I I I I I I ~ I II I HEREBY CERTIFY T~A~G~s ~ C- ' WITHIN PROTRACTED SEC'S. PROPERLY REGISTERE~nc~' °mmi~~t 28 ~35,TWE IIN.,RGt.15E., LICENSED TO PRACTICE LAND E* ~ 4S~~ ~, UM[AT MERIOIAN. ' SURVEYING IN THE STATE OF ~'"~* ....... ALASKA AND THAT THIS PLAT ~..~~ NOTE; NO ~UMERlCAL REPRESENTS AN AS.BUILT SURVEY ~.~ ~= OESlGNATIONS HAVE BEEN ~ MADE BY ME, AND THAT ALL f~",, ASSlGNE~ ~0 ~ELLS A,B ~ ~ DIMENSIONS AND OTHER D~AIL~ ~l~e~",,..;..,," AT THiS TIME BY ARCO DRIVING. AR~ CORRECT, AS OF;OCT. 9~I984. o,~. ~... ~~~ o.s. ~]-COND. e-]~,lS, A,e,C lAS-~'bi~' ARCO Alaska nc. ', DATE oCT. 11,]984 ' '- ' I " Suhidln~ of A~[anli~ Richfield ~omp=n~ Il-la Y-- 5,952,636.1~: X; 707,197 Il-lO Y'--5~952~7§~ ,49 X= 707,170,0T LAT,=70°I6'27. 66 69" 1058' ES.L. LONG,=I48°I9'26.642" ~52' RE.L. LAT.=70°I6'26.5153' 921' ES, L. LONG,'-148e 19'25.937" 528' F.. E,L LAT,=70°I6~ ~5,~,574'; I~0 ~,' ES.L, LONG,'-148eig'~'5.308" :505' EE.L.' L AT.= "~'0° 16'24.2 055" 686~ ES.L. LON(i." 148c'19~[4.486'' 279' F,E.L. LAT.--70°I6'21.S 944'' 451' ES.L. LONG.= 148°19~::':~,0~7'' ~:~9' EL.L. LAT.-- 70016' ~.0.7429' 3~4' F.$.L. LONG.=I48Oi9'22.$12' ~05~ EE.L, LAT.:TOe16'Ig. 5895" 217' LONG.= 148°19'21.595" 180' FE.L. LAT.'- 70Ol6'17,2:784' 18~ F.N.L. VICINITY MAP NO ~,CAI. F.. _ - . 11'9 Y--5,952~B69,22 LAT. sTOOI6'2:8.B224' 1155' ESL X= 707,141 4gl ION~=I48elg'27.3BO' ~77' KB,L, CtlECK LIST FOR NEW WELL PERMITS Company Lease & Well No. t// ITEM APPROVE DATE (1) Fee z ~ - i:~5 .,~'~! /,, ,?,,"'",~,,'? (2) Loc '"'~[ I~'~"'- ............ /~ :t"6"~ (:2 thru 8) 1· 3. 4. 5. 6. 7. 8. ^_, (%: (3) ,-,stain ~/~ / 0 -' %'"~V /'9. ('4 thru ~7~ :'"10. (10 and 12) ~ 12 ,~, (~) C.a s~ W~ /~-~?-%Y ~ ~. (13 thru 21) 14. 15. 16. 17. 18. 19. 20. 21. Is YES NO the permit fee attached ......................................... ~~ , REMARKS Is well to be located in a defined pool ............................ Is well located proper distance from property line ................. Is well located proper distance from other wells ................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is well bore plat included ............. Is operator the only affected party ..................... i ./~ Can permit be approved before ten-day wait . ' ..... .......... Does operator have a bond in force .................................. ~i. ", Is a conservation order needed ...................................... ~f/~o Is administrative approval needed ................................... Is the lease number appropriate ..................................... Is conductor string provided ............................. Is enough cement used to circulate on'~o~du~t~r a~d ~ce . . Will cement tie in surface and intermediate or production strings ...~.~'~ Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... $~ t~ AotO, . (22 thru 26) 22. 23. 24. 25. 26. (6) Add: ~[~fl ),~-~?-fd 27 .- ', ,~ . · Is a diverter system required ..................................... Are necessary diagrams of diverter ~n~ BOP equipment attached ' Does BOPE have sufficient pressure rating - Test to ,~-~2~ psig Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. O i--] i-.-I O mm Geology: Engineering: HW~_~ LCS ~ ~Ew ~ rev: ~ ,70 -. "~ :: ' ~ ' .... ,,.' .::' 6. CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. LIBRARY T.~PE CURVE SPECIFICATIONS Company ARCO. ALASKA INC. gell D.S. 11-12 RECEIVED PAGE 1 OF 2 ECC# '3205 Field PRUDHOE' BAY DEC 2) 1987 County, State NORTH SLOPE, A/.~t~)ll-.& GasCons. Com~.is~.s.~k~lke 11/19/87 DELIVERY DATE '12/15/87 ~.. Curve Name (Abbrev.) Standard Curve Name Logs Used Scale CCL LS SS FILES 1- 3 GLES G2 Casing Collar Locator Long Space Short Space G1 Gate 1 " I! GR BKL BKS MON CSS Gate 2 ,Ga .mrna Ray Backgmround Lonq S,~ace' Background Short Space Monitor Capture Short Space PDK-100 ~00-600 ~-2700 L6000-54000 ~-72000 )-12000 )-100. -3O0 -300 ISS IInelastic Short,Space " MSD Mean Std. Dev. , J" SGMA ,Sigma ! " 60-0 RATO !Ratio of CaptureCounts !" 33-3 RICS JRatio or Inelastic to CaptuJe" RIN JRatio of Inelastics I" (14-4_ RBOR Borehole Ratio " 3 to -1 Page 2 of 2 LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO Alaska, Inc. Well 0.S. 11-12 ECC#~ 3205 Field Pr~dhoe Bay -. County, State North Slope,. Alaska Curve Name (Abbrev.) Date ! 1/19/87 .DELIVERY DATE 12/15/87 Standard Curve Name Logs Used Scale FILE 4 SGAV Average Sigma" PDK- 10 0 6 0- 0 RNAV Average RIN " 14- 4 I RCA¥ Average RICS " 43- 0 RIAV Average Ratio " 3 3- 3 GR Gamma Ray Pass 1 " 0-100 ½; . -.-.' ** RE~L HE&DE~. REEL NAME : DATE : ORiGiN : FSYS SERVICE N~ME: 51TLIS REEL CONTiNU~Ti~K NUMBER: 01 PREVIOUq REEL N~N~---- : - -, r COMMENTS: ~.,~=S~:2 ~TL~S LIS CUSTCt¢-=_~,' T~~: --- R &~ ~ BY u u~ .-- ** TAP: HEa.DE~ *~ T~PE NAME : C~TE : ORiGiN : FSYS SE~VZ~'E k~'qE: :--'-.SS 1 T~PE CONTINUATT~' U" COMM:NTS: LENGTh: 1}2 ~YT~S ~,, FIL~ d.E~OER : I ** FILE N~M~: P~SS '~.001 . . ' . SERVICE .-.::-~,.. ~ VERSION ~ : 1 ~TE: ~/1! /Z:.: H~x RECORD LENGTh; 102~ aYTES FZL5 TYPE: LO ** F-'-Ma° "= C-1 68 ,:, 1 CPS G~ 68 ¢ I CPS MON 68 .4. 1 CPS ~KS 68 /- 1 C~S ISS 68 '- 4,, I CPS ,-:SS x.,~. 4 I St: RD, OR 58 4 I CiM q i C .S 5 a 4 I D I ?. GE13 S~.L RnT3 · ..o ~.'7. 68 ~ t' CpS SU ,_-,Zv =NTRY :LOC<S c I S ~-:T-~ S 7. -- C R-- -s. S _: 8 6C,O F R ~.~ E SP~CZNC- 9 lin FR~'E q~"-CTF~'' · ~ ,,. ~ UNITS 11 12 M/~XIMUM FR~ME-/RECO~D C T: R~ "',q-& T 0 R -0·¢00 L~¥EL SP$CZNG O~TUM SPEC!FIC~,TiON BLOCKS CUqVE N.$ME SPD SS .-_-1.3. :-. % S.S ?"-~ : U t",~.,.'rTS F/"N LS x S£ C~ C*L 0.CC9 SzC I-,'-. $~c :-_-1 MO"~ 29C7.79~, 7".L a9.2C,: ISS LS '3 £ :_KS ~'-: SE' I,.,'.1 t.547 317,C17 '-'_.350 7Z.C'75 SS ,3 R SSS ~'TC 37.612 2371 CCL ~- r G1 7121.2:~ G~IS 7~737.31.3 HO~' ~ ~6 ~' c~C I3S ~3~9~=,103 3G~ !.$.~73 - . .... ::,,~.-:z.:~ .. LS CZ' MSS RICS 21ZC.577-, C c 1 "" 15.clc SS GR CSS R'STC j~75.¢!3 13.':£1 CCL x0.450 Sa~ 15.x,;m G1 7202.383 GElS ~,~96~ . 94-'0 MON ~21~.a13 ~KL 350.33~ ISS 285476 ·300 SGM~ 22.977 ,.. ,., L N' · .',, ,_ 0 $~-3 I~, ~:~3-_~ t,:, 31 ~43~.' 74 S':!S !:777~.I3- .,vN 27~3,~$3 S~l 4,23 7 ~ ._'t. '~.~S ,.. ,..~ .., ~ '- m : ' ; ~' ~- ~50R ! .577 ~iN 6. ~2-2 ~lCS ""' ~' ~O 1 ~' ~39 L~' CCL 0. ~,.,~ S1 ~916.1~ O=IS i:*,277.19C G2 MON 2993.&~'lv BKL ?~6_- ,~5&, 8KS OEPTH 12400.C00 FT 3779.$28C M rc~ 0 C~q ~mO I = -$.~m t~ G1 1Cx-'-c =~ GEl~ ---82-S7':; 7r''''' ~5~ 1,'~''' ~*h ..~ ,~01 .. CEPT,.-, 12C1~. 3552.c,:IC ~i ~TSF, TiNG F:'m-PT~ :12951 .r~-- . ~ -, = ...... ~.~U =~ x~5'.~. -210 ' ENDING D:PT~ :12017.50C ,~T 3.66_;.7410 201 7.32 ~_ 1593.483 344.5~4 O./-.,. 