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188-073
Originated: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above Transmittal Date: RECEIVE® APR 2 3 2020 AJGCC WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE 1 1E-20 50-029-20895-00 906260886 Kuparuk Multi Finger Caliper Field&Proc 23-1an-20 2 1E-12 50-029-20736-00 906207895 Kuparuk Leak Detect with ACX Processed 30 -Dec -19 3 1E-12 50-029-20736-00 906190298 Kuparuk Plug Setting Record Final -Field 19 -Dec -19 4 iF-OS 50-029-20807-00 906223186 Kuparuk Injection Profile Log Field&Proc 8 -Jan -20 5 1R -23A 50-029-22200-01 906228630 Kuparuk Multi Finger Caliper Field&Proc 7 -Jan -20 6 WSW 11 50-029-20882-00 1906310488 IShallow Sandl Plug Setting Record Final -Field 12 -Feb -20 7 3G-05 50-029-20132-00 906174377 Kuparuk Packer Setting Record Final -Field 26 -Dec -19 8 3M-17 50-029-21729-00 906210841 Kuparuk Leak Detect Log Final -Field 29 -Dec -19 9 3N -02A 50-029-21527-01 906192001 Kuparuk Leak Detect Log Final -Field 23 -Dec -19 10 30-01 50-029-21836-00 1906193765 IKuparuk I Plug Setting Record Final -Field 20 -Dec -19 i PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS _ANC@ halliburton.com Date: Signed: 32817 13 -Mar -20 PRINTS # CD # 0 1 0 1 RECEIVED • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APR 14 ?01R WELL COMPLETION OR RECOMPLETION REPORT ANArkloppi la.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended❑ 1b.Well Clas 20AAC 25.105 20AAC 25.110 Development E ' Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 116 188-073/315-498 3.Address: 7. Date Spudded: ii /14 `c 15.API Number: P.O. Box 100360 Anchorage,AK 99510 7/27/1988 / 50-029-21836-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: VV..' 16.Well Name and Number: Surface: 724'FNL, 1842'FWL, Sec 22,T13N, R9E, UM 8/3/1988 KRU 30-01 Top of Productive Interval: 9. Ref Elevations: KB: 59' 17. Field/Pool(s): 1206'FNL, 594'FEL, Sec 16,T13N, R9E, UM GL: 24' BF: 25' Kuparuk River Field/Oil Pool. Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1008'FNL, 735'FEL, Sec 16,T13N, R9E, UM 8860'MD/6645'TVD. ADL 25513 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 525478 y- 6022095 Zone- 4 11201'MD/6633'MD ' 2554 TPI: x- 523017 y- 6026884 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 522875 y- 6027082 Zone- 4 N/A 1967/1840 5. Directional or Inclination Survey: Yes E(attached) No ❑ 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 SCOW JUN 2 0 2016 none 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD • AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 62.5 H-40 33' 115' 33' 115' 24" 200 sx ASI I 9 5/8" 36 J-55 35' 5305' 35' 4066' 12 1/4" 1250 sx ASII, 370 sx CI G 80 sx ASI 7' 26 J-55 35' 9148' 35' 6871' 8 1/2" 200 sx Class G 24. Open to production or injection? Yes J No 0 25.TUBING RECORD PACKER SET(MD/TVD) If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) 5412'MD/4138'TVD Size and Number): 3-1/2" 8575' ' 8480'MD/6350'TVD all perfs squeezed off 8666'MD/6494'TVD 4}6R1.10 C NEO 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. COMrL LOI. Was hydraulic fracturing used during completion? Yes❑ No ❑ DAT ___12111 /206 Per 20 AAC 25.283(i)(2)attach electronic and printed information VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1.1- cement plugs 8944'-7581' 31.8 bbl of 16.5 ppg cement(22 bbl of CemNet) 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period .-0.- Flow ♦Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 24-Hour Rate Form 10-407 Revised 11/2015 V TI- 67•3 / 6o CONTI U D ON PAGE 2 RBDMS (.1� Submit ORIGINIAL only }� ftf3 517/yAPR 1 4 2016 128.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No Q rIf Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed). Submit detailed descriptions,core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No CI Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1967' 1840' Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. Kuparuk C Top 8781' 6582' Kuparuk C Bottom 8809' 6604' None Kuparuk A Top 8820' 6612' Kuparuk A Bottom 8952' 6716' Formation at Total Depth: Kuparuk 31. List of Attachments: -0 Amy DP&.iRTtbOS >i WM4 4a4/, SC..b(t.GMT/c.. 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: Cody Pohler @ 265-6435 Email: Cody j.pohler(a�cop.com CJ jP Printed Name: Ga •.Eller Title: CTD Engineering Supervisor Signature: Phone: 263-4172 Date: 4iN1e INSTRUCTIONS General: This form and t e required attachments provide a complete and concise record for each well drilled 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 Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange 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 measured depth and true vertical thickness of permafrost.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. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including, but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. 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 • • ,a ,. Well Service Summary °; , r' 30-01 Cono ,hp Almka Time Log Report Start Date Report End Date Dur(hr) Operation Details 11/4/2015 06:00 11/4/2015 19:00 1.00 PICK UP COMP&FILE,TRVL TO LOC VIA 1-Y PAD FOR TOOLS, Report Start Date Report End Date Dur(hr) Operation Details 11/4/2015 06:00 11/4/2015 19:00 0.59 ARRIVE ON LOC,CONTACT DSO,CHECK IN W/RIG SITE CONTROL, INSPECT AREA,TGSM. Report Start Date Report End Date Dur(hr) Operation Details 11/4/2015 06:00 11/4/2015 19:00 1.75 MIRU HES,REPACK,MAKE UP.108"WIRE, 1.875"TS=6',KJ,5',OJ,KJ,LSS(OAL=27') MIRU LRS. CONTACT DSO TO S/I WELL. Report Start Date Report End Date Dur(hr) Operation Details 11/4/2015 06:00 11/4/2015 19:00 1.75 DSO S/I G/L&MANIFOLD,PT LUB W/LRS, F/P FL W/14 BBLS DSL. BRING LRS ON LINE, AFTER 10 BBLS DOWN TBG RIH W/2.2"CENT,BLB&1.75"S.BLR,SD LRS&25 BBLS AWAY, SD IN 2.75"D.NIP @ 8665'SLM(8701'RKB)=36'C/F,TAG @ 8880'SLM(8916'RKB)EST 6' OF RAT HOLE,PUH AND BOL LRS BRUSH DS NIP @ 5334'RKB&UPPER GLMs. Report Start Date Report End Date Dur(hr) Operation Details 11/4/2015 06:00 11/4/2015 19:00 1.00 RIH W/KJ,3"D-RT&2.81"CSA-2 PLUG TO DS NIP @ 5334'RKB,BRING LRS ONLINE,SD& SET PLUG @ 5308'SLM(5335'RKB)GOOD PULL TEST,TBG NOT PRESSURING UP,SHEAR OFF&POOH,LRS PUMP 10 BBLS WHILE POOH. TBG UP TO 675 PSI. T.TAILS GOOD (POSSIBLE ANN COMM ISSUE) Report Start Date Report End Date Dur(hr) Operation Details 11/4/2015 06:00 11/4/2015 19:00 1.00 LRS RD AND ANOTHER LRS TRUCK MIRU(TAKES REMAINING LOAD f/1ST TRUCK) Report Start Date Report End Date Dur(hr) Operation Details 11/4/2015 06:00 11/4/2015 19:00 2.00 PT LUB W/LRS,RIH W/3"GS&BAITED GUTTED JD(OAL=44")TO CA-2 PLUG @ 5334' RKB,SD&SET CATCHER @ 5307'SLM',POOH,SEE F/L @ 800'SLM,BUMP UP&HAVE LRS PUMP 10 BBLS AND TBG INCREASE FROM 675-2000 PSI,MONITOR 15 MINS,TBG DOWN TO 1875 PSI. BUMP BACK UP TO 2050 PSI W/.3 BBLS,MONITOR 15 MINS,DOWN TO 1800 PSI,BUMP BACK UP W/.3 BBLS,MONITOR 15 MINS, 1700 PSI. SIBO. Report Start Date Report End Date Dur(hr) Operation Details 11/4/2015 06:00 11/4/2015 19:00 2.75 RIH W/2.5"RB&3.5"D&D HOLE FINDER(CS)ATTEMPT MITT AGAINST PLUG. INITIAL T/I/O = 1500/1000/440/80 START=2600/1000/440/80 15 MINS=2540/1000/440/80 30 MINS=2500/1000/440/80 45 MINS =2460/1000/440/80(TOOK.5 BBLS TO PT FAILED/RETEST W/.1 BBLS) 2625/1000/440/80 15 MINS=2610/1000/440/80 15 MINS=2600/1000/440/80 15 MINS= 2590/1000/440/80 POOH WITH D&D HOLE FINDER,BLEED TBG BACK TO 1500 PSI,SIBO. Report Start Date Report End Date Dur(hr) Operation Details 11/4/2015 06:00 11/4/2015 19:00 0.59 LDFN,CONTACT DSO,INSPECT AREA,PJSM. Report Start Date Report End Date Dur(hr) Operation Details 11/4/2015 06:00 11/4/2015 19:00 0.58 TRVL TO CWG TO DOWNLOAD/PAPERWORK. Report Start Date Report End Date Dur(hr) Operation Details 11/4/2015 06:00 11/4/2015 19:00 0.00 END TICKET. Report Start Date Report End Date Dur(hr) Operation Details 11/5/2015 06:00 11/5/2015 19:00 0.84 PICK UP COMP&FILE,TRVL TO LOC VIA 1-Y PAD. Report Start Date Report End Date Dur(hr) Operation Details 11/5/2015 06:00 11/5/2015 19:00 0.50 ARRIVE ON LOC,CONTACT DSO,SIGN IN W/RIG,INSPECT AREA,TGSM. Report Start Date Report End Date Dur(hr) Operation Details 11/5/2015 06:00 11/5/2015 19:00 0.50 RU HES,MAKE UP.108"WIRE, 1.875"TS=6',KJ,5',OJ,KJ,LSS(OAL=27') MIRU LRS. Report Start Date Report End Date Dur(hr) Operation Details 11/5/2015 06:00 11/5/2015 19:00 0.75 PT LUB W/LRS,BEGIN MITT 2500 PSI. INITIAL T/I/O/FL = 1150/1000/400/80. LRS PT TBG TO 2500 PSI W/.4 BBLS DSL. START=2550/1000/400/80 15 MINS=2470/1000/400/80 30 MINS=2445/1000/400/80 PASS. Page 1/8 Report Printed: 4/14/2016 • • Well Service Summary 4r � 30-01 t ps A1. Time Log Report Start Date Report End Date Dur(hr) Operation Details 11/5/2015 06:00 11/5/2015 19:00 1.33 RIH W/KJ,3"OM-1,7"EXT&1.625"JD TO GLM @ 4697'RKB,HARD TO LOCATE,SD& LATCH GLV @ 4676'SLM(4697'RKB)POOH W/GLV.(ISSUES WITH LRS TAKING BACK FLUIDS FROM LUB TOOK 20 MINS TO GET OFF WELL) Report Start Date Report End Date Dur(hr) Operation Details 11/5/2015 06:00 11/5/2015 19:00 0.84 RIH W/KJ,3"OM-1 &1.5"DV ON RK LATCH,LOCATE LOW AND SKIP BUY,SD&SET DV @ 4676'SLM(4697'RKB)GOOD PULL TEST,SHEAR OFF&POOH,F/L @ 1200'SLM,OOH W/ KOT INDICATING A GOOD SET. Report Start Date Report End Date Dur(hr) Operation Details 11/5/2015 06:00 11/5/2015 19:00 0.75 BRING LRS ONLINE, RIH W/KJ,3"OM-1,7"EXT&1.625"JD TO GLM @ 2928'RKB,AFTER 11 BBLS TBG INCREASE f/400-1000 PSI, LOCATE,SD&LATCH GLV @ 2908'SLM(2928'RKB) POOH W/GLV. Report Start Date Report End Date Dur(hr) Operation Details 11/5/2015 06:00 11/5/2015 19:00 0.75 RIH W/KJ,3"OM-1 &1.5"DV ON RK LATCH TO GLM @ 2928'RKB,LOCATE,SD&SET DV @ 2908'SLM(2928'RKB)GOOD PULL TEST,SHEAR OFF&POOH W/KOT INDICATING A GOOD SET. Report Start Date Report End Date Dur(hr) Operation Details 11/5/2015 06:00 11/5/2015 19:00 1.25 PT LUB W/LRS,LRS PUMP 4 BBLS&TBG INCREASE FOR 450-1500 PSI,HOLDING FOR 15 MINS(GOOD TEST)RIH W/KJ,3"OM-1,7"EXT&1.625"JD TO GLM @ 5287'RKB,LOCATE, SD&LATCH OV @ 5265'SLM(5287'RKB)POOH W/OV. SECURE WELLHEAD. Report Start Date Report End Date Dur(hr) Operation Details 11/5/2015 06:00 11/5/2015 19:00 4.08 LRS MIRU FOR CIRC OUT. BEGIN PUMPING @ 14:50. PUMP 105 BBLS SW FOLLOWED BY 90 BBLS DSL. BEGIN U-TUBE @ 17:35 Report Start Date Report End Date Dur(hr) Operation Details 11/5/2015 06:00 11/5/2015 19:00 0.50 LDFN,CONTACT DSO,INSPECT AREA,PJSM. SIGN OUT W/RIG. (Irs to finish u-tube and f/p flow line w/meth) Report Start Date Report End Date Dur(hr) Operation Details 11/5/2015 06:00 11/5/2015 19:00 0.66 TRVL TO CWG TO DOWNLOAD/PAPERWORK. Report Start Date Report End Date Dur(hr) Operation Details 11/5/2015 06:00 11/5/2015 19:00 0.25 END TICKET. Report Start Date Report End Date Dur(hr) Operation Details 11/8/2015 06:00 11/8/2015 14:00 1.00 PICK UP COMP&FILES,TRVL TO LOC VIA 1-Y PAD FOR TOOLS. Report Start Date Report End Date Dur(hr) Operation Details 11/8/2015 06:00 11/8/2015 14:00 0.34 ARRIVE ON LOC,CONTACT DSO,CHECK IN W/RIG,INSPECT AREA,TGSM. Report Start Date Report End Date Dur(hr) Operation Details 11/8/2015 06:00 11/8/2015 14:00 1.00 MIRU HES,MAKE UP.108"WIRE, 1.875"TS=6',KJ,5',OJ,KJ,LSS(OAL=27') Report Start Date Report End Date Dur(hr) Operation Details 11/8/2015 06:00 11/8/2015 14:00 1.34 MIRU LRS,PT LUB W/LRS, RIH W/KJ,3"OM-1 &1.5"DV ON RK LATCH TO GLM @ 5287' RKB,LOCATE,SD&SET DV, BRING LRS ONLINE AND PT TBG TO 1500 PSI W/IA HOLDING 300 PSI,SHEAR OFF&POOH. TOOL INDICATES A GOOD SET. Report Start Date Report End Date Dur(hr) Operation Details 11/8/2015 06:00 11/8/2015 14:00 1.00 RIH W/3"GR TO BAITED P/T,SD&LATCH BAITED PULLING TOOL @'SLM,POOH WITH EQ PRONG,TBG DROP f/1500-600 PSI. (RUN MADE BY KEITH PIERCE) Report Start Date Report End Date Dur(hr) Operation Details 11/8/2015 06:00 11/8/2015 14:00 1.07 RIH W/3"RS,TOOLS FALL FREE TO LATCH PLUG BODY @ 5305'SLM,HIT 2 700#OJ LICKS &COME FREE,POOH W/PLUG BODY.(RUN MADE BY KEITH PIERCE) Report Start Date Report End Date Dur(hr) Operation Details 11/8/2015 06:00 11/8/2015 14:00 0.67 LRS PERFORM INJECTIVITY TEST. @.3 BPM FOR 5 BBLS @ 600 PSI @.5 BPM FOR 5 BBLS @ 650 PSI @ 1 BPM FOR 5 BBLS @ 700 PSI. ATTACHED IS A PUMP REPORT. Page 2/8 Report Printed: 4/14/2016 • • Well Service Summary 30-01 +onocoPt dIip5 Ri ska Time Log Report Start Date Report End Date Dur(hr) Operation Details 11/8/2015 06:00 11/8/2015 14:00 1.09 RDMO,CONTACT DSO,INSPECT AREA,PJSM. SIGN OUT W/RIG. END TICKET. Report Start Date Report End Date Dur(hr) Operation Details 11/8/2015 06:00 11/8/2015 14:00 0.49 (ASSIST 7ES WITH SETTING P PRONG FOR PXN PLUG) Report Start Date Report End Date Dur(hr) Operation Details 11/12/2015 06:00 11/12/2015 12:00 1.25 P/U UINIT FROM YARTD,STOP BY Y-PAD FOR TOOLS,CONTACT DSO,TRAVEL TO LOC, SIMOPS W/RIG Report Start Date Report End Date Dur(hr) Operation Details 11/12/2015 06:00 11/12/2015 12:00 1.00 ARRIVE LOC,PJSM,MIRU 108 WIRE,SWAP TO 1.875"STEM,TS=RS,5',5',KJ,LSS(OAL 18') CONTACT DSO, INSTALL FUSEABLE Report Start Date Report End Date Dur(hr) Operation Details 11/12/2015 06:00 11/12/2015 12:00 2.25 PT W/GAS, 10 MIN LUBE STOP,RIH, LOC TTL @ 8735'RKB/8701'SLM,RIH 30 MIN STOP @ 8840'RKB,PUH 15 MIN STOP @ 8710'RKB,POOH 10 MIN LUBE STOP,SIBO Report Start Date Report End Date Dur(hr) Operation Details 11/12/2015 06:00 11/12/2015 12:00 1.00 PJSM,FUSEABLE REMOVED,TREE CAP PT, INSP LOC,CONTACT DSO Report Start Date Report End Date Dur(hr) Operation Details 11/12/2015 06:00 11/12/2015 12:00 0.50 TRAVEL TO 3M Report Start Date Report End Date Dur(hr) Operation Details 11/17/2015 06:00 11/17/2015 18:00 0.20 Attend OPS Meeting in Company Man's office. Report Start Date Report End Date Dur(hr) Operation Details 11/17/2015 06:00 11/17/2015 18:00 2.00 Travel to location. Report Start Date Report End Date Dur(hr) Operation Details 11/17/2015 06:00 11/17/2015 18:00 0.20 PJSM. Report Start Date Report End Date Dur(hr) Operation Details 11/17/2015 06:00 11/17/2015 18:00 3.00 MIRU. Report Start Date Report End Date Dur(hr) Operation Details 11/17/2015 06:00 11/17/2015 18:00 2.60 Perform Weekly BOP Test. Report Start Date Report End Date Dur(hr) Operation Details 11/17/2015 06:00 11/17/2015 18:00 3.08 Hold PJSM and then M/U Milling BHA w/Baker(Russell Gallens) Pull test good....and pressure test fails redo connector and re-pressure test Report Start Date Report End Date Dur(hr) Operation Details 11/17/2015 06:00 11/17/2015 18:00 0.50 Take injector stack to well and stab BOPs w/night cap onto well.Take injector stack to rear deck. Report Start Date Report End Date Dur(hr) Operation Details 11/17/2015 06:00 11/17/2015 18:00 0.42 Secure location for the night.Return in morning to mill nipple. Report Start Date Report End Date Dur(hr) Operation Details 11/18/2015 06:00 11/18/2015 19:15 0.25 Morning Ops Meeting in Company Man's office. Report Start Date Report End Date Dur(hr) Operation Details 11/18/2015 06:00 11/18/2015 19:15 0.35 Travel to location. Report Start Date Report End Date Dur(hr) Operation Details 11/18/2015 06:00 11/18/2015 19:15 0.25 PJSM. Report Start Date Report End Date Dur(hr) Operation Details 11/18/2015 06:00 11/18/2015 19:15 1.30 Take injector stack to well.Fluid pack and pressure test both lubricator and surface lines 300/ 4,000. Report Start Date Report End Date Dur(hr) Operation Details 11/18/2015 06:00 11/18/2015 19:15 1.26 Open swab valve and RIH 1st WT CK @ 3,000'=7.8k Page 3/8 Report Printed: 4/14/2016 ti • r p Well Service Summary t1,. i° = r Well Service Summary 30-01 Catxxo hi lips Time Log Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 1.90 M/U CTC and BJN BHA. Pull test and pressure test are both good. Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 0.86 Taker injector stack to the well.Fluid pack and pressure test both lubricator and surface lines 300/ 4,000. Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 0.37 Open swab valve and RIH pumping warm S/D @ 1 bpm to warm coil(-26 degrees ambeint) slowly RIH and bleed gas cap off Cementers are rigging up Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 0.90 Switch to 120 degree SSW and continue RIH WHP=494 IA=896 OA=403 CP=1,048 Maintaining 1:1's Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 2.40 Tag TD @ 8,944' PUH 5 and pump bottom's up while holding PJSM w/SLB pumpers SLB starts batching cement play with choke and 40 bbl FRT to monitor for 1:1's Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 0.27 Cementers ready to pump 5 bbls of F/W ahead for water spacer Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 0.14 Cementers pressure test their hardline 700/4,000. Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 0.11 P.T.good start pumping 5 bbls of 16.5 neat cement WHP=233 IA=1,196 OA=507 CP=1,098 Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 0.34 Now pumping 22 bbls of 16.5 cement w/CemNet(1.5 ppb).... WHP=198 IA=1,373 OA=507 CP=1,518 Pump rate at 1 bpm still Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 0.08 Now pumping 5 bbls of neat cement WHP=368 IA=1,149 OA=503 CP=1,411 Have now swapped to 35 bbl FRT to verify 1:1's.... 31.6 totals bbls of 16.5 cement pumped Page 5/8 Report Printed: 4/14/2016 • • „ Well Service Summary 30-01 COnocoPhi)l ps' st Time Log Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 0.10 Switch to F/W spacer Pump rate still at 1 bpm. WHP=266 IA=1,135 OA=502 CP=1,517 Still verifying 1:1's Start PUH at 26 fpm in 7"casing 2 bbls of cement above nozzle Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 0.10 Still pumping F/W WHP=250 IA=1,140 OA=503 CP=760 1 bpm rate and still PUH at 26 fpm Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 0.10 Stop at flag still pumping F/W at 1 bpm WHP has fallen to 34 psi starting to squeeze cement away due hydrostatic pressures less than 1:1's now choke is wide open Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 0.20 Close choke and start squeezeing WHP never came above 80 psi reduce pump rate to.4 bpm and PUH to safety. Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 0.20 Stop at 6,900'.Wait here for hesitation. Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 0.60 Coil hands went to pump methanol down the BOPs to keep from freezing and the WHP shot up 2,500 psi.WHP was bled off immediately,but very slowly to 1,400 psi and held for 30 minutes. Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 0.12 Drop 3/4"ball and start pumping PowerVis getting 1:1's and keeping WHP at 900 psi after bleeding down from 1,400 to 900 psi Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 1.15 Start RIH to 8,663'contaminating stringers and TOC hit top of cement @ 7,581'RKB (which means we squeezed about 14.8 bbls behind pipe)continue RIH washing cement Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 1.00 AT 8,684'and stop PUH at 30 fpm and wash cement area again Switch to S/D out of PowerVis Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 1.25 at 7,581' POOH pumping S/D at 1.5 bpm WHP=928 IA=1,081 OA=495. Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 0.60 At surface.Close swab valve.Bring injector stack to rear deck. ***3/4"stainless ball recovered*** Report Start Date Report End Date Dur(hr) Operation Details 11/19/2015 05:45 11/19/2015 22:00 2.72 RDMO. Report Start Date Report End Date Dur(hr) Operation Details 11/22/2015 06:00 11/22/2015 11:00 1.00 PU CPU/WELL FILES,TRAVEL TO LOCATION VIA Y-PAD, Page 6/8 Report Printed: 4/14/2016 • • Well Service Summary .,-',1 30-01 Ciltips Alosko Time Log Report Start Date Report End Date Dur(hr) Operation Details 11/22/2015 06:00 11/22/2015 11:00 1.50 UNIT ON EOP,START MAST TRUCK,SPOT UNIT,TGSM,RU.108 WIRE&1.875"TS= RS,5',KJ,5',OJ,LSS.OAL=24.5', INSTALL FUSIBLE CAP,CONTACT DSO. Report Start Date Report End Date Dur(hr) Operation Details 11/22/2015 06:00 11/22/2015 11:00 1.50 PT W/LRS,RIH W/3'X WB,2.17"CENT&1.75"S-BLR,TAG CEMENT @ 8656'SLM,PUH TO 8000'SLM,P/T TBG TO 2000 PSI HOLDING,R/D TAG @ SAME,BLEED BACK TO 475 PSI, POOH,BLR FULL CEMENT,CONFER W/CWG REP, Report Start Date Report End Date Dur(hr) Operation Details 11/22/2015 06:00 11/22/2015 11:00 0.75 PSJM,RDMO,REMOVE FUSIBLE CAP,CONTACT DSO. Report Start Date Report End Date Dur(hr) Operation Details 11/22/2015 06:00 11/22/2015 11:00 0.25 MOVE DOWN TO 30-20.SPOT UNIT. Report Start Date Report End Date Dur(hr) Operation Details 11/24/2015 09:00 11/24/2015 17:00 1.00 Travel to location Report Start Date Report End Date Dur(hr) Operation Details 11/24/2015 09:00 11/24/2015 17:00 0.50 Spot equiptment.Rig up Report Start Date Report End Date Dur(hr) Operation Details 11/24/2015 09:00 11/24/2015 17:00 2.00 (PRE CTD):Tighten all flange studs from THA to tree cap.Tree Shell test(PASSED).DDT-MV, SSV,SV(PASSED),PPT-MV,SSV,SV(PASSED). Initial T/I/O=si TWC/vac/320 Pressured tree above TWC. Discovered leaking ring gasket between SSV&MV. Bled to 0 psi. Hammer wrenched all flanges from THA up,except Between SV&SSV due to scaffold in the way. Repressured tree.Ring gasket leaking between SV&SSV bled to 0 psi.stand by for scaffold crew. Report Start Date Report End Date Dur(hr) Operation Details 11/24/2015 09:00 11/24/2015 17:00 1.00 Stand by while scaffold crew arrives and air wrenched connections Page 7/8 Report Printed: 4/14/2016 • Well Service Summary 30-01 ConooPhillips Time Log Report Start Date Report End Date Dur(hr) Operation Details 11/24/2015 09:00 11/24/2015 17:00 2.00 **Scaffold crew use air gun to tighten tree flanges.** Incrementally pressured tree aboveTWC to 5000 psi.Monitor for 15 min for tree shell test 15 min no external leaks.Tree Shell test passed. (PRE CTD):DDT-MV,SSV,SV(PASSED),PPT-MV,SSV,SV(PASSED). Pressured tree above TWC to 5000 psi w/diesel.Closed MV trapping 5000 psi between TWC and MV. Bleed pressure above MV to 0 psi.Monitor for 15 min. 15 min=40 psi.(Passed). Opened MV. Pressured tree above TWC to 5000 psi w/diesel.Closed SSV trapping 5000 psi between TWC and SSV. Bleed pressure above SSV to 0 psi.Monitor for 15 min. 15 min=50 psi.(Passed). Opened SSV.Pressured tree above TWC to 5000 psi w/diesel.Closed SV trapping 5000 psi between TWC and SV. Bleed pressure above SV to 0 psi.Monitor for 15 min. 15 min=0 psi.(Passed). Opened SV.Bled tree to 0 psi above TWC.Shut SV. Pressured tree above SV to 5000 psi w/diesel.Monitor for 15 min. 15 min=4725 psi.(-275).(Passed). Bled tree to 0 psi above SV.Opened SV.Shut SSV. Pressured tree above SSV to 5000 psi w/diesel.Monitor for 15 min. 15 min=4625 psi.(-375). Repressured tree above SSV to 5000 psi w/diesel.Monitor for 15 min. 15 min=5000 psi.(Passed). Bled tree to 0 psi above SSV.Opened SSV.Shut MV. Pressured tree above MV to 5000 psi w/diesel.Monitor for 15 min. 15 min=4700 psi.(-300).(Passed). Bled tree to 0 psi above MV.Opened MV.Shut SV. Final T/I/O=SI TWC/vac/320. Report Start Date Report End Date Dur(hr) Operation Details 11/24/2015 09:00 11/24/2015 17:00 0.50 Rig down Report Start Date Report End Date Dur(hr) Operation Details 11/24/2015 09:00 11/24/2015 17:00 1.00 Travel to camp Page 818 Report Printed: 4/14/2016 n�, a KUP OD 30-01 • ConocoPhilli ips Well Attrib Max Angle&MD TD r .A1851<,..Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Cpg phigi, 500292183600 KUPARUK RIVER UNIT PROD - 52.62 3,700.00 9,173.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-01,4/14/20163:11;46 PM SSSV:NIPPLE 140 12/15/2015 Last WO: 2/26/2009 34.98 8/5/1988 _..:.Yanccal schematic(actual) _ Annotation Depth(ftKB) End Date Annotation Last Mod By End Date 1' g� Last Tag:SLM 8,880.0 11/4/2015 Rev Reason:ADD LATERALS,GLV C/O lehallf 1/8/2016 nn.unnu,ann,,, maanuwuumum � .,�I --,Casing - HANGER;33.2 �� Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread I P-_.� CONDUCTOR 16 15.062 33.0 115.0 115.0 62.50 H-40 WELDED ,`�,� ,_Z� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 111 SURFACE 95/8 8.765 34.6 5,305.0 4,066.0 36.00 J-55 BTC :11 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade 'Top Thread CONDUCTOR;33.0-115.0 , PRODUCTION 7 6276 35.2 9,148.0 6,870.7 26.00 J-55 BTC Tubing Strings NIPPLE;511.0 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection IN TUBING 31/2 2.990 33.2 5,399.81 4,129.6 9.30 L80 EUE8RD Completion Details GAS LIFT;2,928.2 - ..: Nominal ID I i Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 33.2 33.2 0.20 HANGER C.I.W.TUBING HANGER 2.950 IN 511.0 510.8 3.27 NIPPLE CAMCO 2.875"'DS'NIPPLE 2,875 GAS LIFT;4,697.1 tIta.� 5,334.0 4,085.5 47.73 NIPPLE CAMCO 2.813"13S'NIPPLE 2.813 111 H; 5,377.0 4,114.4 47.86 LOCATOR LOCATOR 2990 I III 5,378.3 4,115.2 47.86 SEAL ASSY SEAL ASSEMBLY w/2'SPACEOUT 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection Straddle Packer 3 1/2 2.992 5,368.1 8,575.0 6,423.6 9.30 L-80 EUE 8rd AB Mod GAS LIFT;5,287.0 Completion Details IV Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 5,368.1 4,108.4 47.83 SLEEVE "HR"LINER SETTING SLEEVE 4.420 SURFACE;31.8.5,375.0 5,381.7 4,117.5 47.87 SBE SEAL BORE EXTENSION 4.000 NIPPLE;5,334.0 5,401.7 4,131.0 47.93 XO- CROSSOVER SUB 2990 Reducing 5,411.6 4,137.6 47.91 PACKER BAKER 4782-7"26#FHL PACKER 2.970 SLEEVE;5,388.1 r 8,479.6 6,350.2 39.71 PACKER BAKER 4782-7"26#FHL PACKER 2.970 LOCATOR;5,377.0 1. (. 8,529.0 6,388.2 39.64 NIPPLE 'OTIS 2.813"'X'NIPPLE 2813 Ilti 8,568.5 6,418.6 39.55 OVERSHOT BAKER 7"x 3.625"POOR BOY OVERSHOT w/6.10" 3.620 SEAL ASSY;5,378.3, -®- SWALLOW SBE;5,381.7 s t Ma Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ibllt) Grade Top Connection Ali TUBING Original 31/2 2.992 8,570.6 8,736.0 6,548.0 9.30 J-55 Completion Details o Nominal ID It Top(ftKB) Top(ND)(ftKB) Top Incl(-) Item Des Corn (in) 8,6522 6,483.3 39.41 PBR AVA PBR/LOCATOR 3.000 PACKER;5,411.6 " " ' 8,665.9 6,493.8 39.39 PACKER AVA RMS PACKER 3.000 it 8,701.4 6,521.2 39.34 NIPPLE CAMCO'D'NIPPLE 2.750 8,735.2 6,547.4 39.18 SOS SHEAR OUT SUB um sr r 2.992 Other In Hole(Wireline retrievable plugs,valves, fish etc. PACKER;8,479.6 - pumps,Top(ND) Top Incl ' Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) I� 8,840.0 6,628.9 38.69 WHIPSTOCK Baker XL Whipstock Tray 12/11/2015 0.000 NIPPLE;8,529.0 -ANCHOR TRAY 11 A 9,000.0 6,754.3 38.18 FISH PIECE OF 3"JD DOG 1"x 1.5" 8/31/2008 0.000 OVERSHOT,8,568.5 II Perforations&Slots Shot I Dens GAS LIFT;8,611.6 �. Top(ND) Btm(ND) (shots/ q',=_ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 8,696.0 8,698.0 6,517.1 6,518.6 A-1,30-01 9/17/2015 3.0 IPERF SHOOT2'TUBING PBR;8,652.2 - PUNCH AT 8696'(ELM) PACKER;9,865.9 USING 2"HSC BIG HOLE CHARGES,3 SPF,120 DEG IPERF;8.096.0-8,698.0 PHASING;CCL TO TOP SHOT 7.5' ' �° NIPPLE;8,701.4 8,832.0 8,847.0 6,622.7 6,634.4 A-3,30-01 4/28/1989 12.0 IPERF 2 1/8"EnerJet;60 deg. � ph 8,850.0 8,866.0 6,636.7 6,649.3 A-2,30-01 4/28/1989 12.0 IPERF 2 1/8"EnerJet;60 deg. 'ii Iph 8,890.0 8,910.0 6,668.0 6,683.7 A-1,30-01 10/3/1988 8.0 IPERF 4.5"Csg Gun;45 deg. SOS;8,735.2 ph Mandrel Inserts St - ati on Top(TVD) Valve Latch Port Size TRO Run IPERF;8,832.08,847.0 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type (in) (psi) Run Date Com I Type 0 wHlPsrocK-ANcrIORrRav:`� �1 2,928.2 2,504.2 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,275.0 12/24/2015 11:30 9,ew.o I} 2 4,697.1 3,649.5 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,266.0 12/24/2015 6:00 (PERF;S.0S0.05,886.0.-. i ` I _ 3 5,287.0 4,053.9 Camco MMG 1 1/2 GAS LIFT 'OV RK ' 0.250 0.0 12/24/2015 4:30 • IPERF;8.890.0-0,910.0 . �if 4 8,611.6 6,451.9 OTIS LBX 1 1/2 GAS LIFT OPEN 0.000 0.0 1/28/2009 4:30 SLOTS,0,730.0-10.985.0 Notes:General&Safety FISH;9,000.0 •r 1 End Date Annotation 2/28/2009 NOTE:View Schematic w/Alaska Schematic9.0 l i i 1/8/2016 NOTE:LATERALS 30-01A,30-01AL2.30-01AL3 ADDED,AL1 NOT DRILLED PRODUCTION;35.2-9,148.0 II II Lateral Slotted Liner; 8,729.8-10,985.0 "A"Lateral Slotted Liner;9,171.8 -11,200.0 -magi me.- • • DrillingOperations Summary (with Timelog Depths) =4 &Wels 30-01 LonucoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK siert rria - -End rirne• : Out(fir) Op code A$ ty Cade Tape P-T X Operation::` - :. ( ) . End as (M B)_ 12/7/2015 12/7/2015 3.00 MIRU MOVE MOB P Prep for rig move to 30-pad.Load and 0.0 0.0 03:00 06:00 secure tree.Check all tree bolts,found 4 loose bolts between SSV and Master. 1.25 hrs. ""Note:Confirmed temp to be minus 33", Able to keep working as per ConocoPhifips SOP. 12/7/2015 12/7/2015 2.00 MIRU MOVE MOB P Complete RD checklist,Pull pit sub 0.0 0.0 06:00 08:00 away from drilling sub.Prep shop for move.Prep for Sow arrival at 4am and rig move starting at 8:45am. 12/7/2015 12/7/2015 0.75 MIRU 'MOVE MOB P PJSM,Peak and rig crew, 0.0 0.0 08:00 08:45 continuously monitoring ambient temp as per Conoco SOP,currect temp 32 below zero, install jeeps,ready to move down the road. 12/7/2015 12/7/2015 3.00 MIRU MOVE MOB P Move Rig and Shop to 30-pad, 0.0 0.0 08:45 11:45 ....Note:IA valve stem gas leak, dispatch valve crew to repair stem packing. 12/7/2015 12/7/2015 4.00 MIRU MOVE MOB P Spot rig modules over 30-pad,Well 0.0 11:45 15:45 01.remove jeeps "'s Note:No loose tree bolts to report, 0.5 hr. 12/7/2015 12/7/2015 2.75 MIRU MOVE RURD 'P RU checklist,RU interconnect(Putts), 0.0 0.0 15:45 18:30 connect ground to well head. 12/7/2015 1217/2015 1.50 MIRU MOVE RURD 'P Nipple up BOPE stack,Intall fusable 0.0 0.0 18:30 20:00 cap,open IA and OA, 12/7/2015 12/8/2015 4.00 MIRU WHDBOP RURD '1 Replace all BORE door seals for 0.0 0.0 20:00 00:00 Incident prevention in lou of previous o -ring failures. •"'Note:Rig Accept at 20:00.... 