27 1..,:. S z. 2 !4g~_. 2 ,_-' C 5e! 4~ .074 C. S.~ 1317.25a 423.~C1 387.133 C.£~7 19.534 245~.020 3111.7~.5 ,',2C. 5~! C.276 C.CCC 4.0~4 i ~ ~ _ SS GR CSS R~TC SS -C££ p^T¢ SS C S.S R$.TC SS CSS R~TC S£ S~ CSS ~Tr SS SSS S'S ~TC 2'75 98. 13.a34 23751 11!. -I ' 1496~.25,3 1 c..;1 :- 22341 .els ~ ., 7,... ~ 2,2 1/-,. 30&. 110 31381.~42 63.179 19355.~59 11.745 72.331 7'11 .':7. ~_;_' 11 .2::1 1C 11C.1~C C.C3C ** FILE TRA!LE~ ** FILE NAMS: PASS 1.001 SERViCe NAME: VERSION # : 1 DATE: 85/1t/ MAXIMUM LENGTh: 1024 FILE TYPE: LC NEXT FILE NAM2: FILS N~M:: P~S~ 2.002 S:,~V-"'~,,., N~ME: V:P$i~'.~ ~ : I O.~TE:,.,~:/11/20., ~,!&X RECOqC L:NGT~-: !,32 ~TLE TYP:: LC ~R'-ZV IGUS FILE :YTSS INC. UNITS TYF: ~NT~Y ~II 4 1 s .11' 11 !2 NQME ~ COL 6a L S e--=. 01 6~* iSS ~F, u,. S -S ¢.;.. RSOR 6~ · ~.~,S 6.. S--_- 1 $ S 'S ¢'; · ~ R IN ,.a C' SP.,. SU TY~E =NTRY ELOCKS ENTRY CSSCRimTiGN . .~TZON =LCC.~~ CURV= LS G1 62 MON 8KS :'SS MSG RBOR RiCS 66 ,¢ 1 C~c 68 4 ! CPS 68 4 1 CPS ~.~ ~ ! CPS 68 ~ 1 C?S 6~ ~ 1 cps ~.8 ~ 1 SU 68:: ~ 1 DIM CURVE SS-,. .~:1S Gr-< -":- K L RATO C ~ C_--- ~8 68 4 1 1 1 1 1 1 1 1 1 LS $2 ;¢$2 F-SCS I .Ola ?f .'-. f 1 4.f.574 OEPT' 12cCC,'"C'' ;T ,s'T!,..:2-.,.- v LS G2 vs C sIrS~ !244.32C 3.7!8 .... SS GR CSS ~T~ ::K S ,-'-' S -_ R?SS S~ CaPTH 12795.C;3j FT =27-.gOSC M CCL 379.'-- 50 SP3 i5,222 G1 112m~,110 G~IS 1CC:,~ 22~ mc:~ "'"', N 3350 .~ ~' -:. '" ,"'., ' · -_ B<L 25'~.'-' Z~¢ =, x"t 7 ! 7 1C'C S3Ma 17 ~-~OR 1.463 ~.::,i 7.S,.,,s LS M SC ::.SCS 2m1~.,373 CSS 700 · ;}-C 4o.910 22C~'_. 63C' SEPTI, 12*r'''''' r , . . ,- CCL "21 ~ .... ::.,: ._ O.CSO .:_ .SPD__ 15.411 ' I - :.-~ ~ . m ~ , q 1 c91 ,z, 54 8dZ,915 /.m~ ~/,,I SS 2~354 102.45z RSOR I .510 ..... C:33C M 2._=,~Tm I~z, CC,CC-g =T 37 CCL 0.£?0 MCN _~419.~79 BKL -SS S 074 :~7. ;'35 SS~','-' -'' ~80R I 3~9 RiN 0EPTH 12300.000 FT 37 CrL r, C~_O 61 12666.050 G:I MON x120,545 8KL iSS 331711.300 SSM 15.375 LS _..- i ~ -_:'v ~ ._ 302.092 -.~ ~, S IC.~=I "SC' · ?, -. 7.73_° LS -, RZCS LS STaRTiNG 3=PTm :!2°S': ~Sb ENC'iNG O=~'~ =I'~ ' 5 c~'~ O. 5'~ e :3 _=662.327'3 14~4.CCl 1~. ,3!.: !5 -]3.3'12 377.6c7 S.lt? 13.3~'5 2 =6 ~ · 724 ':11 '.211 447.714 C .3Cl q'~ o~C !~.77~ ? l ':" ',:, .5.=c 2~11 .='CZ 1 ~ 2 c .997 C · '3 C C !7 . :..71 a ,.,.' -'C SS CSS ~4TC C S S SS CSS RATC SS -SSS Si CSS SS CSS 27323, I ?~..'S' 17154..:,3J I.i:, .c c 9 3 ~X?l ,'cO 25~34,71C 13.404 ,2..Z 3 ,2 122.s2C ='L~ NAM=: ;':'SS :.003 $ ~_ ;.,. V i C = V_:RSTON ~ -' C'ATE: ~5/11 MAX RECORD L~NGTi-: 1C2'4. FiL-- TY~:: LC PqFVi:3US =ILE ~: ..:- l ~-~ : O..h : ~.';- C C "-..Lc"-_.<_:.,, COUN : NC~T~. SLOPE. STAT : AL~.~ LCC : 150.00 :YT~S ENTRY BLOCKS TYPE ENTRY -C. SS0 CESCRiPTiON-- -- !M -r ~T CN :, r:rK S CURVE 7..-- s ~ "'~: S "',N! ~L E UNITS N~,ME Su~., S~ZF- CCL .x.. ~ 4 I Ci?4 LS 6S 4 1 G1 6~ ~ 1 C~S .?-.: 0 -'-,~ 68 ": I C ~'S ~K'~ ,:~ 4 I C~S ISS 5:~ 4 I CPS u.. S S 5 '~ 4 I l U CUPV SS 5715 5~ L ,CS S k.t "' "j SiZE 4 4 S~VPL£ 1 1 1 1 1 1 'I 1 F/vN C~S SU ,,. ENT-~Y ~LOC,~ S TYPE. E.NTDY., O:S"=:.'iPT?ON., 4 1 O:FTH 8 6C.C' :q~'= 9 11" FRA-'v= 1 I 1 2 M~ ×~ n TF-~Z -~u...cO0 LEVEL S g-ZC ~-E ~.S E Sm~CiNS SP~CiNG UNITS NATOR S-~CZNc CCL 68 4 1 LS .~ ~ I C~ Gl ~ ~ I 62 6~ '-. I C --" S ,v :3 :-, c ~ ' I C ? $ ~ 5 .J ~, ,~ _? .,t I _- Z '-t- Z S S 45 ; ":7v "] U -~ v -- Gpm S~ '3--:! S :- ~EPTh 1£m6!.CCC ;T 3;50.5Z1C ~4 . D~PTH 12mOO rm.n ST 39Zl ~2:~C M 499.95C 71~.~:~ ~C.432 1147.93d 1154.75~ 224.2?2 SS G~ CSS Si GR CSS 1325~..670 49.75~ 1131~.~0C 27.174 ~1~39.120 I~.~$1 le.~4~ R,2TC !7.:47 3EPTh 127C0.Cu5 ,=T 3-,~7E.,s~-_3C v, ~3/.'': .~F_I CSS CCL 1~.~0 SPO ,51 575'9 '~'~? '""= -.- · ,M 0 r.i 3321 .cZq r-KL 4£7.Z5~ ISS 3 o2'72 ~..-_' $-9 S g .,'; A 31 .1:~0 RBCR ! .551 RiN 8.2=1 : DEPTH 1250 CCL 135.470. S~O ~, .c.~.: LS G1 NON 32~6.1~5- ~KL ~d.d~) 5K.S ISS RBOR .1 .537 RIN- 8.302 RICS LS C, ? NS._', ~.iCS leF_l 78~... 4/.,. 4 514.7C7 C..'- ~ ~, 1E.9Sd 19.89C SS G: CSS SS ~SS R~TC ?,C~!93. 543 113.595 1~.2~3 .Z.I.~ 32.71C 73.93C 13~27.15j 23.$71 LS 5KS LS r'- ~ G2 BKS .-~ DEPTM 1Zl13.500 FT 3692.20ZC M IIi LS G2 bKS MSB talCS STA2TZNG .~~T~- :!~9~I.2C5 =T x_ i-.~5 I N G O_;PTd =12ii5.53C FT zEg?._, _~CZ3 ". *'~ :iL--_ TR"-.!LE~ ** SERVICE N '~ '"~ E: VERSION ~ : ~ 3~TE: ~5/1q/ M -A x i F,b:q L---kGT~: 1274 FiLE TYPE: LC ~EXT FiLE NA.~:-: FiLE N~NE: S q .9~4-~ ~AT=: MnX RECO~C L~NGTr': iO2~ 2YTES ~ILE TYPE: LC PREVIOUS FiL: N~ME: . ** INFOR~AT!CN ~ECOm-S ** MNEM ON W N FN COON ST~T CONTENTS : ~RCC : '~.S. 11-!Z : NORTH SLOP-_-- : ~L~SK~ iNC. UNITS ~1.~7~ 41~,SCZ C.22~ I~.CC9 191 5.75: ?Ga.=. -974 ~96 774 C ."~e 15.171 249.975 3CC 1 .39Z 12.7~3 G ~ CSS e~TC SS GR CSS SS G~. CSS R~TC 7,3.142 !"C~i,.:2~ 92.795 175t~.040 1~.007 3179 12g.13c 1 9.'79 1£.723 9 C '-"- T U :-' CC~ L$ 51 G2 MON BKS iSS mSS ~S I i il Ii ii z~ 4 I CPS 68 4 1 CPS 68 4 1 CPS N~ & I CPS 68 ~ 1 CPS $-~ ~ I SU 68 ~ I CZM 68 4 I UNITS F/MN CP~ CPS SU Z' ! '"'. 10 ENTRY ~1 ~,~ TYPE EqTRY Z~SC~iPTiON ~ I 3EPTM~.,.~ F.;E"~E~.S_:,.~ $ 6C.9 $$AME SD~CiNC- ~ ,lIN ~R~..':= SsAC!NG UNITS 11 12 .~aX"~'~U'~'~_, . F~MES/~EC~RC 0 -0.50C' L-=VEL CURVE DEDR ~ ___ j~,.~PLz ' r'~ T~ CmL~ A~.. 4 1 Clix L$ 68 4. 1 ~¢=~ 51 68 4 I 6~2 G2 68 4 1 C~S MON 68 4 1 CmS 5KS 6~ 4 1 lS¢~ 6~ .~- 1 C~S MSD 68 a 1 SU RBOR 58 4 1 SiM RiCS 68 4 I DEPTH 12~5~.C00 FT ~949.606C M SS GEIS G~ 5KL rSS S g M" CCr-= 1 1 1 1 1 1 1 1 1 UNIT% ~ / ;'.~ N C~S CmS Sd G1 O.CCO ,jEIc.~ -'5'q'~??~+_, _ .5CS i$3 C. ':: '20 SG r'4'~ -2.132 R:OR 1.CCC RIN O.CCO F. 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',~ 40.115 4¢.940 114.119 C.~C3 1~.99~ 2.c...cC7 7 .c~f ~ ~..~7 RATC 1.237 SS 5C.3c4 GR 75.701 CSS 46.C:4 RSTC 1.261 S f c..~ .; 1 - ' I '-f · ~ 'i.~ CSS ~;TC 4,~C2 12 ** ¢!LE TR~ZLER ¢iLE NAME: G R .004 SERVIC: N~''=~''~: VERSICN~ ~ : I D&T~: 05/11/ ~XiMUM LENGTh: 132~ FILE TYP~: LC NEXT F!Lf NA~E: · *~ T~PE TRAILER ** T~PE NAME: SERVICE NAME: G R BATE: ORIGIN 0~ DATA: ~SYS TAPE CONTINU~TIO~ # NEXT TAPE N~E: COMMENTS: : 01 REr- DER DAT ORI REE NEX COM Rr_-E . .,.:?'.--.. ~:] / T A p ~IL FOR : OAT TAB FIL T~P TOT REEL TRAILER ** L NAME: VICE NAME: 8ITLIS E . GIN OF D~T~: FSYS L CONTInUaTION N : 01 T REEL NA~E: MENTS: DRESSE~ ATLAS L HEADER - 1 E HEADER - 1 E HEADER - 4 ORMATION - MAT - A- - 616 LE DUMP - 4 E TRAILER - E TRAILER - 1 L TRAILER - I AL RECORDS: 644 LiS CUSTOMER TAPE --- CREATED BY SDS PROGRAM R 2.0 COMPANY NAME : ARC[] ALASKA, INC. WELb NAME : D.S.# ~1-1~ FIELD NA~E I PRt.JDHOE BAY BOROUGH : NORTH SLOPB] STATE : ALASKA API NUMBER : 50-o29-21~12-00 REFERENCE NJ) : 73~88 LIS Ta~e Verification Listing Schlumberger Alaska Computing Center 18-jUL-1989 22~52 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 89/07118 ORIGIN ! FbIC REEl., NAME : 73388 CONTINUATION # PREVIOUS REEL C~M~ENT : ARCO ALASKA, INC.,PRUDHOE BAY,D.S.# 11-12,50-029-21212 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 89/07/18 O~I~IN : FLIC TAPE NAME : 73388 C~NTIMUATIOM # PREVIOUS TAPE COMMENT : ARCO ALASKA, INC.,PRUDHUE BAY,D.S.~ 11-12,50-029-21212 **** FILE HEADER **** FILE NA~E : EDIT ,001 SERVICE : FLIC VERSION : 001A02 [)ATE : 89/07/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FII,E : PAGE: ******************************************************************************* ** ** ** ** SCHLUMBERGER WELL SERVICES ** ******************************************************************************* COMPANY NAME: ARCO ALASKA, INC. WE[,L: D $.# 11 12 DHOE AY BOROUGH: NORTH SLOPE STATE: ALASKA API NU~BE~: 50-029-2~212-00 LOCATION: 136' FNL & SECTION: 33 107' FEb RANGE: 15E PERMANENT DATUN: MSL FLEVATION: 0 bOG MEASURED FROM RKB 58' ,ABOVE PERMANENT DATU~ I~IS Tame Verification Listing Schlumberger Alaska Computing Center 1B-JUL-1989 22:52 PAGE: ELEVATIONS KB: 58' DF: 57' GL: 28' DATE LOGGED: RI~N NUMBER: TD DRILLER: 01-jUL-1989 ON~ 12973' CASING 1: CASING 2: 9 5/8" 47 LB g DRILLER DEPTH OF O' TO 9118' 7" 29 LB 9 DRILLER DEPTH OF 9029' TO 11032' BIT SIZE 1: CASING BIT SIZE 2: LINER TYPE'. FLUID IN, HOLE: PRODUCED FLUIDS TIME LOGGER ON BOTTOm: 12:00 LOGGING DISTRICT: PRUD}~OE BAY bOGGING ENGINEER: M,MCBRIDE WITNESS: A, SALEH TOO[, NUMBERS: CNC DA 101 PTS A t5 ATTB 442 C~LU COMPUTING CENTE~ ~EMAR~S~ FILE EDIT,001 CONTAINS TEMPER.ATtIRE DATA LUGGED DOWN FILE EDIT,O02 CONTAINS ] PASSES CASED HOLE CML DATA AND HOD(;ES LEYMANN AVERAGED NPh.I DATE JOB STARTED: 6-JUL-89 JOB REFERENCE N~: 73388 LDP/ANA~ R, KRUwELL TABLE TYPE : CONS TUNI VALU DEFI CN ARCO A.bASKA, INC, ~ompany Name FN PRUDHOE [%AY ~ield Name API~ ~ -~9"21212'00 AP1 Serial ,Number F'[, 136 FML & 1.07' FEb Field Location SECT 33 Section TOWN 11,~ Townsh~.p RAN~ 15E Range COU'N NORTH St, OPE County ST,Ag~ AbASk, A State or Province M~T] LiSA Marion ENGI M,~CB,RIDE Engineer's Name I$ Ta~e Verification Listing chlumberqer AlasKa Computing Center 18-JUU-19B9 22:52 TUNI VALU DEFI TN A SALEH Wltnes$'s name SON 3~0269 Service Order Number PDAT ~Sb Permanent datum L~F B hog Measured From APD FT EKB FT 58, EDF FT 57, EGL FT 28 TLAB i200 Time Logger At Bottom STE~ DEGF O, TABLE TYPE ~ CURV DEFI DEPT DEPTN CHANNEL NAME T~N$ Tension PR~ PTSA FLUID DENSITY (RHO) PPRE PTSA FLUID PRESSURE PTE~ PTSA FLUID TEMPERATURE PDTE PTSA DIFFERENTIAL, FLUID TEMPERATURE Gamma Ra CCL CCL Ampl~t'ude DATA f ORNAT SPECIFICATION RECORD ** 3 7 32 4 6~ 6 8 68 0,5 9 65 FT 11 66 12 68 13 66 0 14 65 fir 66 68 16 66 IS Tape Yeriftcation Listing chlumberger AlasKa Computing Center 18-JUL-lgS9 22:52 TYPE REPR CODE YALUE 0 66 0 ** SE ID D£PT FT TENS ?M? LB PRH TMP G/C3 PPRE TMP PSI PTE~ TMP DEGF 5 269 00 00 1 350269 00 000 00 0 1 1 350269 00 000 00 0 1 350269 O0 000 O0 0 ! 350269 O0 000 O0 0 hEM COD 1 4 68 I 4 68 ! 4 68 1 4 68 PROCESS''' E (HEX) oooooo ;;o 0000000000 0000000000 O00000000O 0000000000 0000000000 0000000000 .o.oo. ooooooo PAGE: ** DATA ** DEPT, 1466,000 TENS,TMP ,,999,250 PRH,TMP -.999,250 PTE)4.TMP -999,250 PDTE,TMP '999.250 GR,T~P 999.~50 DEPT. lSO0,O00 TENG.TMP 2!0.~00 PRM.T~P ;0,003 PTE~,TMP 67,262 PDTE.TMP . O, 05 (;R,TMP 5,250 DEPT, 1600,000 TENS,T~P ~80,000 PRH,T~P ~0,002 PTE~,TMP 65.397 PDTE.T~P 0.028 GR,T~P 9,969 DKPT, 1700,000 TENS.TieR 290.000 PRH.I~P PTE~,T~P 65,421 PDTE.T~P 0,005 GR,TMP .688 DEPT, 1800,000 TENS.~ ,,TMP 300,000 PRH,T~P ~0,003 PTEM.TMP 67,313 P[.~TE,TMP -0,031 GR,T~P 5.469 DEPT, 1900 000 TE. NS,T~P 310,000 PRH,~ P -0,005 PTEM,TMP 70:410 PDTE,TMP 0,033 GR,T~P 36.719 DEPT 2000,000 TENS.,TNP 300,000 PRH,TMP -0 012 PTE. , ,T~P 92,413 PDTE,T~P 0.054 GR.TMP 26'047 DEPT. 2100,000 TENS,TMP 310,000 PRH.TMP ~0,013 PTE~,TMP 84,648 PDTE,T~P 0,013 GR,TMP 5. 125 oo.ooo PTE}~.TMP 9.1,107 PDTE,TMP ,014 G ,'TMP ~ , 18 DEPT 2300,000 TENS,T~P 315,000 PRH,T~P -0,020 PTE~..TMP 96,665 PDTE.T~P 0,017 GR.TMP 23,344 PPRE.TMP CCL, T~qP CCh, T~P PPRE T~P CCL~TMP PPRE, TMF CCL. TMP PPRE,TMP CCL. T~ P PPRE, T CCL.TMP PPRE,TMP CCL.T~P PPRE,T~F CCL,Tk{P PcP. RE, CL.T~P PPRE, CCL, T~P -999.250 0,000 0.000 '2385 o -2385 o:gg , ,98 ,00 -2385,98~ 0.00 '2385,983 0,000 -2385.983 0.000 S Ta~e verification Listing hiumberger AlasKa Computino Center 18-jUl,-1989 22:52 DEPT. 2400.000 TENS.T~P PTE.~.T~P 97,705 PDTE,TMP DEPT 2500 000 TENS,TMP P?E" :TMP 97: 512 PDTE,TMP DF:PT, 2600,000 TENS,TMP PTEM,TMP 97,694 PDTE,T.MP DF. PT 2700,000 TENS TMP PTEW:TMP 100,052 PDTE:T~P DEPT. .~800 000 TENS T~P PTE~,TMP 100:750 PDTE:T~.P D~PT 3000,000 TENS,TMP P'..EH,TMP 102,204 PDTE,TMP DEPT 3100,000 TENS TMP P.'5,~ TMP -999,250 PDTE:T~P DF....PT, .3200,000 TENS,~P PTE~,T~P -999,250 PDTE, ~P DE~, 3300.000 PT ,TMP -999.250 PDTE, DEPT. .]400,000 TENS,TMP PTE".TMP 999,250 PDTE.T~P DEP~[, 50 ,000 TE PTE~,TMP 99 .250 PDTE.T~P Dg'PT, ~600,000 TENS T~P PTE~~, TM[: 999,250 DTE.T~P DFPT, 700,000 T S,TMP PTEM,TMP 999,250 PDTE.T~P DEPT, ]BO0,O00 TENS.T~P PTE~.T~P '999,250 PDTE, T.~P DF..PT .3900,000 TENS, ~I P PTE~;T~P 999,250 PDTE.T~P D~PT, 4000,000 TENS.TM PTE~,TMP -999.~50 PDTE.. P 300,000 PRH,~NP '0,004 GR, ~P 290,000 PRH,TMP 0,004 GR,TMP 295,000 PRH T~P 0,013 GR:TMP 290,000 PRM,TMP -0,036 GR,TMP ]00,000 PRM,T~P 0,003 GR,TMP 3~0,000 PRH,TMP .0,001 GR.T~P 310,000 PRH,T~P 0,014 GR,T~P -999 ~50 PRH.TMP -999: 50 GR.TMP -999,250 PRM,TMP -999,250 GR,TMP '999,~50 PRH,TMP -999. 50 GR.T~P -999.~50 PRH,T~P '999.250 GR.T~P -999,~0 PRH,TMP -999, 0 GR,T~P '999 ~50 PRH.TMP -999:50 GR,T~P -999,250 PRH,TMP -999.~50 GR.TMP -999,~50 PRH.TMP -999,250 GR.TMP -999,~50 PRH,T~P -g99,~50 GR,TMP "999,250 PRH,TMP '999.250 GR.T~P ~0 020 8:219 -0,020 29,844 -0,020 40,563 '0,022 46,031 '0,022 43,969 '0,022 48,906 -0 023 60:531 :999,250 999.250 999,250 :999,~50 -999, 0 '99~,250 '99 ,250 '999,~50 -999. 50 '990,~50 -999..50 2999 250 999~50 '999,250 '999.250 -999.2.50 '999.250 '999.250 '999.250 PPRE,T~P CCL,TMP PPRE,TMP CCI,.T~P PPRE,TMP CCL.TMF PPRE.T~P CCL.T~P PPR~.T~P CCL.T~P PPRE.TMP CCL.T~P PPRE,T~P CCL,T~P PPRE,TMP CCL,T~P PPRE,TMP CCL,TMP PPRE,T~P CC£,.T~P PPRE.TMP CCL.R~P PPRE,TMP CCL.T~P PPRE.TMP CCL.TMP. PPRE.T~P CCL.T~P PPRE.TMP CCL.TMP PPRE TMP' PPRE.T~P CCh. T~P -2385.983 0.000 '2385,983 0.000 '~385.983 0,000 -2385.983 0,000 -2385,983 -0,258 -2385 983 0:000 -2385 983 0:000 :999.250 999.250 :~99,250 99,250 :999,~50 999. 