12/8/2015 12/8/2015 2.00 MIRU 'WHDBOP RGRP T Continue to change out all door seals 0.0 0.0 00:00 02:00 on BOP 2 Hrs Nabors NPT 12/8/2015 12/8/2015 2.00 MIRU WHDBOP RURD P Continue rig up.swap out riser O- 0.0 0.0 02:00 04:00 rings,Prep for BOPE test. 12/8/2015 12/8/2015 12.00 SLOT WHDBOP BODE P Perform initial BOPE test 250/4,500 0.0 0.0 04:00 16:00 psi,annular 250/2,500 psl.Test waived by(AOGCC)Chuck S. 12/8/2015 12/8/2015 4.00 SLOT WELLPR CTOP P PJSM.Prep rig fioor to cut coil.Cut ' 0.0 0.0 16:00 20:00 1,400'coil 12/8/2015 12/8/2015 2.50 MIRU WELLPR PRTS P PJSM,Test TT line,R/U and pull BPV 0.0' 0.0 20:00 22:30 12/8/2015 12/9/2015 1.50 SLOT WELLPR MPSP P -Rig down BPV lubricator and load out, 0.0 0.0 22:30 00:00 C/O pack offs,Start filling coil 12/9/2015 12/9/2015 1.00 SLOT WELLPR CTOP P Complete filling coil,Pump slack,PT 0.0 0.0 00:00 01:00 and chart inner reel iron and pack offs - 12/9/2015 12/9/2015 1.25 SLOT WELLPR CTOP P Cut 37 feet of CT back to find a-line. 0.0 0.0 01:00 02:15 1400'total 12/9/2015 12/9/2015 0.75 SLOT WELLPR 'PRTS P Pressure lest PDL's.Good test. 0.0 0.0 02:15 03:00 t Page 1/10 Report Printed: 514/2016 • S ptliu.ng Operations Summary (with Timetog Depths) a Wells 30-01 ConocolhiHips Rig: NABORS CDR2-AC ne.14 :•-..v.- ',.::---,::.. 1 G SIDETRACK TL Sioalntia Endtune (hr) SLOT rtreoe ..: OpOgle AclMtycoda .11eP-1'-ff - ' swn 12/9/2015 12/9/2015 2.35 SLOT WELLPR CTOP P Rehead coil connector and pull test to t 0.0 0 0 03:00 05:21 37klbs. Rehead MC and test a-line. Test CC o-rings. 12/9/2015 12/9/2015 1.30 SLOT WELLPR CTOP P PJSM.Stab on,pump lack forward. 0.0• 0.0 05:21 06:39 12/9/2015 12/9/2015 0-50 MIRU WHDBOP OWFF P Perform flow check,found leak on 0.0 0.0 06:39 07:09 BOP stack at 2 3/8"D.ram door seal. 12/9/2015 12/9/2015 1.00 MIRU WHDBOP RGRP T Troubleshoot BOP stack repair.Add 0.0 0.0 07:09 08:09 more torque to 2 3/8"door seal. NPT:1 Hour 12/9/2015 12/9/2015 1.00 MIRU WHDBOP BOPE P Function test BOPE,good test. 0.0 0-0 08:09 09:09 12/9/2015 12/9/2015 0.85 PROD1 RPEQPT PULD P PJSM.PU/MU BHA#1 with.9°AKO 0.0 62.5 09:09 10:00 motor and 0331 mill with sick guage 12/9/2015 12/9/2015 2.50 PROD1 RPEQPT TRIP P RIH WI cement milling assembly while 62.5 8,110.0 10:00 12:30 pumping SW©1 bpm. 12/9/2015 '12/9/2015 0.50 PROD1 RPEQPT DLOG P Start logging tie-in pass,log HRZ. 8,110.0 8,174.0 12:30 13:00 PUH to relog,wits problem. 12/9/2015 12/9/2015 2.50 PROD1 RPEQPT DLOG 'T Relog HRZ several times,having 8,174.0 8,500.0 13:00 15:30 MWD software problems,continue troubleshooting logging issues. 12/9/2015 12/9/2015 0.25 PROD1 RPEQPT DLOG P Log K1 for a+2.5 foot correction 8,500.0 8,605.0 15:30 15:45 12/9/2015 12/9/2015 0.50 PROD1 RPEQPT TRIP P RIH and tag cement at 8691' 8,605.0 8,691.0 15:45 16:15 12/9/2015 12/10/2015 7.75 PROD1 RPEQPT MILL P PUH and displace well over to 8,691.0 8,845.0 16:15 00:00 Seawater milling fluid.Begin milling cement pilot hole.Stall at 8834'. Continue milling. 12/10/2015 12/10/2015 1.25 PROD1 RPEQPT MILL P 8845'.Continue milling pilot hole to 8,845.0 8,860.0 00:00 01:15 planned depth of 8860'.ROP 20-25 FPH.20 FPH-'20'above whipstock setting depth` 8840 12/10/2015 12/10/2015 0.25 PROD1 RPEQPT MILL P Pull up hole and dry drill transition 8,860.0 8,860.0 01:15 01:30 area.Clean drift. 12/10/2015 12110(2015 1-70 PROD1 RPEQPT TRIP 'P Pull out of hole and LD BHA#1 8,860.0 72.0- 01:30 03:12 12/10/2015 12/10/2015 1.30 PROD1 RPEQPT PULD P At surface,Flo check well 30 Min-Lay 72.0' 0.0 03:12 04:30 down BHA#1,D331 out at 2.79"No- Go 12/10/2015 12/10/2015 1.50 PROD1 RPEQPT PULD P PJSM with HES caliper-Stab on well 0.0 0.0 04:30 06:00 to jet stack,shell test BOP stack, lower 2 3/8"door seal leaking. 12/10/2015 12110/2015 4.00 PROD1 'RPEQPT PULD 7 Troubleshoot door seal leak,change 0,0 0.0 06:00 10:00 door seal and retest as per town. Good test.Town decide to wait on new door seal.LD Halliburton caliper assembly In mousehole,release crew. Begin NAD NPT Time©06:00 End NAD NPT Time®16:15 12/10/2015 12/11/2015 14.00 PROD1 RPEQPT WAIT T Secure wellhead.Wait on new door 0.0 0.0 10:00 00:00 seal arrival.Prep stack for new seals. New door seals on location at 22:10. Page 2/10 Report Printed: 5/4/2016 • • DrillingOperations Summary(with Timelog Depths) &Wells 30-01 LonOct>I'l,illips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Tithe tag i:i ;:i i8 rl TbNtP�r(Nfj Pf b'9 '. t7'1;4- ":Ac" .:de.: .,:i Y St :§1!!" ut>ap 12/11/2015 12/11/2015 2.50-PROD1 RPEQPT RGRP Tt Completed installation of new style 0.0 0.0 00:00 02:30 BOP door seals. Function test rams. Shell test BOP to 4,500 psi. End NAD NPT Time 12/11/2015 12/11/2015 1.50 PROD1 'RPEQPT DLOG P Run Valve check list,PJSM with HES 0.0 22.0 02:30 04:00 to MN caliper,M/U to end of coil and surface test caliper 12/11/2015 12/11/2015 2.25 PROD1 RPEQPT DLOG P RIH with caliper,tie-in log-6.5' 22.0 8,855.0 04:00 06:15 correction,RIH to 8,855'. 12/11/2015 12/11/2015 0.75 PROD1 RPEQPT DLOG P Caliber arms deployed,log up hole @ 8,855.0 8,150.0 06:15 07:00 40 FPM. - 12/11/2015 12/11/2015 1.50 PROD1 RPEQPT CLOG P POOH w/caliper assembly 8,150.0 0.0 07:00 08:30 12/11/2015 12/11/2015 3.15 PROD1 RPEQPT DLOG P LD Halliburton BHA,set down on 0.0 0.0 08:30 11:39 master during pick-up,bent bow spring centralizer.Wait on caliper data to be downloaded&processed. 12/11/2015 12/11/2015 1.05 PROD1 RPEQPT PULD P PJSM.MU BHA#3 0.0 72.5 11:39 12:42 12/11/2015 12/11/2015 2.75 PROD1 RPEQPT WPST P RIH w/Baker XL WS tray,tie-in K1 72.5 8,851.0 12:42 15:27 marker for-13'correction,PUW 8,560'40K,continue in hole to set depth @ 8,851'.Close EDC,pressure up to 3,200 psi,release from WS, stack 3K down.TOWS(§)8,840', orientation 12 deg LOHS. 12/11/2015 12/11/2015 1.45 PROD1 RPEQPT TRIP P POOH for WS milling assembly 8,851.0 57.5 15:27 16:54 12/11/2015 12/11/2015 0.80 PROD1 RPEQPT PULD P Tag up,30 MMflow check,Lay down 57.5 0.0 16:54 17:42 BHA#3,Whipstock setting tools 12/11/2015 12/1112015 1.20 PROD1 WHPST PULD P M/U BHA#4 Window milling with.6" 0.0' 74.3 17:42 18:54 motor,2.79"string mill and 2.80" window milt.M/U to coil and surface test tool 12/11/2015 12/11/2015 1.50 PROD1 WHPST TRIP P RIH,EDC closed,Pump min rate 74.3 8,540.0 18:54 20:24 12/11/2015 12/11/2015 0.30 PROD1 WHPST CLOG P .,Log K1 for-13'correction,Get rates 8,540.0 8,619.0 20:24 20:42 above cement top,1.6 BPM 25o0PS1 FS,PUW=39K 12/11/2015 12/11/2015 0.30 PROD1 WHPST TRIP P Continue in well,dry tag whipstock Q 8,619.0 8,841.0 20:42 21:00 8841,PUW=39K 12/11/2015 12/12/2015 3.00 PROD1 WHPST WPST P Bring pumps on 1 6BPM C+2500 PSI 8,841.0 8,842.0 21:00 00:00 FS,RIH to mill.Begin milling window per procedure.Observed some motor stalls while establishing the window. Started milling from pinch point at_, !, 8840.3 ft. 12/12/2015 12/12/2015 5.50 PROD1 WHPST J WPST U Pp( 8842 drilling ft.CoMlnueprocedure.miltiWa8ng window1.7klbs per 8,842.0 8,846.0 00:00 05:30 �V T , f D pumping 1.6 BPM at 2500 psi pump pressure. 12/12/2015 12/12/2015 2.00 PROD1 WHPST WPST. P Continue miffing window(812 fph as 8,846.0 8,850.5 05:30 07:30 per well plan.1.6 BPm©2,450 psi. Minimal formation sand in returns. 12/12/2015 12/12/2015 1.00 PROD1 WHPST WPST P Drill rathole:1.60 BPM©2,415 PSI, 8,850.5 8,862.0 07:30 08:30 BHP=3,405 PSI,CTW=10.5K, WOB=2K,ROP=10.0.Still not seeing much formation sand in returns,did get some crude. Page 3/10 Report Printed: 5/4/2016 • • DoriKing Operations Summary(with Timelog Depths) aWells 30-01 LonocoPhiIiips Rig: NABORS CDR2-AC :TimeL .. Job: DRILLING SIDETRACK op Gale. . ActivityT Rt-Xsears B 12/12/2015 12/12/2015 3.25 PROD1 WHPST REAM Taf _. Y Make back reaming passes ses to the 8,862.0 8,862.0 08:30 11:45 right,PUH,shut down pump,dry drift. Stack-out four times above window. PUH,call town for input,try it with pump up.Bring pump online,RBIH,no issues through WS.PUH for pump issues. 12/12/2015 12/12/2015 1.50 PROD1 WHPST REAM T Make three more back reaming 8,862.0 8,862.0 11:45 13:15 passes,PUH.Shut down pump,dry drift twice,clean_ 12/12/2015 12/12/2015 2.00 PROD1 WHPST TRIP P POOH for build drilling assembly 8,862.0 63.5 13:15 15:15 12/12/2015 12/12/2015 025 PROD1 WHPST OWFF P Flow check,wellhead preesure 63.5 63.5 15:15 15:30 coming. 12/12/2015 12/12/2015 1.75 PROD1 WHPST PULD P PJSM.PUD BHA#4 63.5 0.0 15:30 17:15 12/12/2015 12/12/2015 2.25 PROD1 DRILL PULD P PJSM.MU/PD BHA#5,0.6°AKO 0.0 0.0 17:15 19:30 motor and rebuilt HCC bi-center bit. 12/12/2015 12/12/2015 3.25 PROD1 DRILL TRIP P RIH with BHA#5. 0.0 8,862.0 19:30 22:45 12/12/2015 12/12/2015 1.00 PROD1 DRILL SVRG P Service rig,prepare to drill ahead. 8,862.0 8,862.0 22:45 23:45 12/12/2015 12/13/2015 0.25 PROD1 DRILL DRLG P 8862 ft.After clean trip through 8,862.0 8,870.0 23:45 00:00 window,tag bottom at 8862 ft.Begin drilling build section.Displace viscosified seawater with 8.9 ppg flo- pro while drilling. 12/13/2015 12113/2015 5.25 PROD1 DRILL DRLG P 8870 ft.Continue drilling build section. 8,870.0 9,005.0 00:00 05:15 New mud at bit at 8875 ft.End of build • called at 9005 ft.Ankerite©8,909' broke free c'8,914'. 12/13/2015 12/13/2015 1.75 PROD1 DRILL TRIP P POOH for lateral drilling assembly,tag 9,005.0 65.5 05:15 07:00 up,space-out. 12/13/2015 12/13/2015 ' 2.50 PROD1 DRILL PULD P PJSM.PUD BHA#5,LD BHA. 65.5 0.0 07:00 09:30 Maintenance injector&BOP,pump slack,change-out UQC,test E-Line. 12/13/2015 12/13/2015 2.50 PROD1 DRILL PULD P 'PJSM.MU/PD BHA#6,service choke 0.0 72.5 09:30 12:00 as well. 12/13/2015 12/13/2015 1.50 PROD1 DRILL TRIP P RIH w/lateral drilling assembly,0.5"+ 72.5 8,535.0 12:00 13:30 AKO motor,new Hycalog bit. 12/13/2015 12/13/2015 0.25 PROD1 DRILL DLOG P Tie-in to K1 marker at 8521 ft for a- 8,535.0 8,571.0' 13:30 13:45 12.5 ft correction. 12/13/2015 12/13/2015 0.50 PROD1 DRILL TRIP P Continue to RIH to EOB at 9005 ft. 8,571.0 9,006.0 13:45 14:15 12/13/2015 12/13/2015 0.50 PROD1 DRILL DLOG P Tag bottom ay 9005 ft.MAD pass up 9,006.0 8,885.0 14:15 14:45 through build section for resistivity • data. 12/13/2015 12/13/2015 5.25 PROD1 DRILL DRLG P RBIH and continue drilling the lateral. 9,005.0 9,410.0 14:45 20:00 1.59 BPM 0 3,590 PSI FSI, BHP=4,110 PSI,CTW=10.5K, WOB=2K,ROP=70-120 FPH. 12/13/2015 12/13/2015 0.50 PROD1 DRILL WPRT P Wiper trip#1 to the window.PUW= 9,410.0 9,410.0 20:00 20:30 33 Klbs. 12/13/2015 12/14/2015 3.50 PROD1 DRILL DRLG P 'BOBD.1.6 BPM al 3822 PSI FS. 9,410.0 9,713.0 20:30 00:00 BHP=4154 PSI.WOB=1.8 Klbs. ROP 70 FPH. Page 4/10 Report Printed: 5/4/2016 • • go-7 WELL LOG TRANSMITTAL#902978896 DATA LOGGED /201C0 4( ( BENDER To: Alaska Oil and Gas Conservation Comm. January 15, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JAN 2 0 2016 RE: Multi Finger Caliper: 30-01 AOGCC Run Date: 12/11/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 30-01 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21836-00 Multi Finger Caliper(Field Log) 1 color log 50-029-21836-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton � pNEQ 4, 9U r� Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ''✓V���� -..---. ...-- • z.C>4a3 WELL LOG TRANSMITTAL#902754954 DATA LOGGED o/2-9/2O15 K BENDER To: Alaska Oil and Gas Conservation Comm. October 23, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED OCT 28 2015 RE: Tubing Punch Record: 30-01 Run Date: 9/17/2015 AOGGC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 30-01 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21836-00 SCOW , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS ANC@halliburton.com Date: Signed: •rai , `�;,ti"_"_C OF Tk ,74,'4' THE STATE Alaska Oil and Gas ���� ofj\ ® Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®F ALAS"- Fax: 907.276.7542 www.aogcc.alaska.gov Cody Pohler �� .4k)CTD Engineer S 4 3 ConocoPhillips Alaska, Inc. l P.O. Box 100360 6 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-01 Sundry Number: 315-498 Dear Mr. Pohler: 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, a/ath4/09).e.j..4.74dL.CFoerster Chair RBDMSY F � i 2015 DATED this i day of September, 2015 Encl. STATE OF ALASKA AKA OIL AND GAS CONSERVATION COMMON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations • Fracture Stimulate r Pull Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill • Perforate New Pool r Repair Well r Re-enter Susp Well r Other: r"-- 2. �2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc.- Exploratory r Development 17. 188-073 • 3.Address. Stratigraphic r Service r 6.API Number. P.O. Box 100360,Anchorage,Alaska 99510 50-029-21836-00- 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No I KRU 30-01 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25513 . Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9173 - 6890 , 9065' . 6805 none 9000' _ Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 115' 115' SURFACE 5270 9.625 5305' 4066' PRODUCTION 9113 7 9148' 6871' ` w• '"" -- - AUG 13 AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8832-8847, 8850-8866,8890-8910 6623-6634,6637-6649,6668-6684 3.5 L-80 5400 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER 4762-7"26#FHL PACKER - MD=5412 TVD=4138 PACKER-BAKER 4762-7"26#FHL PACKER - MD=8480 TVD=6350 PACKER-AVA RMS PACKER • MD=8666 TVD=6494 NIPPLE-CAMCO 2.875"'DS'NIPPLE . MD=511 TVD=511 12.Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development Fv7 ,Service ` 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/20/2015 OIL r VVINJ r WDSPL r Suspended 14,r 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r ,,aso Commission Representative: GINJ r Op Shutdown r Abandoned 1 •R" 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Cody Pohler @ 265-6435 Email: Cody.J.Pohler@conocophillips.com Printed Name Cod Po - Title: CTD Engineer A Signature y`,� 6 _ O Phone:265-6435 Date ) O61( Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3(5- .(q Plug Integrity r BOP Test IV Mechanical Integrity Test r Location Clearance r Other: Sop 17-5f 457,0 p5i• t!^'' n 5 P 15 4407-r5-9 /1-n.-t vl Qv o r<tit h ,t-r r- 11 -51- to 25- 0p5'0 , / 1 7 L t.- /411—er,14 tr pi y Jo]aeri-v[t07J' Gcppr-o ✓t•G1 I)rc ,,?cit-4- c Z Spacing Exception Required? Yes ❑ No [/ Subsequent Form Required: `p —4U.7 ,D APPROVED BY / Approved by: COMMISSIONER THE COMMISSION • Date: 9-/14--- /,5 YTL q/q I l Approved plication is valid for 12 months from h-a . - .f a.pr,val• Form 10-403 Revised 5/2.15 0RGINAL ? vi" I' ' ., r,, `. SE43115s unbtsmiint mide KRU 30-01 CTD Summary for Plugging Sundry (10-403) Summary of Operations: Well 30-01 is a Kuparuk A-sand producer well equipped with 31/2"tubing and 7"production casing. A rig work-over was completed in 2009 to isolate the production casing leak between 5,551' MD to 5,556' MD. Four laterals will be drilled to the north west of the parent well bore with the laterals targeting the different A sand lobes. These laterals will access reserves in the adjacent fault blocks targeting the Al, A2, and A3 sands. Prior to CTD operations,the 3-1/2"tubing tail will be perforated and the D nipple at 8,701' MD will be milled out to a 2.80"ID. The existing A-sand perfs will be squeezed with cement to provide a means to kick out of the 7"casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A-sand perfs in this manner. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 8,840' MD and set a mechanical whipstock in the 2.80"pilot hole to kick off at 8,840' MD.All four laterals will be completed with 2-3/8" slotted liner from TD with the final liner top located inside the 3-1/2"tubing tail. Using the maximum formation pressure in the area of 4674 psi in 3R-22,the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 4007 psi. CTD Drill and Complete 30-01 Lateral: Septem— be 0 Q 5 Y4fvi °/1 dr- Pre-CTD Work kites--q'/f 40 fe. entree /" ' "2w' r3 rPtUItV .4eCaj WO W,'// .0€ 1. RU Slickline: dummy off gas lift mandrels. ComItgra ,v,17-h f/0 fter/ 6.00, inp 2. RU E-line: Shoot 2' of holes in the 31/2"tubing tail at 8696' MD. i e ���f f� �el��Y'tf 3. RU Pumping Unit: perform infectivity test down the tubing. !� 4. RU Service Coil: Mill out D nipple and cement squeeze the A sand perforations up to a 44. tp the perforations in the tubing tail. 4 cCeff //e (cf ervef 5. RU Slickline: Tag top of cement and log. /�,'�� 1,004'Ceti 6. Prep site for Nabors CDR2-AC, including setting BPV. ln/€Il. Rig Work ✓ 49 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 30-01A Lateral(Al sand to north west) a. Drill 2.80"high-side pilot hole through cement to 8,840' MD b. Caliper pilot hole c. Set whipstock at 8,840' MD d. Mill 2.80"window at 8,840' MD. e. Drill 3"bi-center lateral to TD of 11,150' MD. f. Run 2%" slotted liner with an aluminum billet from TD up to 10,400' MD. 3. 30-01AL1 Lateral(A2 sand) a. Kick off of the aluminum billet at 10,400' MD. b. Drill 3"bi-center lateral to TD of 11,200' MD. c. Run 2%" slotted liner from TD up to 9,350' MD 4. 30-01AL2 Lateral (A2 & A3 sands) Page 1 of 2 8/13/2015 • • a. Kick off of the aluminum billet at 9,350' MD. • b. Drill 3"bi-center lateral to TD of 11,200' MD. c. Run 2%"slotted liner from TD up to 9,065' MD 5. 30-01AL3 Lateral(A3 sand) a. Kick off of the aluminum billet at 9,065' MD. b. Drill 3"bi-center lateral to TD of 10,500' MD. c. Run 2%" slotted liner from TD up to 8,730' MD, above the whipstock and in the 3- 1/2"tubing. 6. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Install GLV's. 3. Return to production. Page 2 of 2 8/13/2015 r KUP PROD • 30-01 ConocoPhillips s Well Attributes Max Angle&MD TD A ia/Si3,1{1C Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) ConocoPhi€6 - Fy 500292183600 KUPARUK RIVER UNIT PROD 52.62 3,700.00 9,173.0 ••• , Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 30.01,6/7/20153;45:34 PM SSSV:NIPPLE Last WO: 2/26/2009 34.98 8/5/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _.. ....., _ Last Tag: SLM 8,881.0 429/2015 Rev Reason:TAG,MANDREL ORIENTATION h pshkf 6/7/2015 t= sIl111 aaa Casing StringsHANGER 332 .,,I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread j CONDUCTOR 16 15.062 33.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.765 34.6 5,305.0 4,066.0 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 35.2 9,148.0 6,870.7 26.00 J-55 BTC CONDUCTOR;33.0-115.0 Tubing Strings Tubing Description String Ma...ID(in) Top(AKB) Set Depth(ft..'Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.990 33.2 5,399.8 4,129.6 9.30 L80 EUE8RD NIPPLE;511.0 I Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;2,928.2 33.2 33.2 0.20 HANGER C.I.W.TUBING HANGER 2.950 511.0 510.8 3.27 NIPPLE CAMCO2.875"'DS'NIPPLE 2.875 5,334.0 4,085.5 47.73 NIPPLE CAMCO 2.813"'DS'NIPPLE 2.813 5,377.0 4,114.4 47.86 LOCATOR LOCATOR 2.990 GAS LIFT;4,697.1 5,378.3 4,1152 47.86 SEAL ASSY SEAL ASSEMBLY w/2'SPACEOUT 3.000 --, Tubing Description String Mu...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection Straddle Packer I 3 1/21 2.9921 5,368.11 8,575.0 6,423.61 9.301 L-80 IEUE 8rd AB Mod Completion Details, ll Nominal ID Top(ftKB) Top(ND)(ftKB) Tap Incl(°) Item Des Com (in) 5,368.1 4,108.4 47.83 SLEEVE "HR"LINER SETTING SLEEVE 4.420 5,381.7 4,117.5 47.87 SBE SEAL BORE EXTENSION 4.000 GAS LIFT;5,287.0 x- 5,401.7 4,131.0 47.93 XO-Reducing CROSSOVER SUB 2.990 5,411.6 4,137.6 47.91 PACKER BAKER 4782-7"268 FHL PACKER 2.970 SURFACE;34.6-5,305.0 - 8,479.6 6,350.2 39.71 PACKER BAKER 4782-7"269 FHL PACKER 2.970 8,529.0 6,388.2 39.64 NIPPLE OTIS 2.813"'X'NIPPLE 2.813 amp NIPPLE;5,3340 8,568.5 6,418.6 39.55 OVERSHOT BAKER 7"x 3.625"POOR BOY OVERSHOT w/6.10" 3.620 SWALLOW Tubing Description 1 String Ma...l ID(in) !Top(ftKB) [Set Depth(ft..l Set Depth(ND)(...I Wt(Ib/ft) 1 Grade 'Top Connection TUBING Original 31/2 2992 8,5706[ 873601 65480 930 3-55 11 SLEEVE;5,368.1 LOCATOR;5.377.0 Completion Details Nominal ID ' Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) �I�I 8,652.2 6,483.3 39.41 PBR AVA PBR/LOCATOR 3.000 SEAL ASSY;5.378.3, 8,665.9 6,493.8 39.39 PACKER AVA RMS PACKER 3.000 SBE,5,361.7 i ' 8,701.4 6,521.2 39.34 NIPPLE CAMCO'D'NIPPLE 2.750 8,735.2 6,547.4 39.18 SOS SHEAR OUT SUB 2.992 y Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl �• Top(ftKB) I (ftKB) C) I Des I Corn I Run Date I ID(in) 44 9,000.0 11 6,754.3 38.18 FISH PIECE OF 3"JD DOG 1"x 1.5" 8/31/2008 0.000 PACKER;5,411.6 Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/f lif Top(ftKB) Bier(ORB) (ftKB) (ftKB) Zone Date t) Type Com PACKER;8,479.6 8,832.0 8,847.0 6,622.7 6,634.4 A-3,30-01 4/28/1989 12.0 IPERF 2 1/8"EnerJet;60 deg. ph 0. 8,850.0 8,866.0 6,636.7 6,649.3 A-2,30-01 4/28/1989 12.0 IPERF 2 1/8"EnerJet;60 deg. ph NIPPLE;8,529.0 IIV8,890.0 8,910.0 6,668.0 6,683.7 A-1,30-01 10/3/1988 8.0 (PERF 4.5"Csg Gun;45 deg. 111 ph Mandrel Inserts St T OVERSHOT;8,566.5 -I> on Top)TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com 2,9282 2,5042 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,258.0 3/21/2012 11:30 GAS LIFT;8,811.6 2 4,697.1 3,649.5 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,259.0 3/21/2012 6:00 3 5,287.0 4,053.9 Camco MMG 11/2 GAS LIFT OV RK 0.250 0.0 3/21/2012 4:30 PBR,8,652.2 ,'. 4 8,611.6 6,451.9 OTIS LBX 11/2 GAS LIFT OPEN 0.000 0.0 1/28/2009 4.30 PACKER,8,6659 Notes:General&Safety End Date Annotation NIPPLE;8,701.4 2/28/2009 NOTE:View Schematic w/Alaska Schematic9.D SOS;8,735.2 fl IPERF;8,832.0-8847.0- (PERF;8,850.0-8866.0 IPERF;8,890.0-8.910.0---- FISH; ,890.0-8.910.0FISH;9.000.0 PRODUCTION;35.2-9,148.0 W • • 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 Taskonsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the atricia r Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" t boxes are also checked, cross out that erroneous entry and initial it on both V 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 trici or Steve work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change Jenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. ` VG -0,,3 • • WELL LOG TRANSMITTAL DATA LOGGED %/114/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. July 15, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RdECEIVED AUG 1 3 261J Resubmit E-Set#25962 AO - - RE: Multi Finger Caliper(MFC) : 30-01 A. Run Date: 5/31/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett,Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 30-01 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21836-00 scAMIED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE A FIENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: &A-Six-Auk., / .� • • 2-5 9 Co 2, WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 4, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVWD DA1T L oGED /CI/ 15 Anchorage, Alaska 99501 i.K.BENDER ,SUN 18 2WS RE: Multi Finger Caliper(MFC) : 30-01 Run Date: 5/31/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 30-01 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21836-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 wog) . Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 6-4utedt Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned dudng the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done) RESCAN DIGITAL DATA OVERSIZED (Scannable) Color items: [3 Diskettes, No. E] Maps: [3 Grayscale items: Poor Quality Originals: Other: [] Other, No/Type Other items scannable by large scanner OVERSIZED (Non-Scannable) [3 Logs of various kinds Other TOTAL PAGES: '"~ "~ NOTES: ORGANIZED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL I~ATE: tsl Project Proofing Staff Proof Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS~ Scanned (done) PAGES: SCANNED BEVERLY BRE~-~HERYI. MARIA LOWELl. ReScanned (done) RE SCANNED BY i~RE N VINCENT SHERYL M4RIA LOWELL General Notes or Comments about this file: Quality Checked (done) Rev 1 NOT Sca nned.~pd • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS.F ~~ APR.:?' 1. operations Pertormed: Abandon ^ Repair Well ^~ Plug Pertorations ^ Stimulate ^ Other LJL I' ~ `' "„j~~~ Alter Casing ^ Pull Tubing Q ~ Perforate New Pool ^ Waiver ^ Time Extension~f~~' Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ • Exploratory ^ 188-073 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21836-00 ' 7. KB Elevation (ft): 9. Well Name and Number: ~ RKB 59' 30-01 ' 8. Property Designation: _. 10. Field/Pool(s): - ADL 25513 Kuparuk River Field /Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9173' feet true vertical 6890' • feet Plugs (measured) 8701' Effective Depth measured 9065' feet Junk (measured} 9000' true vertical 6805' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SURFACE 5246' 9-5/8" 5305' 4066' PRODUCTION 9089' 7" 9148' 6871' P rf ti d h M ' ' ' ' ' ~+~ ~ ~ ~~' `~~ ~~~ ~~ +~ ~~~ ora e on ept : easured depth: y 8832 -8847, 8850 , 8890 -8866 -8910 p ~ true vertical depth: 6623'-6634', 6637'-6649', 6668'-6684' Tubing (size, grade, and measured depth) 3-1 /2" , L-80, 5400' MD. Packers & SSSV (type & measured depth) 2 Baker FHL pkrs @ 5412' & 8480', AVA RMS pkr @ 8666' Camco DS nipple @ 511' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 246 1251 1943 -- 168 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ 'Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil Gas^ WAG^ GINJ^ WIND ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. sundry Number or NiA if C.O. Exempt: 309-028 Contact Ji nis @ 265- 1544 Printed Nam ~ EnniS Title Wells Engineer Signature ~ Phone: 265-1544 p~ Date ~ ~O Q'~ Pre a d ron Isu -Drake 263-4612 Form 10-4 Revised 04/2006 ~ , ., , , Submit Original Only ipp ~OtIOCO~'1'I~~IpS ~ ~~ Well. Attributes ~1J'L)hi}, Ifn~ Welbore APVU WI 'Fieltl Naml / ~~~n., n... Data 30-01 173 2126/2009 I 34.98 I 8/5/1988 Casing Description ,String 0... String ID ... Top (ftK8) Set Depth (f... Set Depth (ND) ... String Wl... String ... String Top Thrd CONDUCTOR 16 15.062 33 115 115.0 62.50 H-00 Casing Description ,String 0... String ID ... Top (ftK8) Set Depth (f... Set Deplh (ND) ....String Wt... String ... String Top Thrd SURFACE 9518 8-765 35 5,305 4,066.0 36.00 J-55 Casing Description String 0... String ID ... Top (ftK8) Set Depth (f... Set Depth (ND) ... String W[... String ... String Top Thrtl PRODUCTION 7 6.151 35 _ 9,148 _ 6,870.7 26.00 J-55 _ _ _ BTC Tubing. Strings Tubing Description _ _ String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (ND) .. String WI... String ... String Top Thrd TUBING 3112 2.990 33 5,400 4,130 9.30 L80 EUESRD Com letion De tails Top Depth (ND) Top Inc! Top (ftK8) (ftK8) (°) Item Desoiption Comment ID (in) 511 510.8 3 42 Nipple Camco 2.875"'DS' Nipple 2.875 5,334 4,085.5 47.73 Nipple Camco 2.813"'DS' Nipple 2.813 _ 5.377 4,114.4 _-__._- 47.86 Locator Locator _._._-- _. _ 2.990 I - 5.378 ' 'I 4,115.2 47.86 Seal Assembly Seal Assemby w! 2' spaceolrt 1 3.000 Tubing Description -String 0... Top (ftK8) (Sat Depth (f... (Sat Depth (ND) ... String ID ... (String Wt... IiString _. (String Top Thrd Straddle Packer ,. __ ( ( 3 1/2 2.992 5,368 1 8.575 ll 6 424 9.30 L-80 IEUE 8rd A __ _ B Mod Completion De Top Depth tails _ _ _ _ _ I - (ND) ToP Inc! p f~tK811 (HKB) To (°) Item Desniptlon CommaM ID (in) _ 5,368 4.1084 47.83 SLEEVE "HR Liner Setting Sleeve _ 4.420 5,382 4,117.5- _. - 47.87 SBE SBE - __ 4000 5,412r 4,137.5 47.72 PACKER Baker4762-7"26#FHL Packer _._ 2.970 8,480 6,350.2 39.74 PACKER Baker 4782-7" 26# FHL Packer 2.970 8,529 6,388.2 39.57 NIPPLE Otis 2.813"'X' Nipple w/RHC BALL/ROD 2.813 8,5691 6.418.6 39.52 OVERSHOT Baker 7" x 3.625" Poor Boy Overshot w/ 6.10" Swallow 3.620 Tubing Description String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING Original 31/2 2.992 8,571 8,736 6,548 _.. 9.30 J-55 Completion De tails --- Top Depth ~, (ND) ~~, ToP Inc! Top (HKB) (HKB) (°) Item DBSCription Comment ID (in) 8,652 6,4834 39.57 PBR AVA PBR/LOCATOR 3.000 8,6661 6,493.9 39.51 PACKER AVA RMS PACKER 3.000 8.701' &521.21 39.34. NIPPLE '~. CAMCO'D'NIPPLE 2.750 8,735 6,547.5 39.18 SOS 2.992 Other In Hole ( Wireline retrievable plugs, valves, pumps, fish, etc .) __ Top Depth. (TVD) Top Ind ~ Top (HKB) (HKB) (°I Description Comment Run DMe _ ID (in) 8,701 6,520.9 39.35'PLUG CA-2 BLANKING PLUG -CaC030N TOP OF PLUG 12/75/2008 0.000 9.000 6,754.3 38.18' FISH PIECE OF 3" JD DOG 1" z 1.5" 8/31/2008 0.000 1 Perforations 8 Slots - I Shot Top (rVD) Btm (fVD) Dens Top (ftK8) Btm (ftK8) '( (HK8) (HKB) Zone Date (sh Type Comment 8,832 8,847 ' 6,622.6 6,634.4 A-3, 30-01 4/28/1989 12.0 IPERF 2 1/8" EnerJet; 60 deg. ph 8,850 5,866 6.636.7 6,649.2 A-2, 30-01 4/28/1989 12.0 IPERF 2 1/8" EnerJet; 60 deg. ph 8.890 8,910 ' 6 668.0 6,683.7 A-1, 30-01 10/3/1988 i 8.0 IPERF 45" Csg Gun; 45 deg. ph Notes: General End Date ( & Safety Annotation '(2/28!2009 -NOTE VIEW SCHEMATIC wIAlaska Schematic9.0 I Mandrel Details -- - -- Top Depth Top Poft (TVD) Inc! OD Valve Latch Size TRO Run Stn To_p (HKB) (HKB) (°) Maka I Model (in) Serv Type Typo (in) (psi) Run Date Comm 1 2,928 2,504.0 47.95 Camco (MMG 1 1/2 GAS LIFT DMY RK 0 000 0.0 2/25!2009 2 4,697 3,649.5 47.37 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/25/2009 3 5,287 4,053.9 47.58 Camco MMG 1 1/2 GAS LIFT SOV RKP 0.000 1,500.0 2/25/2009 4 8,612 6,452.2 39.77 OTIS LBX 1 1!2 GAS LIFT OPEN 0.0001 0.0 1/28/2009 30-01 Well Events Pre and Post Rig DATE SUMMARY 1/4/09 PRE RWO T POT PPOT POT PASSED IC~POT PASSED PASSED IC - , - - - - - , , - , h ~ PASSED, FUNCTION TEST LDS -PASSED ~ ~ 1/28/09 MEASURED BHP ~i 5600' RKB: 2745 PSI. DUMP BAILED APPROX. 7' CaCO3 ON CA-2 PLUG @ 8702' RKB. PULLED DV @ 8611' RKB. READY FOR BPV /RIG. 2/12/09 POWERCUT 3.5" 9.3 PPF TUBING AT 8260'. UNABLE TO REACH FIRST FULL JOINT ABOVE PBR DUE TO BARITE SAG IN WELL. FLUID IS UNCIRCULATED BELOW TUBING LEAK AT 5600'. 2/15/09 ATTEMPT TO JET CUT TUBING WITH 2.5" POWERCUTTER BETWEEN GLM #6 AND PBR. UNABLE TO RUN POWERCUTTER THROUGH CUT TUBING JOINT AT 8260'. ATTEMPT TO CAILIPER TUBING WITH PDS CALIPER. TOOLS BECAME STUCK IN CUT TUBING STUB. INTENTIALLY PULL OFF WITH EL1NE AND LEAVE TOOLS IN HOLE. FISHING OPERATIONS UNDERWAY. 2/17/09 ATTEMPT TO FISH ELINE TOOLSTRING WITH CALIPER (50'OAL) FROM 7" CSG 12.6# MUD.TOP OF FISH 8190' ELINE~JNABLE TO LATCH. 2/24/09 RIG UP S/L ON NORDIC 3: GAUGED TBG TO 2.902" TO 475' SLM. GAUGED TBG TO 2.855" TO 5298' SLM. RDMO. 3/2/09 ASSISTED VALVE CREW IN REMOVING BPV. CMIT TBG x IA 3000 PSI, PASSED. TAGGED DRILLING MUD @ 8350 SLM, EST. 160' ABOVE RHC. IN PROGRESS. 3/3/09 SET CATCHER @ 5345' SLM. PULL SHEARED SOV AND REPLACED WITH DV @ 5287' RKB. PULLED CATCHER, HUNG UP IN DS NIPPLE @ 5334' RKB. WORKED FREE, ~ ~ POH. SLIP RETAINER BROKE LEAVING 3 SLIPS, CARRIER, AND BOTTOM OF ~ CATCHER IN HOLE. RAN MAGNET, RECOVERED ONE SLIP. IN PROGRESS. 