50 '999,250 '999.250 -999 250 '999,250 '999,250 '999,250 '999,250 '999.250 "999 50 '999,250 '999.250 c~ Tape Verification Listing lumberger .Alaska Com~uting Center D~PT, PTE~.T~P .4100,000 TENS,T~P 999,250 PDTE,TN~P .4.200,000 'rENS,TMP 999,250 PDTE,T~P oo. ooo 4400,000 TENS,T~P '999,250 PDTE,T~P 4500,000 TF. NS,TMP '999.250 PDTE,T~P 4600.000 TEMS,TMP -999,2'50 PDTE,T~P 4700,000 TENS TMP -999,250 PDTE:TMP 800,000 TENS,T~P 999,250 PDTE,T~P 4900,000 TENS. T~p 999.250 P~.. TE,T~.P .5000,000 TEN~,T~'P 999.~50 PDT .T~P 100,000 TENS,T~'P 5~999,250 PDTE,T~P :25o 5300,000 TEN$,T~P '999,250 PDTE.T~P 5400,000 TENS,TMP '999.250 PD'TE. TNP 5500,'000 TENS,TMP '999,250 PDTE.T~P 5600,000 TENS.T~P '999.250 PDTE.TMP 5700,000 TENS,~P '999.250 PDTE, 5800,.~00 TE~S,T~P -999. 50 PDTE, T~.P DFpT, PTEP,TPP DFPT. PTE~,TBP DFPT, PTE~,TNP DEPT DEPT PTEP:TNP DEPT, PTE~,TMP DEPT, PTEM,TMP DFPT, PTEF,TMP DF. PT, PTE~, TMP DEPT, PTEP.T~P DEPT PTE~' ,T~P DEPT, PTEM,TMP DFPT PTE~..,TPP DEPT, PTEM,T~P DKPT, PTEP,TMP DEpT, PTEM,T~P DEPT. PTEM.TMP 18-JUL-1989 22:52 ~999,250 PRM TMP 999,250 GR:TMP -999,250 PRM,TMP -999,250 GR,TMP ~999,250 PRH.TMP 999,~50 GR,TMP '999,250 PRH,TMP -999.250 GR.TMP :999,250 PRH,T~P 999,250 GR,TMP '999.250 PRH,TMP '999'250 GR'T~P -999,250 ~999,250 GR, ~P '999,~50 PRH,T~P '999, 50 GR.TMP '999,250 PRH,T~P '999.250 GR.T~P -999,~50 PRH,TMP '999. 50 GR.TMP '999,250 PRH TMP '999.250 G'R:T~P '99~,2~0 PRH,TMP -99 .250 GR.TNP -999,250 PRH.T~P -999.250 GR.T~P -999 ~0 PRH,T~P -99 : o -999.250 PRH,T~P -999,250 GR.TMP -9~,250 PRH,T~P -9 ,250 GR,TMP '999,.250 PRH TMP -999,250 GR~T~P -999 25O -999:250 -999.250 -999,250 -999 250 =999:250 99~,250 -999 250 -999~250 -999 250 -999~250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999 250 -999:250 -999,250 -999.~50 -999.250 -999,250 -999,.250 -999.250 -999 ~50 -999:~50 -999,250 -999.250 -999,~50 -999.250 :999,250 999.250 ':,999,250 999.250 PAGE: PPRE.TMP CCL,T~P PPRE,TMP CCL.TkP PPRE.T~{P CCL.T~P PPRE.TMP CCL,TMP PPRE.TMP CCL.TMP PPRE.T~P CCL.T~P PPRE,TMP CCL.T~P PPRE,TMP CCL,T~P PPRE,TMP CCL.T~P PPRE.TMP CCD.T~P PPRE,T~P CCL.T~P PPRE.TMP CCL · TMP PPRE,TMP CCL. TMP PPRE,T~P CCL.TMP PPRE,TMP CCL,TMP PPRE,T~P CCL.T~P PPRE,TMP CCb.T~P PRE,TMP PCCL.T~P -999.250 -999.250 -999.250 -999.250 :999,250 999.250 '999,250 '999,250 ~999,250 '999,250 '999,250 '999,250 99,250 '999.250 "999,250 '999,250 ~999.250 '999.250 '999,250 '999,250 '999.250 '999,250 '999.250 '999,250 '999.2~0 '999,250 -999,250 -999,250 '999.~50 -999,250 -999.250 ~999,2.50 999.250 -999 250 -999:2.50 ~C~ Tame Verification Llstinq .lumberger AlasKa Computing Center DFPT, 5900,000 TENS.TMP PTEM.TMP 133,844 PDTE.TMP DEPT, 6000,000 TENS TMP PTE~,TMP 136.382 PDTE~T~P DEPT, 6100.000 TENS,T~P PTE~',TMP 129.346 PDTE,T~P DEPT. 6200.000 TENS,T~P PTE~.TMP 130,489 PDTE,T~P DEPT, 6300,000 TENS.T~P PTE~,TNP 134,798 PDTE,TNP DFPT, 6400,000 TENS,TMP PTE~,T~P 136,695 PDTE.TMP DEPT, 6500.000 TENS,T~P PTEM,TMP 1~8,018 PDTE,TMP DEPT, 6600,000 TENS T~P PT~,TMP 137.769 PDTE:T~P D£PT. 6700,000 TENS,T~P PTE~,T~P i]9,059 PDTE,TMP DEPT, 6800,000 TENS,T~P PTE~,T~P I39.594 PDTE.T~P DEPT, 6900,000 TENS,TMP PTE~.TMP 140,617 PDTE,T~P DEPT, 7000,000 TENS,T~P PTE~.TMP 140.811 PDTE,T~P DEPT, 7100,~00 TENS,TMP PT.E~.,T~P i42, 42 DDTE,T~P EPT, 7200,000 TEN$,T~!P T'E~.T~P 143,059 PDTE,TMP DE'PT 7300,000 TENS TMP PTE ,TMP 143,92o [I)TE,T~P DEPT, 7400,000 TEN$,TMP PTE~,T~P 144,528 PDTE.T~P DEPT. 7500.000 TENS,TffP PTE~,TMP 144.032 PDTE,T~P 18-J'UL-1989 22:52 345.000 PRH.TMP -0.041 0.016 GR.T~P 163.625 405,ooo PRH ~MP -0.042 0,008 GR:TMP 56.250 415.000 PRH,T~P -0.038 -0.007 GR,TMP 31,969 410,000 PRH.TMP -0.039 0,029 GR.TMP 3~,938 345,000 PRM,T~P -0.041 0,026 GR,T~P 40,375 415 000 PRH,T~P 0 042 420,000 PRH,T~P 0,043 0~000 GR,TMP ~3.594 355,000 PRH,T~P 0 043 "0,006 GR,TMP ,,125 415,000 PRH,TMP -0 044 0,002 GR,T~P 31' ,~50 360,000 PRH,TMP '0 ~44 0,017 GR,T~P 48:~ 50 36~ 000 PRH,TNP '0,044 ~020 GR,TMP 33.406 4~,000 P~H,T~P '0,045 ,005 GR,T~P 31,344 43~]U00 PR~,T~P -0.046 ' 08 GR,T~P 31.156 43.0.000 PR~.T~P -0..046 0.000 GR,T~P 42,.844 42~,000 PRH,T~P -0 046 .005 GR.T~P 32:156 '0,001 GR,TNP .063 PAGE: PPRE.TMP CCL.T~P PPRE,TMP CCD.TMP PPRE.T~P CCL.T~P PPRE.TMP CCL,T~P PPRE,TMP CCL.T~P PPRE.TMP CCL.T~P PPRE T~P CCL:TMP PPRE,TMP CCL.TMP PPRE.TMP CCL,T~4P PPRE TMP CCL:TMP PPRE.TMP CCL.T~P PPRE T~P CCL~T~P PPRE,T~P CCL.T~P PPRE,TMP CCL*T~P PPRE.T~P CCL,T~P PPRE,T~P CCL.T~ PPRE,T~P CCS..T~.P -2397.521 0,000 -2397,521 0,000 -2397,521 0'000 -2397,521 0.000 -2397.521 0,000 -2397,521 0.000 -2397. 521 0:000 '2397,521 0.000 -2397,521 0,000 . O0 -2397,521 0,000 -2397,52! 0.000 -2397,521 0,000 -239~, 521 ,000 000 -239~,521 .00.0 ~2397,52! 0,000 I$ Tame Verification Listing chlumberger AlasKa Computing Center DEPT, 7600 000 TENS.TMP PTEY,TMP 144:502 PDTE,T~P DEPT, 7700,000 TENS,T~P PTEM,TMP 144,033 PDTE,TMP DFPT, 7800 000 TENS TMP PTE.,TMP 144:488 PDTE:T~P DFiPT, 7900,000 TENS,T~P PTE~,TMP 145,057 PDTE,T~P EPT, 8000,000 TENS T~P ~TE~ T.P 146,555 PDTE~T~P DFpT, 8100,000 TENS TMP PTEM,T~P 147,238 PDTE:TMP DEPT, 8200,000 TENS,T~P PTEM,TMP 147,459 PDTE,T~P T~P OEPT, 8300,000 TENS.T~P PTE~,T~P 148,443 PDTE, DEPT, 8400,000 TENS TMP PT~.T~P 149.545 PDTE:TMP DEPT,T 850~ 000 TENS,TMP PTEM, MP 14:904 PDTE,T~P DEPT, 8600,000 TEN$,T~P PTE~.T~P 150,9~3 PDTE,TMP DEPT, 8700 000 TENS,TMP PTEM,T~P 152:505 PDTE,TMP DEPT, 8800,000 TENS,T~P PT~,TMP 153,171 PDTE,T'MP DEPT, 8900,000 TENS T~P PTE.~,TMP 153,466 P[TE,TMP DEPT, 9000,000 T.ENS,TMP PTE~,TMP 153,75,4 PDTE,TMP DEPT. 9100,000 TENS,T~P PTEM,TMP 152,474 PDTE,T~P DEPT, 9200,000 TENS,TMP . T~P PTE~ TMP 153,485 PDTE, DKPT, ~300,000 TENS,T~P PTEM,TMP 999,250 PDTE,TMP 18-d~b-1989 22:52 450,000 PRH,T~P 0,000 GR,T~P 385,000 PRH,TMP -0,013 GR,T~P 440,000 PRH.TMP 0,013 GR,TgP 390,000 PRH,T~P '0,007 GR,T~P 395,063 PRH,TMP 0,000 GR,TMP 420 000 PRH TMP o:ooo 390,000 PRH,TMP 0,007 GR,TMP 380,000 PRH T~P 0,007 GR~TMP 4!9,969 PRH.TMP 0,002 GR,T~P 375,000 PRH,TMP 0,002 GR,T~P 38~ 000 PRH,TMP ~004 GR,T~P 40~,000 PRH,TMP ,004 GR,T~P 4~9,938 PRH,TMP 0,006 GR,TMP 4~5,000 PR~,T~P 0,006 G ,TMP 410,000 PRH,T~P 0,008 GR,T~P 430,000 PRH,T~P 0,008 GR,T~P 435,~63 PRH,T~P O. 06 GR,TMP '999,250 PRH,TMP -999,250 GR,TMP ~0,046 .8.078 0,046 ]0,344 0 046 -0,047 31,672 '0 047 38~221 "0,048 35,594 -0,048 27,188 -0 048 32:969 -0,049 48,096 ~0,049 7,813 0,~50 ~5. ~9 ~0,051 5,1,25 35, '0.051 25,578 '0,051 21,67~ -999 ~50 '999: 50 PPRE,TMP CCL,TMP PPRE,TMP CCL,TMP PPRE,TMP CCL,TMP PP~E.TMP CCL,TMP PPRE,TMP CCL,T~P PPRE,TMP CCL,TMP PPRE,TMP CCL,TMP PPRE,TMP CCL.TMP PPRE.TMP CCI,,TMP PPRE.TMP CCL.TMP PPRE TMP PPRE,T~P CCL,TM~ 'PPRD,TMP CCL,TMP PPRE,TM, P CCL,TMP PPR. E,'T~P CCL,T~P PPRE TMP CCL~TM'P PPR. E,TMP CCL.T~P PPRE,TMP CCL,T~P PAGE: ,-2397,521 0,000 -2397,521 0,000 '2397,521 0,000 -2397,521 0,000 -2397 52~ 0~000 -2397 521 0:000 -2397,52~ 0,00 '2397,521 O,000 -2397,521 0.000 '2397,52~ 0,000 '2391',,521 ,000 ', O, ~2~97,00~ 0 '2397,52I 0,000 "239~.52 '999,250 "999,250 LIS Tape Verification bistinQ Schlumberger Alaska ComDt]ting Center DEPT, 9400.000 TEMS.TMP PTE~.TMP -999,250 PDTE.TMP DEPT. ~500 000 TENS TMP PTE~.TMP 999:250 PDTE:TMP DFPT. 9600.000 TENS.TMP PTEM.TMP -999.250 PDTE.TMP DEPT, 9700,000 TENS,TMP PTE~.TMP -999.250 PDTE.TNP DEPT 9800,000 TENS.TMP PTE~:TNP -999,250 PDTE.TMP DEDT. 9900,000 TENS TMP PTEM.T~P -999,250 PDTE:TFP DEPT, 10000,000 TENS.T~P PTE~,TMP -999.250 PDTE,T~P DEPT, 1.~100,000 TEN$,T~P PTE~,TNP 999,250 PDTE,T~P DEPT. 1~200,000 TEN$,TMP PTE~,T~P 999,250 PDTE.TMP DEPT 1~300,000 TEN$,T~P PTE~'TMP 999,250 PDTE,T~P , , DE. PT, . 1~400,000 TENS,TMP PTEM,~M~ 999,250 PDTE,TMP D~PT, 1~500,000 TEN$,T~P PTE~,TMP 999,250 PDTE,TMP DEPT, 1060~ 000 TENS,TMP PTE~,TMP -99:250 PDTE,TMP DE~', 10700,0'00 TE'NS,T~P PT~,TMP '999,250 PDTE,TMP DEPT, 10800,~00 TEN'S,T~P PTE~,TMP "999, 50 PDTE,T~P DEPT, ~0900,000 TENS T~P PTE~,T~.P -999,2'50 PDTE:TMP DEPT, . l~O00,O00 TE $,TMP PTE~;TMP 999,~50 PDTE,TMP 18-jOL-1989 22:52 -999.250 PRH,TMP '999,250 GR,TMP ~999,250 PRH,TMP 999.250 GR.T~P -999,250 PRH,TMP -999,250 GR,T~P ~999,250 PRH,TMP · 999.250 GR,T~P -999,250 PRH.T~P -999.250 GR,TMP ~999,2b0 PRH,TMP 999,250 GR,TMP -999,~0 PRH,T~P -999, 0 GR,T~P -999,250 PRH,TMP -999.250 GR,TMP -999 250 PRH,TMP -999, 0 GR,TMP -999.250 PRH T~P -999,250 GR:TMP -999,~0 PRH,TMP '999, 0 GR,TMP 999,250 PRH,TMD ~999;250 GR,TMP "999,250 G , ~P "999,2§0 P~H,~P -999.250 GR.T~P -999,250 PRH~TMP -999,~50 GR.TMP -999.~ P~H,T~P '999. GR,TMP -999 250 -999:250 9992250 ~999.250 999.250 -999.250 -999.250 999 250 -999 25O -999:250 -999 25O -9992250 , 0 -999,250 -999,.25O -999,250 -999,250 -999 25O -999:250 -999, -999 50 ~999,250 999,250 2999 2'0 999'.~0 ~999.2S0 999.250 ~999,250 999.250 PPRE,TMP CCL,TMP PPRE TMP CCL:TMP PPRE,TMP CCL,TMP PPRE,T~P CCL,TMP PPRE.TMP CCLeT~P PPRE,TNP CCL,T~P PPRE,TMP CCL,TMP PPRE,T~P CCL.TMF PPRE,TMP CCL,TMP PPRE T~P CCL:TMP PPRE,TMP CCL,TMP PPR~,TMP CCL,T~P PPRE,TMP CCL.TMP PPRE,T~P CCL.TMP PPRE,TMP CCL,TMF PPRE,~MP CCh, ~P PPRE,T~P CCS.TMP PAGE~ -999.250 -999,250 -999.250 -999,250 99,2~0 ,999:250 -999,250 -999,250 -999~250 '"999,250 '"999,250 999,250 999,250 '999,250 '999,250 '999 250 -999:250 '999 250 '999:2~0 '999,25 '999,25~ 2999,250 999,250 ' 9 -999,~50 '999,250 999,250 999,250 -9 ,250 I$ Tape Verification Listing chlUmberger Alaska Computing Center DEPT, PTFU.T~P 11100.000 TENS.TMP -999.250 PDTE.TMP 11200.000 TENS T~P '999.250 PDTE:TMP 11300.000 TEN$,T~P 999.250 PDTE,TMP 11400.000 TENS.T~P -999.250 PDTE.TMP 11500,000 TENS,TMP -999.250 PDTE.TMP 11.,60 99~.000 TENS T~P ,250 PDTE:TMP 11700,000 TENS.T~P 999.250 PDTE.T~P t1800.000 TENS.TMP -999,250 PDTE.TMP 11900,000 TENS TMP '999.250 PDTE~TMP 12000,000 TENS,T~P 184,461. PDTE.TNP 12100,000 TENS,TMP 185.094 PDTE,TMP TMP 12200,000 TENS, 'M" 185.629 PDTE.I P 123060,000 TENS,T~P 18 .153 PDTE.TMP 12400,000 TENS.T~P 187.042 PDTE.TMP 12500,000 TENS.T~P 188,904 PDTE,TMP 12600,000 TENS,T~P 189,4~4 PDTE.T~P 12700,000 TENS.T~P 189.718 PDTE. T~P 12800.000 TENS.T~P ! 90. 172 PDTE.TMP DFPT. PTE~.TMP DEPT. PTE~.TMP D~PT. PTEM.TMP D~PT PTE~:T~P DEPT, PTE~,T~P DEPT, PTEM,TMP DFPT, PTEM.TMP DEPT, PTEM.T~P DEPT, PTEN,TMP DEP~, PTE ,TMP DEPT, PTEN TMP DEPT, PTEM.TMP DEPT, PTEM,TMP DEPT, PTEM,TMP DFPT, PTEM.TMP DEPT, PTE~,.T~P DFPT, PTE~.T~P 18-JUL-1989 22:52 '999.250 PRH,T~P '999.250 GR.TMP -999,250 PRH.T~P -999,250 GR.TMP :999.~50 PRH,TMP 999,250 GR.TMP '999 250 PRB.T~P '999:250 GR,T~P '999,250 PRH,TMP '999,250 GR,TMP ~999.~50 PRH,TNP 999,250 GR,TNP ~999,250 PRH,T~P 999.250 GR.T~P -999.250 PRH,TMP '999,250 GR.T~P '999.250 PRH,TMP '999.250 GR.TMP 540.000 PRH,~MP 0,001 GR. ~P 525 000 PRH.TMP 0:005 GR,TMP 545,~00 PRH,T~P O, 03 GR,'rMP 555,000 PRH.T~P 0.003 GR~TMP 560,000 PRH.TMP 0,006 GR.TMP 5~5,000 PRH,T~P 0.00! GR,TMP 5~0,000 PRH,TNP 0,003 GR,TMP 54~,000 PRH,TMP '000 GR.TMP 540,000 PR~,T~P 0.0~1 GR,T~P '999.250 -999.250 :999.250 999.250 :999,250 999.250 -999,250 '999,250 '999,250 -999.250 -999.250 -999,250 '999,250 '999.250 '999 ~50 '999:250 -999,250 '999.~50 9 ~67 , 88 -0,068 40,625 891 52. 5 ~0.069 4.285 -0 070 67:938 1o,o7 6,31 -0,070 234,375 PAGEI 10 PPRE TMP CCL:TMP PPRE.T~P CCL.TMP PPRE.TMP CCL.TMP PPRE.TMP CCL.TMP PPRE TMP CCL:T~P PPRE.TMP CCL.TMP PPRE.TMP CCL.TMP PPR. E,TMP CCL.TMP PPRE.TMP CCL.TMP PPRF CCS:T~P PPRE TMP' CCS.T~P PPRE TMP CC~TMP PPRE,TMP CCh,TMP PPRE,TMP CCL,TMP PPRE,TM~ CCL,TMP PP~E.TMP CCL.T~P PPRE.TM~ CCL.TMP PPRE.TMP CCL.T~P :999,250 999,250 :999,250 999.250 :999,250 999,250 -999.250 -999,250 -999,250 -999.250 '999, 0 '999 250 -999:2~0 -999,250 -999,250 :999 250 999~250 '2397,~21 O, O0 '239~ 52t 000 52 '2397,00~ O. 000 -2397,~1 O, 0 , 0 '2397,~1 O, 0 hlumberqer AlasKa CompUt nn. Center 18-jOL-1989 22:52 PAGE: 11 DF. PT, 1.2900,000 TEN$,T~P PTE~,TMP 194,172 PDTEsTMP DEpT, 12956,500 TENS,TNP PTE~,TNP 194,483 PDTE.T~P END OF DATA 565,000 PRH,TNP 0,003 GR,IMP 505,000 PRH TMP 0,000 GR:TMp -0 072 PPRE.TMP 38:938 ¢CL,TMP -0,072 PPRE,TMP 47,625 CCL,TMP -2397,521 0,000 -2397,521 0,000 **** FI[,E TRAILER FJL~ NA~E : EDIT ,001 SERVICE : FLIC VF:RSION : O01A02 DATE : 89/07/18 ~X REC SiZE : ~024 FILE TYPE : LO LAST FILE **** FILE MEADER **** F~LE MA~E : EDIT .002 SERVICE : F5IC VERSION : 00lA02 DATE : 89/07/18 MAX REC SIZE : 1024 FILE TYPE : bO LAST FILE : TABLE TYPE : CONS TUNI VAhU DEFI CN 0 A ASKA, NC Com~n~ Na~e FN PRUOftOE BAY ~te! amc WN D~BA~ i1-12 Well Name APIN 5o-,~9-21212-00 API serial Numbe'r F b & 107' ~EL Field ,Location SECT 33 sect!on TOWN llN Township RANG 15E Range COUN NORTH SLOPE County STAT ~LASK'A state or Province N.ATI USA Nation ENG! M,MCBRIDE Engineer's Name son 3§~9 ServlceOrder Number PDAT MSL Per~anent datum EPD FT 0 L~F R~B Log ~easured From APD FT 58. EKB FT 5S, LIS Tape Verification Listing SchlUmberger Alaska Computing Center 18-JUL-1989 22:52 PAGE: 12 T~BLE TYPE : CURV DEFI '''''''''''''''''''~'''''''''''''''''''''''''''''''''''''''DFP~ DEPT C~ANM L ~h~$ TENS Tension NPHI NEUTRON POROSITY RCFT RAW CORRECTED FAR THERMAL COUNTS RCNT RAW CORRECTED NEAR THERMAL COUNTS NTC CORRECTED NEAR THERMAL COUNTS FTC CORRECTED FAR THERMAL COUNTS TNRA CAbIB~ATED T~ER~AL NEUTRON RATIO RTNR RAW THERMAL NEUTRON RATIO TENS Tension NPH~ NEUTRO~ POROSITY RCFT RAW CORRECTED FAR THERMAL COUNTS RCNT RAW CORRECTED NEAR THERMAL COUNTS CNTC CORRECTED NEAR THERMAL COUNTS CFTC CORRECTED FAR THER~Ab COUNTS TNR~ CALIBRATED THERMAL NEUTRON RATIO RT~R RAW THER)~AL NEUTRON RATIO GR Gamma Ray CCL CCL Ampi{rude TENS Tension NPHI NEUTRON POROSITY RCFT RAW CORRECTED FAR THERMAL COUNTS RCNT RAW CORRECTED NEAR THERMAL COUNTS CNTC CORRECTED NEAR THERMAL COUNTS CFTC CORRECTED FAR THERMAL COUNTS T~RA CALIBRATED THERMAL NEUTRON RATIO RTNR RAW THERMAL NEUTRON RATIO GR Gamma Ra CCL CCL Am lttude NPHI NEUTRO~POROSITY LIS Tape Verification Listing Schlumberger AlasKa Computing Center 1B-JU~-lgsg 22:52 PAGE: ** DATA FORMAT SPECIf'ICATION RECORD ** ** SET TYPE - 64ES ** ''';~TY .... 