3/4/09 ATTEMPTED RECOVER SLIPS WITH MAGNETS. UNABLE TO WORK 2.80" BELLGUIDE OR 2.77" LIB THROUGH 2.81" DS NIPPLE @ 5334' RKB. BAILED DRILLING MUD @ 8320' SLM. IN PROGRESS. 3/5/09 ATTEMPTED FISH SLIP STOP PARTS @ 8327' SLM; NO RECOVERY. IN PROGRESS. 3/6/09 ATTEMPTED FISH SLIP STOP PARTS @ 8232' SLM, NO RECOVERY. CONFIRMED BROKEN SLIP ACROSS TBG ON FISH. IN PROGRESS. 3/7/09 CONTINUED FISHING SLIP STOP PARTS @ 8233' SLM. RECOVERED SERRATED SECTION OF BROKEN SLIP. STILL MISSING LOWER HALF OF BROKEN SLIP, ONE FULL SLIP, CARRIER, AND BOTTOM SUB. IN PROGRESS. 3/8/09 CONTINUED FISHING SLIP STOP PARTS @ 8343' SLM; NO RECOVERY. BAILED MUD. CONFIRMED OVER TOP OF SLIP WITH 2.5 BAILER. IN PROGRESS. 3/10/09 BAILED MUD AND CONTINUE TO FISH SLIP STOP PARTS @ 8350' SLM. CONFIRMED AT SLIP WITH IMPRESSION BLOCK. (FISH STILL IN HOLE = 1 FULL SLIP, LOWER 4" OF ANOTHER SLIP, CARRIER RING, AND BOTTOM SUB ) 3/11/09 RECOVERED FULL SLIP W/ MAGNET, LOWER SUB OF BROKEN CATCHER SUB, & GRAPPLE. IN PROGRESS. 3/12/09 MADE SEVERAL ATTEMPTS TO FISH BROKEN SLIP, IN PROGRESS 3/13/09 ATTEMPT TO FISH SLIP, BAILED FILL FROM 8346' WLM TO 8362' WLM, IN PROGRESS 3/14/09 BAILED MUD FROM 8362'SLM TO 8372' SLM WITHOUT ENCOUNTERING DEBRIS; UNABLE TO FIND/RECOVER BROKEN PIECE OF SLIP OR PIECE OF CARRIER RING. 3/18/09 STANDBY FOR WEATHER IN MORNING (-39 DEG F, 15-18-MPH WINDS). PERFORMED BOPE TEST IN AFTERNOON. READY TO RIH IN A.M. 3/19/09 PERFORMED CLEAN-OUT TO HARD TAG 8525' RKB PUMPING SLICK SEAWATER AND DIESEL GEL AT 1.8-BPM (1:1 RETURNS THROUGHOUT JOB). LOADED TUBING FROM 8525' (RHC-PLUG AT 8529') TO SURFACE WITH 100% SLICK DIESEL. READY FOR SLICKLINE. 3/20/09 MIT-T AND IA TO 2500. GOOD TEST. PULLED BALL & ROD FROM 8529' RKB. IN PROGRESS. 3/21/09 PULLED DVs @ 2929' RKB, 4697' RKB & 5287' RKB, SET GLV @ 2928' RKB, 3/16"OV @ 5287' RKB, GLV @ 2928 IS WRONG TRO, NEW DESIGN BEING MADE UP NOW. IN PROGRESS. 3/22/09 SET GLV @ 4697' RKB, PULLED GLV @ 2928' RKB (VALVE WAS SET UP EW GLV @ 2928' RKB. IN PROGRESS. 30-01 Well Events Pre and Post Rig 3/23/09.P 1 i FD RH PL 1 BQDY Ccr~~9' RKB. RECOVERED 4"s OF SLIP FI~ROM SLIPSTOP CATCHER, BAILED DRILLING MUD F/ 8566' SLM TO 8620' SLM, IN PROGRESS. 3/24/09 C~AtI(;FD TB TO 2 7 " TO 2 81" DS NIPPLE Cad 5334' RKB UNABLE TO PASS BAILED DRILLING MUD f/ 8584' TO 8645' SLM. IN PROGRESS. 3/25/09 .BAILED FILL f/ 8630' TO 8675' SLM ON CA-2 PLUG (c7 8701' RKB. EST. 13' FILL REMAINING. IN PROGRESS. 3/26/09 BAILED FILL FROM 8674' TO 8684' WL, 8701' RKB. PULLED EQ-PRONG@ 8701' RKB. PULLED 2.75 CA-2 PLUG BODY FROM 8701' RKB, HUNG UP IN 2.81 DS NIPPLE @ 5334' RKB; LEFT PLUG IN NIPPLE. IN PROGRESS.. 3/27/09 ATTEMPTED PULL CA-2 PLUG BODY @ 5334' RKB, FAILED. ATTEMPTED DRIVE PLUG DOWN, FAILED. IN PROGRESS. 3/28/09 ATTEMPTED DRIVE PLUG BODY @ 5334' RKB -DOWN. ATTEMPTED PULL PLUG UP. NO APPARENT MOVEMENT. IN PROGRESS. 3/29/09 PULLED 2.75" CA-2 PLUG BODY f/ 5334' RKB. TAGGED @ 8951' SLM. COMPLETE. ConocQPhillips Time Log & Summary Wel/view Web Report+ng Report Well Name: 30-01 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 2/11/2009 12:01:00 AM Rig Release: 2/25/2009 9:00:00 PM Time Logs _Date From To Dur S. Depth E Depth_ Phase Code Subcode T Comment _ _ __ 2/10/2009 24 hr Summary Move Nordic Rig 3 off 1 E Pad toward 30 Pad. 03:00 09:00 6.00 COMPZ MOVE MOB P Moved Nordic Rig 3 off 1 E Pad towards ine road. 09:00 12:00 3.00 COMPZ MOVE MOB X Standby with rig crew waiting for airplane to take off and security to resume travel. 12:00 17:00 5.00 COMPZ MOVE MOB P Road Nordic Rig 3 from 1A Pad to CPF 3 17:00 19:00 2.00 COMPZ MOVE MOB X Standby with rig crew waiting for CPAI Feild Chan. a out. 19:00 23:30 4.50 COMPZ MOVE MOB P Road Nordic Rig 3 from CPF 3 to 30 Pad 23:30 00:00 0.50 COMPZ MOVE OTHR P Hang tree in cellar. 2/11/2009 MIRU on 30 Pad. Load pits w/ 12.6 ppg mud. RU hardline to kill tank and test to 4,000 psi. Lubricate out BPV, Open up well, Circ 12.6 ppg KWF and verify well dead. ND tree and adapter NU ROPE and Test 250/4,000 si. 00:00 01:00 1.00 COMPZ MOVE RURD P Accept Nordic Rig 3 @ 0001 hrs MIRU over 30-01, s of and level ri . 01:00 05:00 4.00 COMPZ RPCOM RURD P Spot tanks and load lubricator in pipe shed. Berm u .Sot kill tank. 05:00 08:30 3.50 COMPZ RPCOM COND P RU hard line. PT to 3,500. Load pits w/ 13.1 ppg and 12.0 ppg. Blend to 12.6 ppg. RU lubricator and pull BPV. 08:30 13:30 5.00 COMPZ RPCOM KLWL P SITP =1040 psi, SICP = 1040 psi. Circulated 310 bbls 12.6 ppg mud w/tubes through tbg leak @ 5600' MD and/or empty GLM #6 to kill char ed cs .leak. Bled pressure off to kill tank. ICP = 80 psi on tubing & 90 psi on IA. Shut down to unload vac trucks with mud and blend to 12.6 ppg. FCP 250 psi on tubing 0 psi on IA. Check pressure on well after shut down, 0 tubing, 70 psi on IA. After blending fluids to 12.6 ppg. Circulated 80 bbls @ 2 BPM, 360 psi on tubing and 0 on IA. Shut down, monitored well and let equalize. After 30 min. pressure on tubin 0 and IA 0. Well dead. 13:30 14:00 0.50 COMPZ RPCOM NUND et PV. ow down all lines and ND circulatin lines. 14:00 16:30 2.50 COMPZ RPCOM NUND P ND tree. Install test tool in BPV. ~.~~ ~r~~: '~ of 14 Time Logs ____ _ Date _ ___ From To Dur S. De th E. De th Phase Code Subcode T Comment 16:30 20:00 3.50 COMPZ RPCOM NUND P NU 13 5/8 BOP 20:00 00:00 4.00 COMPZ RPCOM BOPE P Test BOP and . hoke Manifold @ 250/4,000 psi. Choke valve # 11 Failed/Passed. 24 hr Notice was given @ 0900 hrs on 2-10-09, and Witness of test was waived by Jeff Jones @ 1700 hrs on 2-10-09. 2/12/2009 Continue to Test BOPE. Pull Test plug and BPV. BOLDS. MU landing Jt and unland hanger. Attempt to Pull seals from PBR and Circ BU. RU Eline and RIH w/ string shot to 8,365' unable to get any deeper. POOH w/ same. RIH w/ 2.5" Power cutter to 8,325' and cut 8,260' POOH w/ Eline. 00:00 03:30 3.50 COMPZ RPCOM BOPE P Continue to Test BOP and Choke Manifold @ 250/4,000 psi. Test Annular 250/3,500 psi. 24 hr Notice was given @ 0900 hrs on 2-10-09, and Witness of test was waived by Jeff Jones @ 1700 hrs on 2-10-09. 03:30 05:00 1.50 COMPZ RPCOM OTHR P Bleed off IA Pressure of 250 psi. Load Control line spooler. Monitor IA 05:00 06:00 1.00 COMPZ RPCOM OTHR P Trouble shoot Obstruction in choke line, found new HCR valve locked out. Retest blinds and valves 2 5 & 6 to 4000 si. 06:00 08:00 2.00 COMPZ RPCOM PULL P Pull blankin lu~c &BPV. Install landing joint in tubing hanger. BOLDS 08:00 10:30 2.50 COMPZ RPCOM PULL P Attem t to ull tubing from Baker PBR 8652' ~y pulling 114K# (80% of yield plus 35K for Top Drive. Hanger is loose and coming out of seat but could not pull seals from PBR. Est. circulation 1 BPM w/470 psi ICP while pulling on tubing still not successful FCP 380 psi. Increased rate to 2 BPM, 570 psi. Continue to work pipe up and down at max ull until E-line unit arrives. 10:30 15:30 5.00 COMPZ RPCOM ELNE P RU E-line unit and tools for string shot. RIH with string shot to 8365' could not get any deeper. Discussed options with Engineer. POOH with string shot. RD string shot and prep for Power Cutter. 15:30 20:00 4.50 COMPZ RPCOM ELNE T Waiting for 2.50" Power Cutter to come from Deadhorse. Stalled behind Doyon 14 rig move -Rig had flat tire. 20:00 00:00 4.00 COMPZ RPCOM ELNE P RU wireline w/ 2.50" Power cutter TBG flowing 5 gal/ 4 min. 10.1 ppg fluid) RIH w/ cutter to 8,365' and cut 8,260' wlm. Fire shot and POOH. ® ~ ~ -~ ~ ~r~~ 2 €sf 1~ r~ ,• Time Logs Date From To Dur S Depth E. Depth Phase Code Subcode T Comment ___ 2/13/2009 _ __ ___ ___ 2a hr Summary Continue to POOH w/ ELine and RD same. PU and verify pipe free. Circ 450 bbls of KWF @ 9.5 bpm @ 2,430 psi. Condition mud in pits. and Circ. 1.5 hole vol @ 9.5 bpm. Monitor well. POOH w/ 3.5" Decompletion and Rih w/ fishin E ui . 00:00 01:00 1.00 COMPZ RPCOM ELNE P Continue to POOH w/ Eline and RD same. 01:00 02:30 1.50 COMPZ RPCOM CIRC P PU and verify TBG cut. Break circ @ 4 bpm, 870 psi. Stage up to 9.5 bpm @ 2,430 psi. Circ 450 bbls or 7,718 total strokes. Hole vol = 290 bbls or Surf to surf 4,974 strokes Returning Mud wt @ 3,000 strokes 13.2 ppg w/ 47 visc, 4,000 strokes 14.8 ppg w/ 55 visc, 5,500 strokes 12.4 ppg w/ 41 visc, 6,500 strokes 12.5+ w/ 40 visc. Hole vol = 290 bbls or Surf to surf 4,974 strokes Obtain Slow pump rates: pump 1 @ 34 spm 430 psi; 51 spm @ 500 psi; Pump 2 @ 34 spm @ 420 psi; 51 s m 500 si. 02:30 03:00 0.50 COMPZ RPCOM OWFF P Monitor well -Static 03:00 07:00 4.00 COMPZ RPCOM COND P Condition pit vol 501 bbls: 12.5 ppg w/ 50 visc, PH of 9 71 de rees. 07:00 08:00 1.00 COMPZ RPCOM CIRC P Circulated 1.5 hole vol. (441 bbls.) 12.5 ppg w/50 visc, PH of 9 @ 71 degrees 9 BPM w/1940 psi. Returning mud @ 4300 stks = 13.4 ppg w 46 visc. 5800 stks = 12.5 ppg w/48 visc, 7600 stks = 12.5 ppg w/50 visc. 08:00 08:30 0.50 COMPZ RPCOM OWFF P Shut down pump, let equalize. Monitor well for 30 min. static 08:30 12:00 3.50 8,260 6,474 COMPZ RPCOM PULL P Pull tb han er to ri floor, break out and LD same & Landing jt. MU control line spooler. POOH laying down 3 1/2" tubing, spooling up control line. LD SSSV, RD spooler. Recovered 31 SS Bands. 12:00 00:00 12.00 6,474 0 COMPZ RPCOM PULL P Continue POOH laying down 3 1/2" tubin and GLMs. 3/8" hole found 4' down from collar on jt 172 @ 5,625'+/-. Tubing bodies were in good condition w/some coupling corrosion f/ jt # 138, 172, 173, 175, 177, 180, and182. Power cut was belled to 4.125". recovered 2.48' of jt # 254 2/14/2009 Clean and clear floor. Change over to 3 1/2 DP Equip. MU BHA#1, RIH PU 3 1/2 DP to TOF @ 6,280' Dress off and en a e. Pull off fish. CBU and POOH chan a ra le and RIH and en a e fish. 00:00 02:30 2.50 0 0 COMPZ RPCOM OTHR P Clean and clear Rig floor. Change over to 3 1/2 DP Equip. Kick out 3 1/2 TBG. Set wear rin w/ 6.25" ID. P~tc~~ ~ of'1~ i • Time Logs Date From To Dur S Depth E. Depth Phase Code Subcode__ T_ Comment -- 0 214 COMPZ RPCOM PULD P MU 6" x 3.5" ID sizin shoe, Bushing, 5.75" OD OS w/ 3 1/2 Grapple and Pack off control, LBS, Fishing Jars, 6 - 4.75" OD DC's, POS w/ 1 13/16" ID. 02:30 10:00 7.50 214 8,180 COMPZ RPCOM TRIP P RIH w/ BHA #1 PU 3 1/2 DP f/ 214' to 8180' started getting soft, stacking out. 10:00 13:00 3.00 8,180 8,245 COMPZ RPCOM FISH P MU TD. Circulated with 4 BPM @ 370 si down to top of fish, tagged @ 8240' Obtained peramiters, down wt 135K Up wt 85K. Free rotating wt torque 4K ft lbs. @ 70 RPMs. Dressed up top of 3 1/2" fish, lowered down 4', attem tin to work stub thru packoff and into grapple. Unable to et thru ackoff and into ra le to latch onto fish. 13:00 14:00 1.00 8,245 8,230 COMPZ RPCOM CIRC P PU off fish, circulated bottoms up @ 7 BPM w/2400 si 14:00 14:30 0.50 8,230 8,230 COMPZ RPCOM TRIP P Blow down TD. Rig up floor for pulling out of hole. POOH standing back drill i e. 14:30 19:00 4.50 8,230 214 COMPZ RPCOM TRIP P POOH f/ 8,230' to 214' 19:00 20:00 1.00 214 0 COMPZ RPCOM PULL P Stand back BHA #1, break down overshot and found to have rotated w/ ra le and dulled. 20:00 21:00 1.00 0 214 COMPZ RPCOM PULD P Change out grapple and add OS ext. to BHA #2 and RIH to 214'. 21:00 23:30 2.50 214 8,156 COMPZ RPCOM TRIP P RIH w/ BHA #2 on 3 1/2 DP f/ 214' to 8,156' 140k u wt and 90k do wt. 23:30 00:00 0.50 8,156 8,245 COMPZ RPCOM FISH P EST parameters: 140k up wt 90k do wt w/pump off. 123k up wt 87k do wt w/ pump on. Free tq 4,000 ft/Ibs @ 15 rpm. SPR Pump 1 33 spm @ 930 psi, 51 spm @ 1,070 psi. Pump 2 33 spm @ 930 psi, 51 spm @ 1,070 psi. Engage TOF @ 8,240' and swallow over to 8,245'. 2/15/2009 Jar on fish and CBU. Release off fish and POOH. MU OS and RIH PU 3 1/2 8rd TBG to 6,673' 00:00 00:30 0.50 8,245 8,245 COMPZ RPCOM CIRC P Circulate thru GLM @ 8,611' 00:30 06:30 6.00 8,245 8,245 COMPZ RPCOM JAR P Jar on fish @ 25k osw and dead pull to 50k osw. with no movement. Circulating 3 bpm @ 1,310 psi for 1 hole vol. Attempt to pressure up w/ 50k over pull w/ no luck -leak off on IA @ 1,131 psi w/TBG pressure @ 1,800 psi. Shut down pump and Jar w/ no movement. Circulate @ 1 bpm @ 960 psi to keep fluid from freezing while continuing to jar the same. Loading pipe shed w/ 3 1/2 8rd com letion strin . 06:30 07:30 1.00 8,245 8,245 COMPZ RPCOM OTHR P Shut down pump. Released overshot. Blow down TD. Inspect derrick. Fade 4 of 1~ n Time Logs _ _ _ Date From To Dur S De th E. Depth Phase Code Subcode T_ Comment _ 07:30 13:30 6.00 8,245 0 COMPZ RPCOM TRIP P POOH standing back workstring. Stand back drill collars, LD BHA. 13:30 15:00 1.50 0 0 COMPZ RPCOM OTHR P Clean rig floor. Shuffle pipe in derrick to mak r r 15:00 00:00 9.00 0 6,673 COMPZ RPCOM PULD P MU 3 1/2" Overshot w/6' handling up on 3 1/2" 8rd EUE tubing. Picking up tubing and RIH w/ 210 jts to 6 673'. 80k u wt, 55k do wt 2/16/2009 Continue to PU and RIH f/ 6,673' w/another 49 jts to 8,240' Engage fish and Circ 1 TBG Vol. RU Eline for power cut below GLM @ 8,611', RIH to TOF and was unable to get thru. Release OS and POOH.RU Eline and RIH w/ PDS Memo Cali er Tools. 00:00 02:30 2.50 6,673 8,251 COMPZ RPCOM PULD P Continue to PU and RIH f/ 6,673' w/ another 49 jts to 8,231' and space out w/ 20' of pups and engage fish @ 8 240'. Pull 25k osw of 90k and land in sli s. 02:30 03:30 1.00 8,251 8,251 COMPZ RPCOM CIRC P Circulate 75 bbls @ 3 bpm @ 1,200 si. 03:30 11:00 7.50 8,251 8,260 COMPZ RPCOM ELNE T RU SWS and MU 2.5" Power cutter and RIH stopping occasionally to circulate and clean hole for tools to fall. Could not get tools past 8260' (top of 3 1/2" tubing. Attempted to um tools thru stub by setting down on tubin stub um in 3 BPM w/1500 si. No movement. 11:00 12:00 1.00 8,260 8,260 COMPZ RPCOM ELNE T Move sheave from elevators to derrick leg. Change to longer bails. Picked up on tubing to 35K over string wt. and attempt to get Power Cutter thru No movement. Attempted same with different wt on tubing. No luck. Set down and stacked 5K on tubing and attempt to et thru with no luck. 12:00 13:00 1.00 8,260 8,260 COMPZ RPCOM OTHR T Move sheave back to elevators to keep wireline form rubbing hose on the wa out. 13:00 14:00 1.00 8,260 8,260 COMPZ RPCOM ELNE T POOH with SWS, RD tools and move to the side for pulling tubing. Switch bails back to the short set. 14:00 15:30 1.50 8,260 8,260 COMPZ RPCOM CIRC P Circulate bottoms up to condition hole. ICP = 1700 psi @ 8 BPM. One heavy spot circulated out (13.0 ppg) one light spot (12.2 ppg) FCP = 1460 psi. 12.5 ppg 54 visc in, 12.5 54 visc out. 15:30 22:00 6.50 8,260 12 COMPZ RPCOM TRIP P Blow down TD. POOH standing back 3 1/2" tubin f/ 8,260' to 12' 22:00 22:30 0.50 12 0 COMPZ RPCOM PULD P Break down OS, Clean rig floor. 22:30 00:00 1.50 0 0 COMPZ RPCOM ELOG P Held PJSM, RU SWS and MU PDS Memo Cali ertools. RIH. 0 COMPZ RPCOM 2/17/2009 Continue to RIH w/ PDS Memory Caliper Tools on Eline to TOF TBG Stub @ 8,240'. Stuck in TOF. Pull out of ro a socket. RIH w/ SLK line and unable to en a e. RIH w/ OS on DP to 8,206'. -- -._ .............._ ~~ 5 rsf ~~ ~~ ... r~ • Time Logs --- Date_____ From To Dur S _ Depth E. D~th Phase_ _ Code Subcode T Comment 00:00 01:00 1.00 COMPZ RPCOM ELOG P Continue to RIH w/ PD5 Memory Cali er tools. Stuck in TOF. 01:00 04:00 3.00 COMPZ RPCOM ELOG T Work tools and was uable to pull free from TBG Stub @ 2,400 lbs. Wait for Caliper tool to trip and still unable to pull free. Pull out of rope socket 8,190' 3,2001bs. 04:00 06:00 2.00 COMPZ RPCOM OTHR T Change over to 3 1/2 DP equipment while waitin for overshot ra le. 06:00 09:00 3.00 COMPZ RPCOM OTHR T Service rig and top drive. Waiting on Slickline equipment to fish caliper tool. 09:00 11:00 2.00 COMPZ RPCOM RURD T PJSM. RU Slickline 11:00 13:00 2.00 COMPZ RPCOM FISH T RIH with SL overshot to fish tali er tool. RIH to 8192' SL measurement, zero at rig floor. Unable to get much action on the BHA due to low speed caused by the mud and deposits in the well. Could not latch fish. ~ POOH with sli ckline fishin~FlA #1. 13:00 15:00 2.00 COMPZ RPCOM FISH T Add addition stems for weight and RIH to 8192'. Unable to get much action. POOH. 15:00 16:00 1.00 COMPZ RPCOM RURD T RD slickline. 16:00 16:30 0.50 0 234 COMPZ RPCOM PULD T PJSM. MU Baker fishing assembly #4 to be run on 3-1/2" DP. 16:30 20:30 4.00 234 5,830 COMPZ RPCOM TRIP T RIH w/BHA #4 f/ 234' to 5,830' 102k u wt, 73k do wt. 20:30 21:30 1.00 5,830 5,830 COMPZ RPCOM CIRC T Circulate to condition hole vol. w/ 1.5 hole vol. @ 8 bpm @ 2,050 psi ICP w/ 1,900 si FCP. 21:30 22:30 1.00 5,830 8,075 COMPZ RPCOM TRIP T Blow down Top drive. Continue to RIH f/ 5,830' t/ 8,075' 125k up wt, 92k do wt. 22:30 23:30 1.00 8,075 8,171 COMPZ RPCOM CIRC T Kelly up and wash down f/ 8,075' to 8,171' @ 8 bpm @ 2,850 psi ICP and CBU. Obtain SPR's: Pump 1 @ 1 bpm @ 710 psi, 2 bpm @ 820 psi, 3 bpm @ 930 psi. Pump 2 @ 1 bpm @ 680 psi, 2 bpm @ 810 psi, 3 bpm @ 920 psi. Rot wt 106k @ 17 rpm's @ 4,000 fUlbs. Pump on @ 1 bpm @ 690 psi. 120k up wt, 90k do wt. Pum off 128k u wt, 94k do wt. 23:30 00:00 0.50 8,171 8,206 COMPZ RPCOM FISH T wash down f/ 8,171' to 8,206' @ .5 b m 490 si. 2/18/2009 Continue to attempt to Fish eline tools to 8,215'. POOH and laydown 30' of fish. Change grapple and RIH to TOF 8,224', En a e and POOH. La down 8' of fish for a total of 38' recovered. MU and RIH w/ BHA # 6 00:00 01:30 1.50 8,206 8,215 COMPZ RPCOM FISH T Continue to wash to 8,215' and set down 5k. Attem t to en a e fish. 01:30 02:00 0.50 8,215 8,178 COMPZ RPCOM PULD T POOH f/ 8,215' and Lay down 2 singles t/ 8,178' and Blow down Top drive. 130k u wt, 95k do wt. 02:00 07:00 5.00 8,178 0 COMPZ RPCOM TRIP T Continue to POOH f/ 8,178' to surface. Time Logs _ _ Date From To Dur S De th E. De th Phase Code Subcode T Comment 07:00 09:00 2.00 0 234 COMPZ RPCOM PULD T At surface with artial fish. Retrieved Eline running tool portion of fish down to and including the x-over below the CCL. X-over box on the bottom has stripped out thread. The remaining fish is the PDS memory tool with a knuckle joint and shock absorber on top. Total remainin len th f fi h is 20'. Lay down fish and RU up with a 1.75" grapple (shock absorber OD) to make an attempt to retreive remainin fish. 09:00 10:00 1.00 234 4,600 COMPZ RPCOM TRIP T RIH with fishing BHA #2 to 4600'. 10:00 12:00 2.00 4,600 4,600 COMPZ RPCOM SVRG P Slip and cut drill line. 12:00 13:00 1.00 4,600 8,177 COMPZ RPCOM TRIP T Continue RIH with fishing BHA #2 to 8177' 13:00 14:00 1.00 8,177 8,200 COMPZ RPCOM FISH T At 8177', up wt = 123 K#, down wt = 87 K# while pumping 2 bpm @ 970 psi. Up wt = 135 K#, down wt = 90 K# without pumping. RIH pumping and tag top offish at 8224'. sit down 4 K#, PUH no over ull. RIH rotating 20 RPM, work down to 8229' sit down 2 K# Try to PUH, 8K overpull. Sit back down, pick and came free with 12 K# over u-I. PUH to 8200' 14:00 15:30 1.50 8,200 8,200 COMPZ RPCOM CIRC T Drop dart, open pump out sub with 2600 psi. Circulate hole volume 6 b m 1690 si. 15:30 19:30 4.00 8,229 234 COMPZ RPCOM TRIP T Blow down Top Drive, POOH with fishing BHA# 5, standing back DP f/ 8,229'. 135k u wt. 19:30 20:00 0.50 234 0 COMPZ RPCOM PULD T POOH w/ BHA # 5 and laydown 8.35' of fish Recovered 1.75" OD Shock Sub, Knuckle jt, Battery housing, memory sub, and SDX Knuckle jt. w/ dutch man of 9116" to 5/8" OD - Bod rod of Centralizer arted 20:00 21:30 1.50 0 0 COMPZ RPCOM OTHR T Clean rig floor and prepare for weekly BOP Test -waiting for AOGCC to return update call -discussed w/ Chuck Scheve and decided to Preform weekly on 2-19-09 as we would be able to ive 4 hr notice as we started to POOH. 21:30 00:00 2.50 0 578 COMPZ RPCOM PULD T MU and RIH w/ 6" x 4.875" ID Flat bottom rotary shoe, 12 jts 5.75" O D _ Wash ipe, Wash over boot basket, LBS, Jar, 6 - 4.75" OD DC's to 578'. ~.~ ~_._~~ F~~L~L° 7 of 1=i Time Logs - ----~ Date From To Dur S. Depth E. D~th Phase Code Subcode T Comment_ 2/19/2009 24 hr Summary Continue to RIH w/ BHA # 6 on 3 1/2 DP and wash over WL fish and 3 1/2 TBG to top of GLM @ 8,611'. POOH and Conduct week) BOP test. 00:00 02:00 2.00 578 1,742 COMPZ RPCOM TRIP T RIH w/ BHA #6 f/ 578' to 1,742' on d ca 02:00 07:30 5.50 1,742 8,222 COMPZ RPCOM TRIP T Install Check valve between stands 12 n 1 .Continue to RIH f/ 1,742 to 8,222' 07:30 09:30 2.00 8,222 8,222 COMPZ RPCOM CIRC T Circulate 2.5 hole volumes to condition mud. Pumping 7 bpm @ 2350 si. 09:30 13:00 3.50 8,222 8,593 COMPZ RPCOM WASH T Up wt = 135 K#, down wt = 84 K# without pumping. Up wt = 115 K#, down wt = 83 K# while pumping 4 bpm @ 1250 psi. RIH pumping 4 bpm, not rotating. Tagged at 8238' (RKB correction 8245' . PU and tag again at 8238' PUH, slowly rotate while RIH, run in ast 8238' without seein any weight than e. Pum ressure increased 1 4 si. Rotating at 50 rpm washing down at 5 ft/min. Stop rotating, washing down at -3 ft/min. Continue to wash over while rotating at 50 rpm and pumping 4 bpm. Wash down to 8593' (RKB correction 8600' and tag down 4 K# and torque increased. Shut down rotation. PU and sit down 5 K# several times while pumping, but not rotating, unable to work wash string any dee er. 13:00 14:00 1.00 8,593 8,585 COMPZ RPCOM CIRC T PU to 8585'. Circulate bottoms up, 6 bpm @ 2150 psi. Recovering Wt material from fall out of mud. 14:00 20:00 6.00 8,585 578 COMPZ RPCOM TRIP T POOH with the wash over BHA, standin back the 3-1/2" DP. 20:00 21:30 1.50 578 0 COMPZ RPCOM PULD T POOH standing back 5 3/4" Wash Pi e. 21:30 00:00 2.50 0 0 COMPZ RPCOM BOPE P Pre are for weekly BOP Test, set test lu .Test BOP equipment @ 250/4,000 psi and Annular @ 250/3,500 si. 2/20/2009 Continue to Conduct weekly BOP Test. Set wear ring, MU BHA # 7 and RIH to 5,893' Cut 3 1/2 TBG and POOH, La down Fish and Wash i e. RU to RIH w/ Cali er Lo on Slickline. ~'~€~e ~ of 14 r • Time Logs __ D_a__t_e __ From To Dur S De th E. De th Phase Code Subcode T Comment __ __i 00:00 01:30 1.50 0 COMPZ RPCOM BOPE P Continue to Test BOP Equipment. Conduct draw down : Start @ 3,000 psi end @ 1,700 psi; 200 - 28 sec., FR @ 2:26. N2 - 4 @ 2,300 psi. 24 hr notice was given to AOGCC @ 0645 hrs on 2-18-09 and updated @ 2000 hrs on 2-18-09. Return call from Chuck Scheve recv'd @ 2100 hrs -discussed making wash over run and conducting test on 2-19-09 - Call as we start off bottom giving them a 4 -5 hr notice. Update called in @ 14:00 hrs on 2-19-09 and Witness of Test was waived by Lou Grimaldi. 01:30 02:00 0.50 COMPZ RPCOM OTHR P Set wear ring w/ 6.25" ID. 02:00 04:00 2.00 0 570 COMPZ RPCOM PULD X MU 6" OD Outside cutter on 5 3/4 Wash Pi a and RIH to 570'. 04:00 11:00 7.00 570 8,200 COMPZ RPCOM TRIP X RIH w/ BHA # 7 f/ 570' to 8200'. Up wt = 115 K#, down wt = 85 K# while pumping. Up wt = 130 K#, down wt = 90 K# without pumping. Hanging wt = 112K# while rotating 40 rpm @ 5500 ft#. Circulate DP volume, 1 bpm @ 8990 si. 11:00 13:00 2.00 8,200 8,520 COMPZ RPCOM FISH X RIH to 8587'. PUH @ 125 K#, pumping 1 bpm @ 900 psi to 8566' with 5 K# over pull. RIH to slackoff wt, start rotating 40 rpm @ 5500 ft#, pumping 1 bpm @ 950 psi. Start picking up in small step to engage tubing collar with the dogs and activate cutting blades. Continue to pick up in small steps past the original mark at 8566'.. Stop rotating and ick to 8520' with 125, K#. 13:00 14:00 1.00 8,520 8,520 COMPZ RPCOM CIRC X Circulate bottoms up, 6 bpm @ 2100 si 14:00 19:00 5.00 8,520 570 COMPZ RPCOM TRIP X POOH with standing back 3-1/2" DP. 19:00 22:30 3.50 570 0 COMPZ RPCOM PULL X Laydown 2 Its of 5 3/4 WP and Recover the remaining WL tools from TBG stub -TBG stub rolled inward _ durin the dress off TBG flare from Power cutter. Continue to POOH w/ 3 1/2 TBG = 324' recovered. Continue to POOH laying down 10 ~ts 5 3/4 WP. 22:30 23:00 0.50 0 0 COMPZ RPCOM OTHR P Send Baker WP Equipment. 23:00 00:00 1.00 0 0 COMPZ RPCOM SLKL P Held PJSM w/ HES and PDS. Bring TOOLs and Begin to RU for Caliper to F'z=.r~~ 9 €~f f Time Logs _ __ Date From To Dur S Depth E. Depth Phase Code Subcode T Comment _ _ 2/21/2009 __ 24 hr Summary Continue to RU and RIH w/ Caliper LOG on Slickline f/ 8,400'. Log out of the hole. PU and RIH w/ Test Packer to 8,500 and Test CSG. Locate holes in CSG between 5,551' and 5,556'. POOH w/ Test PKR. PU and RIH w/ Straddle PKRs. 00:00 03:00 3.00 0 0 COMPZ RPCOM SLKL P Continue to RU for Caliper log. RIH to 8,400'. 03:00 06:00 3.00 0 0 COMPZ RPCOM SLKL P Log up to surface. RD HES and PDS Cali er to in tools. 06:00 07:00 1.00 0 0 COMPZ RPCOM RURD P LD PDS tools and RD slickline unit 07:00 07:30 0.50 0 0 COMPZ RPCOM SVRG P Service block, swivel and crown. 07:30 08:30 1.00 0 230 COMPZ RPCOM PULD P PU amd MU test acker and drill collars 08:30 13:00 4.50 230 8,465 COMPZ RPCOM TRIP P RIH to 8465', up wt = 140 K#, down wt = 90 K#. 13:00 00:00 11.00 8,465 5,545 COMPZ RPCOM PRTS P Set packer w/ 25 K#, pressure test below acker to 2500 psi: PASSED PUH to 5908', set packer, pressure test below pac cer to 2500 psi: PASSED PUH to 5813', set packer, pressure test annulus above packer; FAILED. Pressure test below to 2500 psi: PASSED PUH to 5716', set packer, pressure test annulus above packer; FAILED. Pressure test below to 2500 psi: PASSED PUH to 5620', set packer, pressure test annulus above packer; FAILED. Pressure test below to 2500 si: PASSED PUH to 5522' set acker ressure test annulus above acker GOOD. Pressure test below to 2500 psi: FAILED RIH to 5615', set packer ,pressure test below to 2500 si in 5' t assed. PU to 5545' and pressure test below to awa 0.6 b m 1250 si. 2/22/2009 Continue to POOH w/ Test PKR. RIH w/ DP and PU Storm PKR, Set PKR @ 99'. Attempt to test -need more wt below. POOH w/PKR and RIH w/ DP to 1,546'. PU and RIH w/ PKR to 99' and set and test.- -good test. ND BOPE and TBG Spool. Change Pack off and Replace TBG spool. PT pack off to 3,000 psi - -good test. NU BOPE. 00:00 02:30 2.50 5,545 5,545 COMPZ RPCOM PRTS P PT annulus above packer @ 2500 psi for 30 minutes and HELD. ' B rrected de th. Blow down test equipment and RD test a ui ment. Pre are to POOH. 02:30 04:00 1.50 5,545 2,687 COMPZ RPCOM TRIP P POOH standing back f! 5,545' to 2,687' Faye 1~ of 1~ r' Time Logs _ _ _ _ __ _ ____ Date From To Dur S De th E. De th Phase Code Subcode T Comment 04:00 08:00 4.00 2,687 0 COMPZ RPCOM PULD P Continue to POOH laying down 3 1/2 DP, DC and test acker 08:00 09:30 1.50 0 0 COMPZ RPCOM SVRG P Clean rig floor and kick out DP. 09:30 11:30 2.00 0 0 COMPZ RPCOM TRIP T RIH w/ 3-1/2" DP and storm packer to 895'. Set storm packer @ 100'. Would not ressure test. POOH. 11:30 13:30 2.00 0 1,661 COMPZ RPCOM TRIP P RIH w! 3-1/2" DP and storm packer to 1661'. Set storm acker at 99'. 13:30 14:30 1.00 1,661 1,661 COMPZ RPCOM PRTS P Pressure test above storm acker to 500 si/ 15 min. Bleed down line. 14:30 17:00 2.50 1,661 1,661 COMPZ RPCOM NUND P ND BOPE. 17:00 21:30 4.50 1,661 1,661 COMPZ RPCOM NUND P Continue to Bleed off OA pressure, and ND 7 1/16 x 11"TBG Spool. Install New Pack off and Install New 7 1/16" x 11" BG s ool. est pac off and void @ 3,000 psi for 30 minutes. Good Test. 21:30 00:00 2.50 1,661 1,661 COMPZ RPCOM NUND P NU BOPE 2/23/2009 Continue to NU BOPE, Test Lower TBG head flange, and Shell Test BOP @ 4,000 psi. RIH and Release Storm PKR and POOH. RIH w/ 3 1/2 Straddle Com letion. 00:00 02:30 2.50 1,661 1,661 COMPZ RPCOM NUND P Continue to NU BOPE. 02:30 03:00 0.50 1,661 1,661 COMPZ RPCOM PRTS P Shell Testa ainst strom packer, blind rams, and lower TBG head flan a 2,000 si.- ood test. 03:00 04:30 1.50 1,661 1,661 COMPZ RPCOM BOPE P Set Test lu and Shell Test BOP @ 250/4,000 psi• -Good test. RD Test equipment and Blow down. Pull test lu . 04:30 05:00 0.50 1,661 1,661 COMPZ RPCOM SFTY P held PJSM w/Crew and packer hand for releasin storm acker. 05:00 06:00 1.00 1,661 0 COMPZ RPCOM TRIP P RIH and Retrieve Storm PKR and POOH. 06:00 07:30 1.50 0 0 COMPZ RPCOM OTHR P Swap handling equipment. Prepare straddle packer completion e ui meht 07:30 15:00 7.50 0 3,211 COMPZ RPCOM RCST P PU and MU straddle FHL packers with 3-1/2" tubing spacer. 3.5" tubing was previously used as a work string in the 12.5 ppg mud. Each stand needed to be steamed to allow the drift to ass. 15:00 15:30 0.50 3,211 3,211 COMPZ RPCOM OTHR P Change over to DP Equipment 15:30 00:00 8.50 3,211 8,541 COMPZ RPCOM RCST P RIH drifting 3 1/2 DP and CBU every 1,000' with staddle packer., com letion to 8 541'. 115k up wt, 83k do wt. 2/24/2009 Shear out OS on TBG stub. CBU, change hole vol. f/ 12.5 ppg to 9.6 ppg brine, POOH LD 3 1/2" DP, slipped and cut drill line, RIH with 3 1/2" as lift com letion to 5,372'. 00:00 00:30 0.50 8,541 8,567 COMPZ RPCOM TRIP P RIH and shear out OS and NO-GO on TBG Stub ar7 8,1571' w/Mule shoe @ 8,577' ORKB Depth. PU to 8, 567'. ~~ fear.;e 1'~ €s~ S~ Time Logs --- - - ` Date From To b ur S_ Depth E. Depth Phase Code -- Subcode - T __ Comment _ 00:30 03:30 __ _ 3.00 8,567 8,567 COMPZ RPCOM CIRC P _ Circulate thick fluid from 8,567' around straddle packer asst' @ .5 b m 800 si and increasin um rate as pressure dropped to 3 b m 950 si. 03:30 04:00 0.50 8,567 8,567 COMPZ RPCOM OTHR P Empty 12.5 ppg mud from pits 1 and 2: 04:00 07:00 3.00 8,567 8,567 COMPZ RPCOM CIRC P Pump 35 bbls - 3 Ib/bbl hi vise sweep, followed by 50 bbls 9.6 ppg brine, followed by 35 bbls-31b/bbl hi visc sweep, followed by 300 bbls 9.6 ppg brine @ 2.5 bpm @ 950 psi ICP, FCP 3 b m 350 si. 07:00 08:30 1.50 8,567 8,567 COMPZ RPCOM CRIH P Pump 140 bbl of corrosion inhibited brine (1 % CRW-132 ). Displace down DP with 35 bbl of brine. Corrosion inhibited brine from 8567' to 4000' in the IA. 08:30 09:30 1.00 8,567 8,575 COMPZ RPCOM PACK P Up wt = 117 K#, down wt = 93 K#. RIH and tag at 8578' with 10 K#. PU 10', pumping 1 bpm @ 70 psi. RIH and tag at 8777 with no pressure increase due to the open mandrel below the overshot. PU and witnessed 5 K# overpull for ~1 ft, then popped free. Sit down, PU to free weight plus 2 ft and mark as set de th of 8575'. 09:30 10:00 0.50 8,575 8,575 COMPZ RPCOM OTHR P Lay break down DP stand and blow down to drive. 