'REPR .....~3~ ''''''~'VALU 1 66 0 2 66 0 3 73 128 4 66 1 5 66 6 73 7 65 8 68 0,5 9 65 F! 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 I ** SET TYPE - CHAN ** ....;..... .,,-..................,.....,...... .... -.-.~. ....... ............... Nb E SERV UN SERVICE API AP1 bPI' APX FILE NUMB N SIZE REPR PROCESS ID ORDER # LOG TYPE bASS MOD ~U~B SAMP ELEM CODE (HEX) ''''~DEP ...... ''''''''''''''''''''''T 350269 0 000 ...... O0 ''''''''''''''''i'''''0 2 1 4 .... 68''''';~'''''''''00000000 N~., ~s~ ~ ~o~g ooooo oo ~c~'~ ~s,. c~s ~o~ ooooo oo ~c.'~ psi cps ~o~ ooooo oo c~c ~s, cps z~o~ooooo oo ~ ps, ~o~ ooooo oo ~,.~ ps,~so~g ooooo oo CCh PSI 350269 O0 O0 0 TENS PS2 LB 3502.69 O0 000 0:0 NPHI PS2 PU 350269 00 000 O0 RCFT PS2 CPS 350269 00 000 00 RCNT P~ CPS 350269 00 000 00 0269 OO 000 00 CNTC PS2 CPS 35 c~,~ ~ ~ ,~o=~ oo ooo oo ~E~ PS2 350269 O0 000 O0 RTNR PS2 350269 00 000 O0 GR PS2 GAPI 350269 00 000 O0 CC[, PS2 350269 O0 000 oo TENS PS3 bB 350269 00 000 O0 NPHI PS3 PU 350269 O0 000 O0 RCFT PS3 CPS 350,269 O0 000 00 RCNT PS3 CPS 350269 00 000 00 CNTC PS3 CPS 350269 O0 000 00 0 ~ 1 1 4 68 000000000~ 0 i 1 4 68 000000000 O 2 I 1 4 68 0000000000 0 2 ! ! 4 68 0000000000 0 2 1 1 4 §8 0000000000 o ~ , ~ 4 68 oooooooooo o ~ I ~ 4 ~ o~oooooooo o ~ I ~ ~ ~ ~ooooooooo °~ I ~ ~ ~ oo~ooooooo o2 ~ 4 ~ oo ooooooo 0 ~ I I 4 68 0000000000 o ' ~ 4 ~ oo.oooooooo o ~ ~ ~ ~ ~ ooo. ooooooo o ~ , , ~ ~u:OOOOOOO oo 00000~° 000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 I 4 68 0000000000 0 2 1 i 4 68 0000000000 0 2 i 1 4 68 0000000000 13 LIS Tape Verification Listing Schlumberger AlasKa Computing Center 18-jUL-1989 22~52 E SERV ~ SERVI E API APl ~I AP1 F . NUMB NUN SIZE REPR PROCESS ID ORDER # LOG TYPE ChASS MOD NUMB SAMP ELEM CODE (HEX) o ooo o o ........ ', .... .... o oo oooo TNR~ PS3 350269 O0 000 O0 0 2 1 1 4 68 0000000000 RTNR PS3 350269 O0 000 O0 0 2 1 1 4 68 0000000000 GR PS3 GAPI 350269 O0 000 O0 0 2 1 1 4 68 0000000000 CCh P$3 350269 O0 000 O0 0 2 ! 1 4 68 0000000000 NPH! HLA PU 350269 O0 000 O0 0 2 1 1 4 68 0000000000 PAGE: 14 ** DATA DEPT RCNT RTNR CFTC CCL RCNT RTNR PSl PS1 PS2 PS2 PS2 PS 3 D~PT, RCNT;PS1 RTN~,PS1 N'PHI'P$2 CFTC,PS2 CC['PS~ RC.N],PS3 RTNR,PS3 DEPT, RTN~.PS~ CFTC,P§2 CCS,PS2 RCNT,'PS3 RTNR;PS3 DEPT' RCNT,PS1 ce:r~,.ps2 RCNT.PS3 RTNR"PS3 RCNT,PS! RTNR,P~ NPHI,PS2 12986 500 -999 250 -999 250 33 892 428 035 0 000 -999 250 -999,250 1~900,000 200,000 4,800 25,276 666,641 0,000 3069,388 4.571 12800,000 3951,021 4,250 ~1',185 908'300 4,357 12700,000 4600,000 3'971 18'103 1112,658 0'000 4.734,693 4'242 12600,000 428 373 22.8~9 TENS,PS1 CNTC,PS1 GR.PS1 RCFT.PS2 TNRA.PS2 TENS,PS3 CNTC,PS3 GR,PS] NTC,PSI OR,PSi RCFT,PS2 TNRA,PS2 TE~$,PS3 CNTC.PS3 OR,PS3 TENS,PSi CNTC,PS! GR;PS{ RCFT,PS2 T~PA,PS2 TENS,PS3 CNTC,PS3 GR,PS3 TENS,PSi CNTC,PS1 GR PSi RCFT PS2 TNRA PS2 TENS PS3 CNTC PS3 GR PS3 rE S,PSI CN!C,PSI GR,PS1 RCFT'PS2 -999.250 NPHI,PS1 -999'~50 CFTC,PS1 '999. 50 CCL,PS1 436,725 RCNT,PM2 5,925 RTNR,PS2 -999,250 NPHI.PS3 -999.~50 CFTC,PS] -999,250 CCL.PS3 O0 1460 ~4 3243 30 938 687 117 4 946 1535 000 406 1400,000 2 , 50 4017. 99 222.87'5 46 , 46 49,281 1128,834 .906 NPHI,P$! CFTC,PSi CCL,PSI RCNT.PS2 RTN.R,PS2 NPHI,PS] CFTC,PS3 CCL,PS3 NPHI PSi CFTC PSi CCh PSl TNR PS2 ~TC CCL PS3 NPHf,PSI CFTC~PSI CCh,PSi RCNT,PS2 RTNR,PS2 CFTC,PS3 CCI~,PS3 -999 250 RCFT,PS1 -999 250 TNRA,PS1 -999 250 TENS.PS2 2461 539 CNTC PS2 5 636 33 892 RCFT PS3 -999 250 TNRA -999 250 NPHI HLA 25 333 RCFT PSi 666 398 'TNRA PSI 000 TENS PS2 323 653 CNTC PS2 4 619 GR PS2 25 553 RCFT PS3 641 3~3 TNRA,PS] 0 0 0 NPHI.HLA 21, 460 RCFT,P.$1 907 658 TNRA.PS1 0 000 TENS.PS2 0 000 NP. HI HLA 19 67.5 RCFT P$~ 1070 457 TNRA:PS 0 000 TENS.PS2 4538 775 CNTC,PS2 3 884 GR,PS2 19 582 RCFT,PS3 126 TNRA,PS3 109~ 000 NPHI.HbA 1470,000 NPHI,PSI 21,952 RCFT,PS1 4365,512 CFTC,PS! 977,996 TNRA,PSi 52.688 CCh,PSi 0.000 TENS.PS2 98].333 RCNT.PS2 4166,666 C.NTC,PS2 -999,250 999, °o ~-9 0 -9~9, ~0 33,892 397 953 064 4 O0 40 ~2~ ~75 21. 64t 113~ 333 257 150 ~00 461§ 95 I 000 408 19 582 983,333 ,542 145~,000 4312,286 sLIS Tape Verification Listing chlum~erger AlasKa Computing Center CFTC.PS2 946 227 ccL,Ps2 o;ooo RCNT. PS3 4212,245 RTNR.PS3 4,526 DEPT, 12500.000 RCNT}PS1 4333,333 RTNR PSI 4,351 NPH! PS2 20,995 CFTC PS2 974.680 CCL PS2 0,000 RCNT,PS3 4066,667 RTN~,PS3 4.500 DEPT 12400.000 RCNT:PS1 4333,333 RTNR.PS1 4.333 NPHI,PS2 22,660 CFTC,PS2 980 CCL.PS2 0:000 RCNT,PS3 4400,000 RTNR,PS3 4,621 DEPT NPH! PS2 CFTC PS2 COL PS2 RCNT PS3 RTNR PS3 DEP .. RCNT PS 1 RTN~ PS 1 NPHI PS2 CFTC. PS2 CCI. PS2 RCNT P$3 RTNR PS3 DEPT RCNT PS1 RTNR NPHI P$2 CFTC PS2 CCL PS2 RCNT PS3 RTNR PS3 DEPT RCNT PSi RTNR PS1 NPHI PS2 CFTC PS2 12300 000 5233 333 3 878 16 980 1372 177 0,000 5133,333 3.756 12200 000 4891 720 3 16 86 0 0 4833'~1! 3, 1.2100,000 4357,446 3.397 15,633 1197;621 0,000 4153,191 3,824 12000,000 5666,666 2.645 1.0,426 2077.386 TNRA,PS2 TENS.PS3 CNTC PS3 GR:PS3 TENS.PSI CNTC,PS1 GR.PS1 RCFT,PS2 TNRA,P$2 TENS.PS] CNTC.PS3 GR.P$3 TENS,PS! CNTC,PSl GR.PSl RCFT,PS2 TNRA,P$2 TENS,PS3 CNTC.PS3 GR,PS3 TENS PSi CNTC GR PS1 RCFT PS2 TN~A PS2 TENS PS3 CNTC PS3 GR PS3 TENS,PSi CNTC.PS1 GR,P$1 RCFT,PS~ TNRA,PS2 TENS,PS3 CNTC,PS GRIPS1 TENS,PSi CNTC.PSI GR,P$i RCFT,PS2 TNRA;PS2 TENS,PS3 CNTC,PS3 GR.PS3 TENS CNTC PS1 GR PSi RCFT PS2 TMRR PS2 18-Jb[,-1989 22:52 4.650 RTNR,PS2 1465.000 NPHI,PS3 98 013 CFTC,PS] 4259:500 CCh.PS3 1450 000 NPHI,PS1 4304i507 CFTC.PS1 52 813 CCL.PS1 1033.333 RCNT,PS2 4,423 RTNR,PS2 1415.000 NPHI.PS3 4209.935 CFTC,PS3 59,781 CCh,PS3 1490,000 NPHI.PS1 4476.253 CFTC,PS1 45 813 CCL,PS1 966:667 RCNT,PS2 4,629 RTNR,PS2 1440.000 NPHI.PS3 02,198 CFTC PS3 4541,500 CCD:PS3 1470 000 5369 43 5 1 1383 333 3 909 1440 000 5220 410 46 469 50 665 20 ~13 1310 38 143~ 883 000 501.