10:00 11:00 1.00 8,575 8,575 COMPZ RPCOM PACK P Dro ball and rod. Rig up to pump down DP. PU ~4' to PU wt and RIH to mark and set depth at 8575'. Pumping 1 bpm, pressure up to 1950 psi and wait 5 min to set lower packer. Sit down 12 K# (did not reach previous mark for 10 K# prior to packer set ). Pressure up to 3000 psi and wait 15 min to set upper acker. Slack off 25 K# and ressure u to 3700 psi and bleed to 0 psi to shear HR setting tool. Slack off and PU several time to release HR setting tool, max weight sat down was 45 K#. Setting tool would not ull free. Pressure up to 3900 psi, bleed off. Sit down 50 K#, PU and pull free with HR setting tool. U wt = 93 K#. 11:00 12:00 1.00 8,575 5,328 COMPZ RPCOM PRTS P PU and lay down 2 joints of DP. Close the pipe rams and pump down the DP. Pressure test to 3000 si for 15 min. Bleed to 0 psi, RD pump lines. 12:00 19:00 7.00 5,328 0 COMPZ RPCOM TRIP P POOH laying down DP and HR runnin tool from 5,374' to 1,000', well out of balance, CBU at 1,000', cont POOH LD 3 1/2" DP. ~~~ ~ e ~ ~ ~ Pie 12 of 14 r~ Time Logs Date From To Dur___S_C~e th E._Depth Phase Code_ Subcode T__ Com_m_ent__ ___ 19:00 20:00 1.00 0 0 COMPZ RPCOM SLPC P Slip and cut drill line. 20:00 23:00 3.00 0 5,174 COMPZ RPCOM RCST P MU seal assembl and RIH with as lift com letion to 5,174'. 23:00 23:30 0.50 5,174 5,174 COMPZ RPCOM CIRC P RU and reverse circ 3 tbg volumes at 5 bpm - 580 psi. Previous straddle run required each tubing stand to be steamed to allow the dirt to pass as this tubing was used as a worksrting in the 12.5 ppg mud. the tubing was run and flushed in preperation of a slickline drift to save time. The reverse circulating was done at a depth of 5174' to ensure that the corrosion inhibited brine remained above the SOV depth in GLM#3 at 5287'. 23:30 00:00 0.50 5,174 5,372 COMPZ RPCOM RCST P Cont RIH with completion string from 5,174' and tagged up at 5,404', up weight 70K, down weight 60K, LD one jnt and prep to RU slickline for tb drift runs. 2/25/2009 RU slickline and make iwo tbg drift runs, RD release slickline, locate and space out seal assembly, MU and land tbg hanger, RILD's, test tbg and IA, shear SOV, install BPV, ND BOP, NU and test tree, RU and freeze rotect well, RDMO. 00:00 00:30 0.50 5,372 5,372 COMPZ RPCOM HOSO P MS stacking out on setting sleeve, made 3 attempts to enter SBE and sto ed for slickline. 00:30 02:30 2.00 5,372 5,372 COMPZ RPCOM SLKL P PJSM, bring slickline tools to rig floor, RU and RIH with a 2.855" drift to top of seal assembly with no problem, POOH CO to a 2.902" drift and RIH to top of the 2.875" DS nipple with no problem. POOH RD slickline. 02:30 05:00 2.50 5,372 5,407 COMPZ RPCOM THGR P Rotated string 1!2 turn and entered the settin sleeve with no roblem. Rolled pump at 1/2 bpm and had good indication entering SBE, no-go'd with mule shoe at 5,409', spaced out seal assembly, MU hanger and landing jnt, drained stack and landed hanger, RILD's. MS set de th at 5,407'. 05:00 08:30 3.50 0 0 COMPZ RPCOM PRTS P RU and test tbg on chart for 15 min at 3,000 psi. Bleed tbg to 2,000 psi and pressured up on IA to 3,000 psi on chart for 30 min. Bleed IA and then tb to 0 si. Start r up the IA to shear the SOV. _ Pressured up to 1,460 psi, SOV sheared. 08:30 13:30 5.00 0 0 COMPZ RPCOM NUND P Install 2 way check valve. ND BOPE. NU tree. Z~~~~ 1J flf 14 f ~ 1 Time Logs ~~ Date From To Dur S Depth E. qe th Phase Code Subcode T Comment 13:30 15:00 1.50 0 0 COMPZ RPCOM PRTS P Fill tree with diesel, test tree to 5,000 psi, test tree adapter to 5,000 psi / 30 min. 15:00 15:30 0.50 0 0 COMPZ RPCOM RURD P Rig down testing equipment. Pull 2 wa check. 15:30 18:30 3.00 0 0 COMPZ RPCOM FRZP P PJSM with Little Red. Tested circ lines and manifold. Freeze protect well, pump 105 bbl of diesel down the IA and allow to u-tube with the tubin . 18:30 20:00 1.50 0 0 COMPZ RPCOM RURD P RD circ lines, installed BPV. dressed tree, moved tanks and mudshack, prepped to pull rig off well. SITP = 0, IA = 0, OA = 20 si. 20:00 21:00 1.00 0 0 COMPZ RPCOM DMOB P Notified DSO and backed rig off well, cleaned up well site and cellar box. Released Nordic Rig 3 at 21:00 hrs on 2/25/2009 ~~~ - -- ~ ~~ar~o 1d ~f ~~ • • _ SELL L~?il~ _ ~~, -- - - -~~_ ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907J 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 9951 S Fax (907) 245-8952 1 J Caliper Report 20-FeIr09 30.01 1 Report/ EDE 2J Signed : /~ Print Name: 50-029-21836-00 Date : _ ~_~N ~,-~~~i~ PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (9071245-8951 FAX: (907)245-88952 E-MAIL : ~r;~a~c~orag~Ca7r:~em®ryiog.cgrra WEBSITE: vd~~vv.rr3etnsar~Ilog.caan C:1Docvmems ana Settings\OwneADesktop\1Yansmit Conoco.daac ~i • Memory Multi-Finger Caliper ~;. Log Results Summary Company: ConocoPhiilips Alaska, Inc. WeN: 30-01 Log Date: February 20, 2009 Field: Kuparuk Log No.: 10536 State: Alaska Run No.: 2 API No.: 50.029-21836-00 Pipet Desc.: T 26 Ib. J-55 Top Log Intvl1.: Surface Pipet Use: Production Gasing Bot. Log Intvl1.: 8,384 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection ' COMMENTS Thls caliper data is tied into the top of the 7" production casing at 0 1 This log was run to assess the condition of the 7" production casing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the casing logged is in good to poor condition, with a maximum wall penetration of 61% recorded in an isolated pit in joint 146 (5,806'). Recorded damage 1 appears as a Nne of isolated pitting from -5,480' to 8,384' (EOL}. No significant areas of cross-sectional wall loss are recorded throughout the casing logged. Deposits restrict the I.D. to 5.91" in joint 140 (5,562'). A 3- Dlog plot of the caliper recordings across these restrictions, as well as a Minimum Recorded Diameter Profile, illustrating minimum recorded diameters on a joint-by joint basis, is included in this report. The caliper recordings indicate slight to moderate buckling in the production casing, beginning below the end of the surface casing at 5,305' and continuing down to 5,800'. Bends are recorded in joints 133 (5,288') and 134 {5,308'). A 3-D log plot of the caliper recordings across the vianity where an RST-Water Flow Log (11/29/08) indicated a leak in the casing is included in this report. ' This is the second time a PDS caliper has been run in this well and the first time the 7" production casing has been logged. MAXIMUM RECORDED WALL PENETRATION-~,~~~;,r~~~~~ ~-~'[~ ~~ ~~ Isolated pitting (61%) Jt, 146 @ 5,806 Ft. (MD) Isolated pitting (54%) Jt. 142 ~ 5,644 Ft. (MD) Isolated pitting (42%} Jt. 155 ~ 6,130 Ft. (MD) Isolated pitting (38%) Jt. 145 ~ 5,755 Ft. (MD) Isolated pitting { 38°r6) Jt. 152 @ 6,020 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : No significant areas of cross-sectional wall loss (> 10%) are recorded throughout the 7" production casing logged. MAXIMUM RECORDED ID RESTRICTIONS Deposits Minimum LD. = 5.91" Jt. 140 @ 5,562 Ft. (MD) Deposits Minimum I.D. = 5.96" Jt. 141 @ 5,608 Ft. (MD} No other significant I.D. restrictions are recorded throughout the 7" production casing logged.. Field Engineer: G. Etherton Analyst: C. Waldrop Witness: R. Dolcater & P. Nezaticky ProActive Diagnostic Senfices, inc. ,/ P.O. Box 1369, Stafford, TX 77497 Phone: f2.81) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS~~memarylag.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ' l~s~s-6~3 /~(0~3 ' ~ • PDS Multifinger Caliper 3D Log Plot ' ~\ _ ~~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 30-01 Date : February 20, 2009 ' Description : Detail of Caliper Recordings Across Restrictions in 7" Production Casing Comments Depth Max. Pen. (%) Max ID (1/1000 in.) 3-D Log Image Map 1ft:340R 0 100 5800 6800 69° 0° 90' 180° 270° 0° Min ID (1/7000 in.) 5800 6800 Nominal ID (1/1000 in.) 5800 6800 Joint 138 j - - __ , .y - - 5490 ~ - _ - - rc 5500 ~- . _ : __ _• . _ _ - _ Joint 139 5510 '~ ~ ~ ~ - ~ ~ t. 2296 wall -- -- - ~ Penetration _~ - -i _ . ~_~ - ,; 5520 __ ~ - -~- - -- - ~ - - - - _ 5530 i : ; 5540 ~ I ° ~~- Joint 140 i _ - x . 5550 I -- - - Minimum LD. = 5.91.. 5560 ~ ' _ _ ~ a _ 5570 I -. - f _ __ ._ 5580 - ' _ i . _ Joint 141 ~ ~ 9 5590 ~ Minimum LD. ~ : = 5.96" -- 5600 ~ i' ! _ , . 5610 _ - _ - - 5620 -- - Joint 142 j i s 5630 54% wall ' a Penetration ~ i ! ~ 4 .~ . 5640 i - . - _ -• - , - , I ._ 5650 ~ . ~ :, Joint 143 ~: Nominal ID (1/1000 in.) r............» .................................... . 5800 6800 Min ID (1/1000 in.) 5800 6800 Comments Depth Max. Pen. (%) Max ID (1/1000 in.) 3-D Log image Map 1ft:340ft 0 100 5800 6800 69° 0° 90° 180° 270° 0° • PDS Multifinger Caliper 3D Log Plot ~, Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 30-01 Date : February 20, 2009 Description : Detail of Caliper Recordings Across Vicinity Where RTS-Water Flow Log Indicated Leak Comments Depth Max. Pen. (%) Max ID (1/1000 in.) 3-D Log Image Map 1ft:340ft 0 100 5800 6800 140° 0° 90° 180° 270° 0' Min ID (1/1000 in.) 5800 6800 Nominal ID (1/1000 in.) 5800 6800 Joint 146 i __ z. - ~'`'~ ~° 5770 ~ - - = ----- ~ i:. - 5780 ._ .. - Joint 146 _ s1°~ wau 5790 j -- Penetration ' ,•,,, _ 5800 - 5810 ' ~ ~ ~ - _ - 5820 ~ ` .P _ Joint 147 20°~G Wall 5830 I - - Penetration 5840 ~ i - 'i 5850 -- F 5860 - - Joint 148 I _ ~ 32% wau 5870 ~ ~ - _ Penetration ~ i '~` - 5880 ~ ~;` ~ 5890 , - - ~ j 5900 - Joint 149 32%wau 5910 i ~ I Penetration ` ~ ~ ' 5920 ~ ~ ~~ 1 - -• ,, ~ _ ---- 5930 " ~ ~ : ,,. , . , Joint 160 ~ Nominal ID (1/1000 in.) 5~ .......» ............................s~; Min ID (1/1000 in.) 5800 6800 Comments Depth Max. Pen. (%) Max ID (1/1000 in.) 3-D Log Image Map 1ft:340R 0 100 5800 6800 140° 0° 90° 180° 270° 0° • _~ Minimum Diameter Profile Well: 30-01 Survey Date: February 20, 2009 Field: Kuparuk Tool: UW MFC 40 No. 218451 Company. ConocoPhiHips AFaska, Inc. Tool Size: 2.75 inches Country: USA Tubing I.D.: 6.276 inches z.7s 1 6 11 16 21 26 31 36 41 46 51 56 61 66 71 76 81 86 91 i 96 d E 101 Z 106 = 111 •~ 116 121 126 131 136 141 146 151 156 161 166 ~ 171 176 181 186 191 196 201 206 211 Minimum Measured Diameters (In.) 325 3.75 4.25 4.75 5.25 5.75 6.25 • Correlation of Recorded Damag Pipe 1 7. in (0.0' - 8377.4') Well: Reld: Company: Country: Survey Date: ;e to Borehole Profile 30.01 Kuparuk ConocoPhitlips Alaska, Inc. USA February 20, 2009 . Approx. Tool Deviation ^ Approx. Borehole Profile 1 0 25 972 50 1967 75 2957 100 3950 ~ ~ ~ c ._ Z 125 4941 -~ ~ - - ~ v o 150 .~ 592 7 175 6920 200 7910 212 8377 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 212 • __ PDS Report Overview ~, ~. Body Region Analysis Well: 30.01 Survey Date: February 20, 2009 Field: Kuparuk Tool Type: UW MFC 40 No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.lD Nom. Upset Upper len. Lower len. 7 ins 26 f -55 6.276 ins 7 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ,~ metal loss body 200 - 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of'oints anal sed total = 212 pene. 16 134 43 16 3 0 bss 163 49 0 0 0 0 Damage Configuration (body ) 50 40 30 20 10 0 isolated general line ring hole /you pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 41 41 0 0 0 0 Damage Profile (% wall) ~ penetration body ~-,., metal loss body 0 50 100 1 51 101 151 `. 201 Bottom of Survey = 212 Analysis Overview page 2 PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf J-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: ELATION SHEET 30-01 Kuparuk ConocoPhillips Alaska, Inc USA February 20, 2009 Joint No. Jt Depth (Ft.) Nt~n. t11»c~r Iln~.l Pen. Body (Ins.) Pc~n. %, ~;t~~l.~l Ic,~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 0 i 1 0.01 2 I 6. 0 45 l~ 0 0 t 1 .21 3 98 U 0.01 2 tl 6. 4 138 t) 0.01 ~ l~ 6.22 178 U 0.01 2 t ~ 6.2 6 217 U 0.01 u 3 2 7 a 0.01 2 U 6. 2 8 297 t) 0.01 2 ti 6. 3 336 t) 0.01 2 U 6.23 10 376 U 0.01 2 t) 6.23 11 4 6 U 0.01 3 t) 3 12 456 U 0.00 1 U 6.2 13 495 t) 0.01 2 i) 6.22 1 53 tt 0.01 ' ti 6.2 15 575 ~ ? 0.01 ? i ~ 6.22 16 614 ~~ 0.00 i ri 6.24 17 654 tt 0.01 _' ~~ 6.23 1 694 t ~ 0.01 i ! ~ 6. 2 19 733 ~ ~ 0.01 i ~ 6. 0 773 ~ ~ 0.00 1 t ~ 6. 21 81 a 0.01 2 t ~ 6.2 853 t~ 0.01 2 t~ 6 2 3 892 t ~ 0.00 1 l1 24 932 a 0.01 ~ U 6.23 72 tt 0. 0 1 u 3 26 1011 U 0.01 2 u 6.21 27 1051 U 0.01 2 n 6.2 28 1091 t~ 0.00 1 t~ 6.21 29 1131 U .01 2 U .22 30 1170 a 0.01 2 u 6.23 31 1210 t1 0.01 2 U 6.2 32 1250 t ~ 0.00 1 U 6.24 1290 U 0.01 t) 6. 34 1331 n 0.00 1 n 6.23 35 1 71 U 0.01 ~' ~ ~ 6.22 36 141 1 t) 0.00 1 u 6.23 7 1451 t) 0.0 1 O .22 38 1490 ~ 0.01 Z u 6.22 39 1530 t) 0.01 2 t~ 6. 3 40 1570 a 0.01 ~ u 6.22 41 1609 a 0.01 ~' U 6.22 42 1649 U 0.01 a 6.21 3 1689 h 0.01 ~' ~ ~ 6.21 44 1728 tt 0.01 ~' ~~ 6.23 45 17 t~ 0.01 i +~ 6.2 46 1808 a 0.01 <~ 6.23 47 1848 ~ ? 0.00 1 ~ ! 6. 4 48 1888 i) 0.01 ? ~.? 6.22 49 1927 t) 0. 1 ~ u 4 50 1967 t) D.01 2 i ~ 6.25 _Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABI, Pipe: 7. in 26.0 ppf )-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: ELATION SHEEP 30-01 Kuparuk ConocoPhillips Alaska, Inc USA February 20, 2009 Joint No. Jt. Depth (R.) I'r°n. l ))„<~t li ~~.) Pen. Body (Ins.) Pen. % ~k~i,~l I oss "4, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 51 007 ~? 0.01 3 1 6. 2 047 ~ ~ .01 ~ U 6.24 53 2087 U 0.01 ~ ~ 6 23 4 126 O 0.0 I U 6.23 55 2166 U 0. 1 ~ ~ ) 06 t) .01 ~~ U 6.23 57 2246 U l) a 6. 3 58 2 85 U 0 01 _' r ~ 6.24 59 2325 a .01 ~~ 6.2 0 2363 U 0.01 .? U .24 61 402 ~ ~ 0. ~ U 6 21 2442 U 0.01 ? t) 6.23 63 2482 U 1 1 l) 6.2 4 2 1 U 0.01 3 l) 6.23 5 61 ~l 0.01 i 1 6.23 66 DO U 0. 1 2 1 6.21 67 264 U 0.01 2 ~~ 6.24 6 2680 ~ 0. 1 2 U 6. 4 9 720 U 0.01 ~ O 2 7 760 U 0. 2 6 I 6.23 7 27 9 (~ 0.01 1 ~) 6.24 72 2839 U ~ 1 6.23 73 2879 ~~ 0.01 Z U 6.24 74 2919 U 0.01 ~ ~~ 6.23 75 5 u .0 1 u 76 2997 ~) 0.01 l u 6.23 77 3 7 U .01 3 I 6. 3 78 3076 ~) .0 2 ~) 6.17 79 3116 t) .0 Z U 6. 80 3156 ~~ 0.01 3 U 6.23 1 3196 (~ 0.01 2 U 6. 82 3235 ~~ 0.01 2 U 6.23 83 3275 U .01 ~ O 6.24 84 3315 i~ 0.01 ~ ~) 6.23 5 3355 a 0.01 ~~ a 6.2 86 3394 U 0.03 a 6.24 87 434 U 0.0 :.' a 6.25 88 3473 U 0.01 Z U 6.23 89 3513 ~~ 0.01 2 r~ 6.2 90 3553 ~~ 0.01 2 ~~ 6.23 91 3593 ~ ~ 0.01 2 U 6.21 92 3632 i ~ 0.01 2 ~ ~ 6.24 93 3672 a 0.01 2 ~) 6. 1 94 3712 U 0.02 4 ~) 6.24 95 37 1 ~~ .02 a i~ 6.2 96 3791 U 0.01 1 I 6.17 97 3831 U .0 ~ I 6.19 98 3870 U 0.01 i I 6.23 99 10 h .01 2 U ~.1 100 3950 U 0.01 2 n 6.16 _Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf J-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • ELATION SHEET 30-01 Kuparuk ConocoPhillips Alaska, Inc USA February 20, 2009 joint No. Jt. Depth (Ft.) I'c~n. L11>sc~t (Ins.) Pen. Body (Ins.) I'c~n. % ~tc~t,~l I oss %~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 101 3989 c) 0.02 4 1 3 102 402 9 U 0.01 t 1 6.17 103 406 tt .01 ~ u 6.23 104 4108 tt 0.01 _' : ~ 6.23 10 4148 l) 0.01 ~ 1 6.23 106 4190 t) 0. ~ + .24 107 4229 a 0.01 _' I 6.2 10$ 4269 U 0.02 ~ I .24 109 4 9 U 0.01 3 t) 6.24 110 4348 t) 0.01 2 U 6.23 111 4388 O .0 ~) 1 .2 112 442 (1 002 5 1 6.25 113 4468 t) 0.03 ti I 6.21 114 4508 a 0.03 1 6.24 11 4547 (1 0.03 9 1 6.17 116 458 U 3 7 I 6.2 117 4627 U 0.0 3 i) 6.2 18 4666 U .0 4 I 6. 