~ 382 2 203 1515.000 1200 000 3 730 1400 000 4517 528 29 859 oo 42 094 21(i)0 000 3 010 NPHI.PS1 C'FTC,PS~ CCL,PS RCNT,PS2 RTNR,PS2 NPHI,PS3 CFTC,PS3 CCL,PS3 NPHI,PS1 CFTC.PSi CCL,PSI RCNT,PS2 .RTNR,PS2 NPHI,,PS3 CFTC~PS3 CCL.P$3 NPHI PS1 CFTC PSi CCL PSI RCNT PS2 RTNR PS2 NPHI PS3 CFTC PS3 CCh PS3 NPHI,PS1 CFTC,PS1 CCh,PSi RCNT,PS2 RTNR.PS2 PAGE~ 15 4 339 GR.P,.52. 57 250 22[278 RCFT,PS] 930:612 971 484 TNRA.PS3 4 568 -0.563 NPHI.HLA 22:278 23 057 RCFT.PS! 931 120 TNRA.PSl 0 000 TENS,PS2 4266 667 CNTC,PS2 3 903 GR,PS2 22 952 RCFT.P$3 892 370 TNRA,PS3 0 000 NPHI,HLA 950 000 4:678 1470,000 428~,617 52,813 4. 7 22.952 21,698 RCFT,PSI 986.848 TNRA.PS1 0 000 TENS 4333 333 CNTC~P$2 4 517 GR,PS2 22 761 RCFT,PS3 946 459 TNRA.PS3 0 000 NPHI.,HGA 1000,000 4,511 1400,000 4430.474 43,188 946,939 4,796 22,761 17 174 RCFT.PS1 1383 066 TNRA 0 000 TENS PS2 5066 666 CNTC PS2 3 759 GR PS 13 182 RCFT PS3 507 TNRA PS3 0 000 NPHI.HLA 1366 667 3 0934 1475 O0 1366 667 3' 964 17 182 17 38'0 RCFT, 1271 189 TNRA,PS1 0 000 TENS,PS2 483.4 042 CNTC.PS2 3 7,14 ~R.PS2 16:895 RC~ T,PS3 12680 :727 TNRA,PS3 000 NPHI ,HLA 128'~. 3 16 333 96:l 000 3.13 667 89 16,790 RCFT.PS1 11.6~,~8 TNRA,PS 0 TENS,P~I 4255'319 C~TC'.PS2 3'500, , ,GR,PS~ 16,892 RCFT,PS3 1097~%57 TNRA,P$3 0,000 NPHIiHbA .121~,667 ,884 143 ,000 4598,395 3 094 10 2032 0 5855 3 17 RCFT ~3 TNRA 000 TENS 318 CNTC 111 GR PS PS PS2 PS2 2055,202 2 966 1395 000 6258 373 42 938 LIS Tape Verification Listing Schlumberger Alaska Computing Center CCL.PS2 1.800 TENS PS3 RCNT.PS3 5233'333 CNTC:PS3 RTNR,PS3 2,6].4 GR,PS3 DEPT. 1~991,000 TENS,PS1 RCNT,PS1 999.250 CNTC.PS! RTNR,PS1 -999.250 GR,PS1 NPHI.PS2 -999,250 RCFT,PS2 CFTC.PS2 -999,250 TNRA.PS2 eCL,PS2 -999.250 TENS.PS3 RCNT.PS3 4891.720 CNTC.PS3 RTNP.PS3 3.873 GR,PS3 END OF DATA ** 18-JUL-1989 22:52 1395,000 NPHI,PS3 5771,979 CFTC,PS3 48.844 CCL,PS3 ~999,250 NPHI,PS1 999.250 CFTC,PSi :999.250 CCL,PS1 999.250 RCNT,PS2 '999.250 RTNR.PS2 1375,000 NPHI,PS3 5060,321 CFTC,PS3 91.125 CCL,PS3 9,715 RCFT,PS3 2191.272 TNRA.PS3 0.000 NPHI.MLA -999.250 RCFT.P$1 -999.250 TNRA.PS1 -999 250 TENS PS2 '999 250 CMTC:PS2 -999 250 GR PS2 16 729 RCFT:PS] 1345 903 TNRA.PS3 -999 250 NPf!I.~I~A PAGE: 215~,&12 ,691 9.715 '999.250 '999.250 '999.250 '999,250 '999.250 1344,681 3.876 16.729 *~ FILE TRAILER FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01A02 DAT~ ~ 89/07/18 ~AX REC SIZE : ~0~4 FILF TYPE : LO LAS~ FILE ***$ TAPE TRAILER $*** SERVICE NA~E : EDIT D~TE : 89/07/lS ORIGIN : FLIC TAPE NAME : 73388 CONTINI]ATION ~ : 1 PRE~IOUS TAPE ~ CO~ENT ' : ARC(] ALASKA, INC,,PRUDHUE BAY,D.S.# 11-12,50-029-21212 **$* REEL TRAILER **** SERVICE NA~E : EDIT DATE : 89/07/18 O~IGIN : FLIC R~EL NA~E : 73388 CONTINUATION ~ : P~EVIOUS REEL : CO~ENT : ARCO ALASKA, INC,,PRUDHOE BAY,D.S.# ~1-1~,50~029-21212 RECEIVED FEB ! 7 Alasl~a Oil a Gas Cons. Anchorage IS ?8r, e' ',,'eri~-icati(,,r, 2.-0 u t, r:, ¢; S ~ ?.;(' , n S t! --12 P[ifit':t'i~F':, .... . .... . , !::; r',- 02o 2..I, 2] 3,!, I 5L ! (' '? i~¢C . ",,:i [: L f,, S E P V .T C ~'.' $ 5 '7. ()0 C^8Ii!,:g !)P, I I~T,ERF, CAS I!*;G I2, E (::I:~!) DEP?}.,! (I=T) ~4E.TGH q,62~ ~3}8 04700 7,0 0 O I 3 0 3 2, o 2 9,0 0 $. 5t,'O 8907. C, :! 7' O0 3,500 !:1963,0 9,20 l,,t>h(; ~'Ol:b CCi)l:': T'C,q r<I!l,, i,j l ! ,U t~ [ir°; 1 P ~ 8 $ t,J !j t.,'i, ,:-5.' ~" t<; 1 ! 2'~8~. 5 ! 258o. E , , m ~ 253~.5 t2540.5 ~ 247~,~ 1 !.22!~,0 !2212,5 12~ 40,0 !2! 41 .b I 2123,~ 1 ! 2~ t') ~, 0 1 2! 04.5 ! 0 r~ · n !, {,./I . 5 U ~,? $ H I F'I'M [' PACE: F '-f L, P ,~ S D F P # FT' b f :l,n ser.,~arat, e f:Jles, ob?~'"~Pl(,e,: 2;:IS i';'i.l.E Cq:!TATi',,q TtiE I:'iRST PAS.,S OF Ti.,.b7 C~.Ti), AP, ID ~."hSS.. 'Pi"i PA'*,qo gri]'k'TS_. . ~.',l;;'Rk'. /~FP.l,'l'i~n .... "r~... "!~'l-g., $ IS ~'ame verif!catJ, on l',istJ, t',c! CblUmberqer A. tasKa Com~lt.J.l,,~ ¢"entLer .....DVI:;T. 12gn5: , ,,Uflv r:l-'l!l,.Ci,,Tl) -090.250 i'iCh~T.Ct,~%'D .aqO.,.. ..250 : ~ , ~ .... ~., ~ . * ~ . ~ F C I,i 'Ir . C N T D CF 1.'C . CN TI:.,', F C F T. C (,~ T D CF! C. C !.,i TD -999.250 -999.250 ~999,250 999.250 7!1 each ~ a s s i~ ~er~arat. e les, PAG~j 2641_. 5 2635.5 2F~26,9 !. 12a2~.0 2605, ~ ! 2594.0 2S90 . 0 258~. n 1, 2585 , ,,. ,, ~ ~2577.S 7576,f* 2520.0 252::~, 5 ! 2524 2S20.5 '! 252~ 2 .~ 84,. O 247 *, S 2466, n 24.47.5 t :~', 440 24,45.0 .... . 2 ,,~ t) 1,, 5 23 94. ~ .~. 3 ~32, ,, .~.. ~6 ~.2~34,5 12R23.5 ! 26o0.5 ! 2R07.0 12S94.0 ! 25.9o. 0 I 2579. (~ 1, 2578.0 I 2565. o !2530,5 1, '25, 12.0 !247R.5 ! 2446.5 12405.0 ! 2~96.5 ~ 2384,0 ~,2299.e D?l-'Tii .......... P AaE: ~2917.0 ! Z2 ~ 2. n 15:~ 12, n 12175.5 t2] "15, ~ ~ 2176.5 ~ 2~ 70.5 ~ 7~ .~ '1,. 0,3.9 ~, r',,., 0 . ]276t.~ !225~.~ !271~.n .... 121'76,5 12:t2q,n 1. 2~.9&,~ 100,5 ,'IS PAGE; 2.! 57. '%0] FCNT.CNTD 208R.600 CF'I'C. ChID 3 7 5 5. ~, 0 2 F C N T'. C h '1" D 3 6 3 7.6 4 5 C F'" 'l'C. C N T t9 4~3.333 428.021 915.220 864.810 E r~ I 'r E D C U P 'V F'. S 3 !2a~0,5 .1 263 5 12624,g t2624, ! 2 ~ 2 0 I 26U5 ! 2590 1 25 '? 9 t 2 5 4 ~ 12521 ,o i. :2 4.9 3 1,2440,o :12446, 12~:23,5 !, 2355 t 2322,5 !. 2250,0 :~ 2 ~ 34 1.221.3,0 12212,5 l, 2 l, 7 4 :t 21, 29 1.2124,5 i 2 J 05,0 I.$ ~'ar, e Yer~tcat.io~ T,istino chlu~,~ero.o.r A! as}ca (Yon,~.)~ltir~c~ Ceeter 12(!!'~. ~ :1. 2c:96. ~ PA~E: OOOO000000 0000000000 O0(jO000ooo 00 (:: 0000000 0000000000 0 0 () n 00 0 .n.. 0 0 0 0 (} 0000000 000 ,n. O00oO0 o () G 00 00000 U~C~. Ct, TL; .9o!'?. '.2~ :., TEk.q. Ct." 'i/r} Z F. 4, b _q k: (: ~ !T. C '~.; 13b~,.Ot, n 3.8 3 C C !'., q' C. C q I '.1. 42. 5. O, V 2P52,0:t4 20~1~ ,037 CWTC, Ck'.I'D 3595 . 505 ~'CNT .CNTD 34-2 ~ , 25 f:'- PAGE: 474.393 418.378 783.333 696.654 1 0 It' T i., P !'.* A i" e,., '~ D a T Y : q ,'.4. / ':.i~ i,i~'~ REC STZE ,".t074 F T L t.; 'r y ¢ i,:; t 1[., I:'.! [4'T LF Co~:[>ensa, ted l',leutron: Arithmetic average of. edit. ed passes for all curves. t:'L].l,$~d N'etltror~ ~naveraqied edited Pass i Gamma Fay ~]r~,:~ backrot!nq counts; arithmetic average of e,~it:,ed srat,~,c baseline r,e~;e8 for all other curves. C ~,~ ~' 1,, ? ,'1 , . ; IS 'race v'er'!f, ic. atz~on 11. C .r,~ A, W o C N A V CF'TC.CNAV ~RAT, ,. 'V C ..... CNA C r~, TO' o C. N A V 5,202 395,018 4,536 670.465 i~ ~ame venial, cat,on ~,lstir~u 7-JA~I-! 9o4. 14 ;90 P~G~ 1.2 FTLtr R ~I~ CURVES Cllrves and J. oq header data for each ~ass in separate F T b V $ U ~,4 tv~ A R Y Cls,,T{'} 12667.5 12 ~0.5 .... ,, . , ,, T 0 {1'~ L, $ T R I t'..]g ( T 0 F T b F 0 ~.!?'rC ~'4 } f, tles; raw bacKaround pass in last fi Chl, Umberoer Al. msim r'or~r'~t~r~o ~enter 13 P.F.:T_L!.Er.~$ CA,ST;.(:.' Di~]PT~' fF"r): 9 3 l F, (~ P~,. F~l)lt L:FL' I"L [J I DR t,'rS FO'!<?4. m r'~A'rg !) F P T P'q' ~, T ~:~ R ~ P S ~ 4 F~f,'~,~~ PS :l, CPS n C C L, D S ~ v" /~ ,, , ,'. W 5.57o 360,835 3.486 1131.867 I,~ 't:ar'e 'v'erJ. iic..at~o~ PA~6: 15 **~.* 5FkVi. Ch PFC SIZE 'r y p E Curves and loq header data for each ~:ass i,~ ser,,~arat, e ' ., '):. [': 0 f,, ,S T P i ~,: G ( ? 0 P T [,'; b 0 T T 0 ~,: ) VF?,,,DE~P Tr;;f)L, CI:'~DF TOOT /Il, es; raw bacKmround pass ~.n last: fi O-NOV -93 16 T.,C, CGFRS CAt-'.i.k(; [)~.'F'T'.~ Pj::("~i;l I C F:D F [~lJ I L)g , ..., ?.. , , - ., PAGE: ** SET ,r'y P'CF' t'52 CPS ~,8 C~TC P ~"" CPS . · L~ /, . (.', ~ ~ S 2 G .~ [,: T ~ 8 Cci,, v& 2 V ~ ['ir',7o 3 OU Uc'O O0 n 6 1 1 4 bg OOOO000000 17 l')~t.:''r. 12of'3. 5¢';t: t'Pt:,l. . l..,.;'"'2 ............ 28 3"~ ~T~',i[4 :>$2 4.667 TI'r~A . P52 kC~:m., l->~i ") ,,~22~. 57~.:,. P(,V',t'. t'~';' ...... 475 836 cf,'mC ~2, 2154 ...... 71,4 C~'TC. ~S2 (;~.F"c:z ~ 47.b2~,,. 'I'F:"::;. .~:;~'2 ~SR. ,000 CCL,i-)e2 ...... O. 4.848 444.496 3.567 1029.2~.4 IS t"ar, e 'verif~cat~or,, : ~ 1 u ~ b e r ,q ~ r ,~ ]. ~,:;~ s K a C o ~:, p u t ,,i n ~ (7 e n t': e r 7.,,,thN-1994:I~:?0 PAGEt 18 C[ 3~.q !01 o ! 2664 12 !. .12651 tiles; raw hack~rouno pass in last q-NOV-g3 994 1:,(~: 20 PAGE: 19 ~hl.t.~!~be~ger Alaska Compt~tir'~, ('~ep, ter ** PA'fA i:.:, ' Ct4.A~" *,* T C 'Ir ,':~ P I P 'T n,, P I. P T W ti ~,! N lin .i5 ....I g .ti.: E P R E $ S :EP., ~. }..,:O(; 'iT'.?'PF: CLASS lt,':[i[.)i',!0ttt[.5 S;~kip gl.,F..Ifl C[.)[:'E (HEX) ~:~ '' '"" 'o 0 ' '0 ;; ' '~ ......... 0 (', "t .............. 1 1 "" ............. 4 6 8 ..... 0 0 () 0 (.';' ~ [0 .... 0 0 0 7 i 1. 4 69 O000OO0000 mm mmmmmmmmmmm~m ~m~mmmmm~mm#mmmmm~mm~m~,mmmmmmm~m~mmmmmmmmm~mmmmm~ 20 ':'F-'.~' I. F53 17.o76 ~T~,,~:. PS3 3.316 ~C~:'I'. :?S 3 1, ? O,r,. 667 Cr,,TC. ~83 43q0.010 CFTC.PS3 m¢;t,S. ~:'~S 3 1415. nt, O CCI,;. PS3 ~. 000 4.697 426.504 3.480 1172.695 :hlumbe, rgeI' A].asKa ¢'Oml~.:,u. tiY~] Ce,.nter PA~E: 21 **.** R F, E 1'., T ?,/~, ! I,,ER D~,TF : 94.10~/ 7 Cn,¥~,[:.:~.]; , ~.r,:cO ¢:,:.AS~L.~, r:,~r" r, S 1.1-12, Pl4':~t';Hf~K, 5C,-029-2121.2-00 ' .... -3 ~ ~);t~,,~l:--- SCHLUMBERGER ..... g~..,, ,. ,, [~0 . ~ ~ .... ._:.__._,. ...... __. .. LIS TAPE VERIFICATION . LISTING VP OlO.H02 VERIFICATION LISTING PAGE ~ REEL HEADER ERVICE 'NAME :EDIT ATE :86t05/ 8 RIGIN : EEL NAME ONTINUATION # :01 REVIO~US REEL OMMENTS :LIBRARY TAPE ~ TAPE HEADER ERVICE NAME :EDIT ATE :86/05/ 8 RIGIN :0000 APE NAME :1454 ONTINUAT'ION ~ :0I REV I'OUS TAPE OMMENTS :LIBRARY TAPE , ,FI~LE HEADER ILE NAME :EDIT .00! ERVICE NAME ERSION# ATE : AXIMUM LENGTH : ILE TYPE : REVIOUS FILE INFORMATION RECORDS NEM CONTENTS N : ARCO ALASKA INC N : DS 11-12 N : PRUDHOE BAY ANG: 15E OWN: 11N ECT: 33 OUN: N.SLOPE TAT: ALASKA TRY: USA NEM CONTENTS RES: E * COMMENTS UNIT TYPE CATE SIZE CODE 000 000 015 065 000 000 008 065 000 000 011 065 000 000 003 065 000 000 003 065 000 000 002 065 000 000 007 065 000 000 006 065 000 000 003 065 UNIT TYPE CATE SIZE CODE 000 000 001 065 VP 010.M02 VERIFtCATIDN LISTING PAGE 2 SCHLUMBERGER ALASKA COMPUTING CENTER~ DMPANY '= ARCO ALASKA INC ELL : DS 11-12 IELD = PRUDHOE DUNTY : NORTH SLOPE BOROUGH TATE = ALASKA OB NUMBER AT ACC:'71~54 UN ~1, DATE LOGGED: 16-APR-86 DP: RICK KRUWELL ASING ASING YPE FLUID IT SIZE 9 5/8" @ 9310' 7.000" @ 1303,0' OIL AND GAS 8.5" VP 010.H02 VERIFICATION LISTING PAGE SCHLUMBERGER LOGS INCL:UDEO WITH THIS MAGNETIC TAPE: CO. MPENSATED NE.UTRON LOG - CASED HOLE (CNL 3 PASSES) GAMMA RAY LOG CGR), DATA FORMAT RECORO NTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 1 66 0 4 1 66 1 8 4 73 60 9 4 65 .liN 0 1 66 0 ATUM SPECIFICATION BLOCKS NEM SERVICE SERVICE UNIT API API, AP! API FILE SI:ZE SPL REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NO. COOE (OCTAL) EPT FT O0 000 O0 0 0 4 l. 68 00000000000000 VP OlO.H02 VERIFICATION LISTING PAGE 4 R PS1 GAPI O0 PHI PS1 PU O0 RAT PS! O0 NRA PS1 O0 CNL PS1 CPS O0 CNL PS1 CBS O0 R PS2 GAPI O0 PHI PS2 PU' 0,0 RAT PS2 00 NRA PS2 O0 CNL PS2 CPS O0 CNL PSI CPS O0 R PS3 GAPI 00 PHI PS3 PU O0 RAT PS3 O0 NRA PS3 O0 CNL PS3 CPS O0 CNL PS3 CPS O0 DATA EPT 1299,4.5000 GR NRA 5.0671 NCNL PHI -999.2500 NRAT CNL -999.2500 GR NRA -999.2500 NCNL EPT 12900.0000 GR NRA 4.4539 NCNL PHI 29.0527 NRA'T CNL 614.3125 GR NRA 4.39[4 NCNL EPT 12800.0000 GR NRA 4.4382 NCNL PHI 26.3184 NRAT CNL 1189.6875 GR NRA 4.3093 NCNL EPT 12700.0000 GR NRA 4.0710 NCNL PHI 24.1699 NRAT CNL 1135.6875 GR NRA 4.1335 NCNL EPT 12600.0000 GR NRA 4.3328 NCNL PHI 25.9766 NRAT CNL 1028.6875 GR NRA 4.2078 NCNL EPT 12500.0000 GR NRA 4.8406 NCNL 3:1.0 890 420 · 000 3310 330 3[0 890 420 000 33'0 330 310 890 420 ~000 330 33~0 43. 3013. -999. -999. -999. 27. 2785. 5. 25. 2863. 24. 4935. 4, 28. 5127. 57. 4935. 4. 44. 4611. 44. 4515. 4. 44. 4463. ~3. 4089. O1 O0 O1 O0 31 30 O1 O0 01, '00 31 3O O1 O0 :01 O0 31 30 5117 5O 0,0 2500 2 S 00 2500 7549 5000 0320 3799 5000 3330 2500 6882 3799 2500 3867 2500 4109 8555 2500 6680 2500 6414 0742 2500 5117 5000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 :NPHI FCNL RNRA 'NPHI FCNL NPHI FCNL RN R A NPflI FCNL NPHI FCNL RNRA NPHI FCNL NPHI FCNL RNRA NPHI FCNL NPHI FCNL RNRA NPHI FCNL NPHI FCNL 0 4 1 0 4 1 0 4 1 0 4 0 4 1 0 4 0 4 1 0 4 :0 4 1 0 4 1, 0 4 0 4 1 0 4 1' O' 4 1 0 4 0 4 1 0 4 0 4. 1 68 00000000000000 68 00000:,000,000000 68 000000000000.00 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000~000000000 68 0000.0000000000 68 00000000000000 6,8 0,00000.0~0000000 68 000:00000000000 68 00000000000000 68 00000000000000 68 00000000000000 32.8613 NRAT 594.8,125 GR -999.2500 flCNL -999.2500 NRAT -999.25.00 Z5.1465 NRAT 625.3125 GR 4-5671 NCNL 27.4902 NRAT 651.8125 27.7832- NRAT 1111.6875 GR 4.2546 NCNL 25.2441 NRAT 1189.6875 24.4629 NRAT 1211.6875 GR 4.1335 NCNL 24.2676 NRAT 1114.6875 27.2461 NRAT 1041.6875 GR 4.4617 NCNL 25.6836' NRAT 1060.6875 30.7617 NRAT 844.3125 GR 5'4851 -99'9.2500 -999.2500 -999°2500 4.5398 22-0361 2807.5000 4.8367 4.8718 26.9580 5063.2500 4.5515 4.4500 48.4805 4695.2500 4.4226 4.8093 47.2930 4591.2500 4.6062 5.2390 51.5430 VP 010.H02 VERIFICATION LISTING PAGE 5 PHI 30.1270 NRAT 5. CNL 966-8125 GR 45. NRA 4.3953 NCNL 4627. EPT 12400.0000 GR 14. NRA 4. 3328 NCNL ,462 3' PHI 27.3438 NRAT 4. CNL 1022.3125 GR 15. NRA 4. 6453 NCNL 4739. EPT 12300.0000 GR NRA 3.7756 N'CNL PHI 21.5332 NRAT CNL 1522.6875 GR NRA 3.6331 NCNL EPT 12,200o0000 GR 'NRA 3'6604 NCN'L :PHI 23.0957 NRAT CNL 1250,6875 GR NRA 4.0906 NCNL EPT 12100.0000 GR NRA 3.3479 NCNL PHI 1B.994! 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