5 119 4703 O 0.05 14 1 6.2 120 4742 O 0.0 6 u 6. 4 121 478 U 0.02 6 I 4 122 48 2 tt 0.01 i I 6.1 123 4861 t) 0.01 Z U 6.25 124 4901 a 0.02 G 1 6.22 5 49 U ~ u 126 4981 (t 0.02 6 I 6.23 127 5 21 tt 0.02 6 tt 6. 0 128 5060 U 0.03 9 I 6.25 129 5100 a .03 I 6. 130 5139 t t 0.02 6 I 6.23 131 517 i) .02 6 I 6.0 132 5218 t t 0.02 4 1 6.25 133 525 U 0.03 ti 6.16 Bend. 134 5298 U 0.03 7 I 6.22 Bend. 135 338 l) 0.0 7 2 6. 3 Sli ht ucklin . 136 5378 U 0.03 8 ? 6.16 137 5417 l) 0.02 6 1 6.23 138 5452 l) 0.04 12 6.15 Lt. D osits. Sli ht bucklin . 139 5491 U .08 22 1 6 16 Isolat ittin . Lt. De osits. 140 5531 t).t)3 0.04 1 Z Z 5.91 De sits. Sli ht bucklin . 141 5570 t) .05 14 5. 6 D sits. 142 5609 t) 0.19 54 6.17 Isola ed ittin . Sli ht bucklin . 14 5649 U 0.07 1U 6.]8 Is lated ittin t D osits. 144 5689 U.US 0.09 l-t 6.21 Isolated ittin . 145 5729 U 0. 4 31~ I 6. 1 Isolated ittin . 146 5768 (t 0.22 61 4 6.19 1 olated ittin Sli ht bucklin . 147 5808 rt 0.07 2C) ,_' .22 Isolated ittin . 148 5848 tt 0.12 32 6.23 Isolated ittin . 149 5888 ~~ 0.1 32 2 Isolate ittin . 150 5927 ~ t 0.09 ?~1 6.21 Isolated ~ittin . _ Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf J-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • ~ LATI ON SHEET 30.01 Kuparuk ConocoPhillips Alaska, Inc. USA February 20, 2009 Joint No. Jt. Depth (Ft.) I'e~n. I ll~,<~t {In..) Pen. Body (Ins.) Pen. %~ ~le~t,~l I ~~<t ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 151 967 t~ 0. 3 ;.> 6 2 solated ~t in . Lt De sits 15 6007 tt 0.14 .8 6.21 Is I ted i tin . 15 604 U .0 17 I 6. 0 Shallow ittin Lt. D its. 1 4 6086 U 0.12 3_; 6.21 Is lated ittin . 15 6125 tt 0.15 42 1 .22 I lat d ittin . 156 165 It 0.07 1 ti Z 6. 1 Sha low ittin . 157 6205 (~ 0.11 3O 2 6.22 Isolat d ittin . 158 6244 t~ 0.08 L i ~' 6.20 Isola ed ittin . 1 9 6284 U 0.07 1 ~) _' 6. 2 Shallow ittin . 160 63 4 t1 0.08 ZZ 6.24 Isolated ittin . 161 6364 U 0.08 23 I 6 23 I late ittin . 1 403 U .12 ai 6.23 Isola ed it 163 6443 U 0.05 1.1 I 6.24 S a low 'tti 1 4 6483 t) 0.07 2t~ _' 6. 4 I I ed ittin 165 6523 a 0.07 ?t) I 6.23 I ate itti 166 6 63 U 0.03 ~) l 6. 4 167 6602 tt 0.05 I~1 1 6.23 168 642 t1 0.0 17 I 6.23 hall w 'ttin 69 6681 t l .04 1 t1 I .23 70 6721 t~ 0.04 12 I 6.23 71 67 0 (~ 0.07 1 ~) I 6.23 Shallow itti 72 6800 tl 0.06 15 Z .23 Shall w ittin . 173 6840 tl 0.05 14 1 6.25 174 6880 t 1 0.06 15 I 6.24 Shallow ittin . 75 6 n 0 ~~ 1 5 176 6959 t ~ 0.05 I ~ ! 6.24 177 99 t) .04 12 1 6.24 178 7039 tl 0.07 ZO I 6.25 Isolated ittin . 1 9 7079 U 0.05 13 6.24 180 7118 (1 0.04 11) _' 6.24 181 7158 tl 0.10 ~7 1 6.26 Isolated ittrn . 182 7198 U 0.04 1l) 1 6.24 18 72 8 l) 0. 4 12 I 6.26 184 7277 tl 0.05 l I 6.24 185 7317 t I 0.06 1(> I 6.24 Sal ow itti 186 7355 U 0.04 t U 6.24 187 7395 it 0.0 15 I .24 Sh Ilow ittin . 188 7435 tl 0.05 1 ; I 6.25 189 7475 t ~ 0.03 ~> I 6.22 190 7514 a 0.05 1 ~ I 6.24 191 7552 t~ 0.04 IO 1 6.24 192 7592 U 0.05 ) _~ 6.24 Lt. De osits. 3 763 t ~ 0.06 1 7 I 6.' S al ow it ~n . 194 7672 t) 0.05 14 ~ 6.24 195 771 u 4 It1 6.23 196 7751 t I 0.04 1 t ~ 6.18 Lt. D osits. 1 7 7791 U 0.05 1 _I 6.24 198 7831 U 0.05 13 6.24 1 9 7870 t) 4 1 U 6.24 200 7910 ~~ 0.05 14 I 6.25 Shallow >ittin . Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf )-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • -LATION SHEET 30-01 Kuparuk ConocoPhillips Alaska, Inc. USA February 20, 2009 joint No. jt. Depth (Ft.) I'~~n. t II „c~t (Im.l Pen. Body (Ins.) Pen. °4, ~tc~t~~l I os `io Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 O1 7949 I) 0.07 19 6. 3 h Ilow ittin . 2 7 9 (? 0.04 1U 3 6 20 8029 I) 0. 4 12 ~' 6. 3 04 8069 U 0. 9 '4 ~ 6.2 I laced itti 20 8109 U 0.04 12 _~ 6.24 06 814 O 0.07 19 ? .23 hall w i ti 207 8188 U 0.0 1' 6.23 hallow ittin . 208 8228 U 0.07 19 II) 6. 2 Shallow ittin . 209 82 8 u 0.05 13 s 6.24 210 8307 U 4 1 C) ~' 6.2 11 83 5 U 7 19 ? 6.23 Sallow i 'n . 21 377 U .0 i 1 6 3 Penetration Body Metal Loss Body Page 5 ~ ~ ~ ~^s ~ ~ ~ ~ i ~ i ~ ~ ~ ~ ~ ~ ~ r PDS Report Cross Sections ~~ ~~ ,. Well: 30-07 Survey Date: February 20, 2009 Field: Kuparuk Tool Type: UW MFC 40 No. 218451 Company: ConocoPhiltips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 7 ins 26 _~-55_ _ _ _ _ Analyst: C. Waldrop Cross Section for Joint 146 at depth 5806.27 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 97 Tool deviation = 47 ° Finger 27 Penetration = 0.22 ins Isolated pitting 0.22 ins = 61% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 ~w _ .~ PDS Report Cross Sections Well: 30-01 Survey Date: February Z0, 2009 Field: Kuparuk Tool Type; UW MFC 40 No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 7 ins 26 f -55 Anal st: C. Waldrop Cross Section for Joint 142 at depth 5643.5 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 97 Tool deviation = 47 ° Finger 11 Penetration = 0.194 ins Isolated pitting 0.19 ins = 54% Wall Penetration HIGH SIDE = UP • Cross Sections page 2 PDS Report Cross Sections ~,. - -~ ~. Well: 30-01 Survey Date: February 20, 2009 Field: Kuparuk Tool Type: UW MFC 40 No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 4U Tubing;.- ____-_7 ins _ 26 ppf J-55 Analyst: C. Waldrop Cross Section for Joint 140 at depth 5561.77 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 99 Tool deviation = 47 ° Finger 18 Projection = -0.328 ins Deposits Minimum I.D. = 5.91 ins HIGH SIDE = UP ~J • Cross Sections page 3 • o ~ a a 0 SARAH PAUN, GOVERNOR 7~T ~+~~tt laa~[1atr't7r~~ 0~ LTD vow7_ _,: .._333 W. 7th AVENUE, SUITE 100 CO1~SL1 RQAii01~ CU1-II~ZISSIUI~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jim Ennis Wells Engineer ConocoPhillips Alaska Inc. ~ .-,;;,~ : ~ ~ ~~ ~ ~~ ~, PO Box 100360 ~ ~ ~ ' "~ ~~ "~ ~~ Anchorage AK 99510 /~~ Re: Kuparuk River Field, Kuparuk Oil Pool, 30-01 ~~ Sundry Number: 309-028 Dear Mr. Ennis: 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 Commission 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 ~ d" ay of January, 2009 Encl. ~~~ ~ FEE ALASKA OIL AND GAS CONSERVATION COMMISSION ~( CEIVE APPLICATION FOR SUNDRY APPROVAL JAN 2 7 2009 20 AAC 25.280 Alac4~ nn o .~ ... 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver A orage Alter casing ^ Repair well ^/ ~ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^/ ~ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 188-073 3. Address: Stratigraphic ^ service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21836-00 ` 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Requires? Y@S ^ NO ^~ 30-01 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25513 ~ RKB 59' ~ Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9173' - 6890' 9065' 6805' 9000' Casing Length Size MD TVD Burst Collapse CONDUCTOR 115' 16" 115' 115'. SURFACE 5246' 9-5/8" 5305' 4066' PRODUCTION 9089' 7" 9148' 6871' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8832'-8847', 8850'-8866', 8890'-8910' 6623'-6634', 6637'-6649', 6668'-6684' 3-1/2" J-55 8736' Packers and SSSV Type: Packers and SSSV MD (ft) AVA'RHS' pkr @ 8666' Camco TRDP SSSV @ 1786' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat February 2, 2009 Oil ~ ' Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify tha he foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed Nam Jim Ennis Title: Wells Engineer Signature '~ Phone 265-1544 Date ~ ~ ©~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ ~ Other: ~d ®d S ~ ~ G.~-a~CS~ Q ~s ~~ S ~ C~.~i~:i~.V~~ ~5~ C~.S ~/~~ ~ Subsequent Form Required: ~ V ~ APPROVED BY ApNroved b . COMMISSIONER THE COMMISSION Date: Ofd Form 10=403 ~tevised 06/2006 e...~ ` I ~ i,; i ~~ + ~ ~ ~~~e~ubmit in ~u2? t `~ ~ig Workover Sundry Procedur~ Well 30-01 Kuparuk Producer Straddle casing leaks 8~ replace tubing / PTD# 188-073 1. MIRU Nordic #3. Circ KWF through tbg leak @ 5600' MD. Verify well is dead. Paint line on tree, tbg head adapter and tbg head. Take photo of tree position for reference at end of Workover. 2. ND tree. Install blanking plug in hanger lift threads. NU 11" BOP. Function test BOP. PT BOP rams to 250/4000 psi and annular to 250/3500 psi (SIWHP 1900 psi & MASP 3854 psi using 12/3/08 SBHP & 0.1 psi/ft gradient). Pull blanking plug &BPV. (Note: 24 hr advance notification to AOGCC required prior to testing BOPE.) 3. Unland tbg hanger. POOH laying down 3.5" tbg w/ SCSSV, GLM's & seal assembly. Note: No equipment shall leave location until surveyed for NORM. 4. RIH w/ service packer on 3.5" workstring. Set pkr @ 8600' MD & PT `RHS' pkr to 2500 psi. Release service packer 8~ verify top & btm of csg leaks (WFL indicates 5852'-5863'). POOH w/ service packer &workstring, laying down 3000'. 5. R!H w/ seal assembly, 2900' 3.5" production tbg, `FHL' packer &PBR on 3.5" workstring. Circ inhibited brine into annulus below 'FHL'. Set `FHL' @ 5750' MD w/ 2500 psi. PT IA to 2500 psi. Shear PBR 8~ circ hole over to corrosion-inhibited 9.6 ppg brine. POOH laying down workstring. 6. Single in w/ 3.5" completion as follows: a) PBR seal assembly w/ handling sub above b) 1 joint 3-1/2", 9.3#, L-80, EUE 8RD Mod tubing c) 2.813" 'DS' nipple w/ handling subs d) New 3-1/2", 9.3#, L-80, EUE 8RD Mod tubing w/ three GLM's (1500 psi SOV in btm GLM) e} 2.875" `DS' nipple @ 500' (3.5" tbg above must drift 2.91 ") 7. Space-out PBR 2' off btm and land tbg hanger with a full joint immediately below. RILDS. RU chart recorder to tbg & IA. With the annulus open, PT tubing to 3000 psi for 15 minutes. Bleed off tubing pressure to 2000 psi. Holding the tubing pressure at 2000 psi, PT IA to 3000 psi for 30 minutes. Bleed off IA & then tubing pressure. Pressure IA to 2000 psi rapidly to shear the SOV. Install TWC. NDBOP. NUWH. Test tree and packoffs to 5000 psi. Pull TWC. Freeze protect well by pumping 100 bbls diesel into IA & equalize across tree. Install BPV. RDMO. Post Rig Work 1. RU slickline. 2. Replace SOV with dummy. PT tbg 3000 psi. 3. Retrieve `CA-2' plug. 4. Install GL design. RD slickline. Jim Ennis Page 1 1/26/2009 • • cul rent Comol 30-01 Proposed Workover in Pronos~ 'd 2009 Coi I I I n I i n 2.875" Camco DS Nipple New 3.5" L-80 Tbg 2.813" Camco DS Nipple PBR 3.5 x 7" Baker FHL Packer Top of casing leaks -5850' MD 3.5" Tbg Original AVA PBR Original AVA RHS Packer Original 2.75" Camco D-Nipple I 7" Prod Csg CuntxoPhillips ri . ~~..: t. Ir1C. CONDUCTOR. n5 SAFEN VLV, 1,]86 GAS LIFT, 3.02] SURFACE. 5.305 GAS LIFT. 5.496 GAS LIFT, s,e66 GAS LIFT. _ _ ] 536 GAS LIFT, 8,067 cAS uFr, 6.61 t PBR. 8.65/ PACKER, 0,666- --- NIPPLE. 0.702 SOS. 8.]35 TTL. 8.]36 IPERF._ __-y 0,832-0,047 ~ s IPERF. 0,850-0,066 .~ IPERF. 8,090-0.910 FISH, 9,000- - PRODUCTION, 9,160 TD, 9,173 KU P • 30-01 I Well Attributes _ _ (Max Angle 8 MD i~TD _ Well[wre APVU WI Field Name Well Status ProNlnj Type Inc!(°) MD(ftK8) ',Act Bhn (kK6) 500292183600 KUPARUK RIVER UNIT (PROD 52.62 3,700.00 9,173.0 Comment M2S (ppm) Dafe Annotation End Date KB-Grd (ft) Rig Release Date SSSV~ TROP 230 7/1/2008 (Last WO: I 34 98 8/5/1988 Annotation 'I Depth (ftKB) End Date Annotation Entl Date Last Tag~~ 8,947.0 8/9/2008 Rev Reason: LEAK @ 5852' TO 5863', PULL PLUG & GAUGES 12/5/2008 Casin Strin s ', _ String OD String ID Set Depth Set Depth (ND) String Wt String Casing Description (inl (in) Top (ftKB) (RKB) (ftKB) (Ibslft) Grade Siring TOp Thrtl 'i (CONDUCTOR '~ 16 15.062 0.0 115.0 115.011 62.SOH-00 SURFACE 9518 8.765 0.0 5,305.0 4,066.0 36.00 J-55 ~PRODUCIION ' 26.00 J-55 7~ 6.151 0.0 9,148.0 6,870.71 . Tubing Strings . I ii String OD String ID Set Depth Sat Depth (ND) String Wt String Tubing Description (in) (in) Top (ftKB) (RKB) (RKB) (Ibslft) Glade Siring TOp Thrd IUBING 31/2 2992 0.0 8,73fi.0 6548.1 9.30 J-55 EUEBrdABMOD ,Other In Hole (A ll Jewelry: Tubing Run 8 Retrievable, Fish, etc.) __ Top Depth/ ~ 1 (TVD) Top Inc! Top (ftKB) (RKB) (°) Description Comment Run Data ~ ID (in) I ' 1,786.0 1,698.21 35.461 SAFETY VLV Camco'TRDP' 10/3/1988 2812 3,027.0 2,568.8 49.69 GAS LIFT IMMH(FHMO/1/DMY/BK///Comment: STA1 9/12008 2.8671 5,496.0 4,194.3 47.72 GAS LIFT MMHlFHMO/t/DMY/BK///Comment STA2 9/1/2008 i 2.8671 6,888.0 5,1478' 4/.45 GAS LIFT MMH/FHMO/1/DMY/BK/!/Comment: STA3 5/2/1998 ~ 2.867 7,536.0 5,633.3 41.26 GAS LIFT MMWFHMOl1/DMY/BK///Comment: STAR 10/3/1958 ~ 2.867 8,087.0 6 049 6 40.35 GAS LIFT MMH/FHMO/1/DMY/BK/// Comment: STA S 5/2!1998 ~ 2.867 5,611.0 6,4518 39.77 GAS LIFT OTIS/LBX/1.S1DMY/RM//l Comment STA6 5/2/1998 2.907 8,652.0 6,4832 39.58 PBR AVA 10/3/1988 3.000 8,666.0 6,493.9 39.57 PACKER AVA'RHS' 10/3/1988 3.000 8,702.0 6,521.7 ' 39.34 NIPPLE Camco'D' Nipple NO GO ~ ~. ~ 10/3/1988 2.750 8,735.0 6,547.3' 39.19 SOS (Baker -~-~ 10/3/1988 2.992 8,736.0 6,548.1', 39.18 TTL ~, ELMD 8745' SWS 8/4/1988 ~ 10/3!1988 2.992 9.000.0 6,754.3 i, 38.78 FISH (PIECE OF 3" JD DOG t" x LS" 8/31/2008 ~I 0.000 Perfiora tions _.. _____ _.._._ _. ~ i ,Shot ii Top (N D) Bim (TVD) '. Dens Top (ftKB) Btm (NK8) (ftKB) (RKB) gone Date (sh... Type Co mment 8,832.0', 8,847.0 6,622.6 6,634.4 A-3, 30-01 4/28/1989 12.0 IPERF 21/8" EnerJet; 60 tleg. ph 8,850.0 ~~ 8,866.0 6,636.7 6,649.2 A-2, 30-01 14/28/1989 12.0 IPERF 2 1/8"EnerJet; 60 deg. ph 8,890.0 ~. 8,910 0 6 668.0 6 683.7 A-1, 30-01 110/3/1985 8.0 IPERF 4.5" Csg Gun; 45 deg. ph Notes: General & Safet '~ End Date Annotation ',8/25/2008 iNOTB POSSIBLE TBG LEAK BETWEEN 5496 MD & 6888 MU 9/9/2008 'NOTE: LEAK FOUND @ 5600' IN COLLAR 11/52008 NOTE: LDL coniirtns TxIA communication @ 5600' 11/292008 NOTE: LEAK FOUND BETWEEN 5852' & 5863' From: NSK Problem Weil Supv [n1617@conocophillips.com] Sent: Monday, December 01, 2008 3:00 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); NSK Problem Well Supv Subject: FW: KRU 30-01 (PTD# 188-073) Report Of Failed TIFL Attachments: 30-01 Wellbore Schematic.pdf; 30-01 TIO Plot.ppt Tom, During the diagnostics for the failed TIFL, a RST WFL identified a production casing. leak between 5852' - 5863'. The well is currently SI and will remain SI until repairs have been made. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 From: NSK Problem Well Supv Sent: Monday, August 25, 2008 8:58 AM To: 'tom.maunder@alaska.gov'; yim.regg@alaska.gov' Cc: NSK Well Integrity Proj; CPF3 Prod Engrs; CPF3 DS Lead Techs; NSK Problem Well Supv; Williams, Theresa Subject: KRU 30-01 (PTD# 188-073) Report Of Failed TIFL Jim/Tom, Kuparuk gaslifted producer 30-01 (PTD# 188-073) failed a diagnostic TIFL on 8/22/08 while the well was shut in and has been added to the SCP report . The TIO prior to the SI TIFL was 1900/2000/220. A gaslift valve is suspected so our immediate plan is to have slickline troubleshoot tubing and accessory integrity. The well will be fixed or shut-in by 9/19/08. Attached is a weltbore schematic and a 90 day TIO plot. «30-01 Wellbore Schematic.pdf» «30-01 TIO Plot.ppt» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 1 /29/2009 TIII~ F~Ir~t - ~t~-0'1 ?~~ 15C~~ 1 ~1~~ ~~~ ................ I ,.. _. _._,: ~_ 151 1~~ ~ ~V L ~1-Jury-~~ ~1-Jul-~~ ~1-Aug-~~ ~~t~ a Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # o/ ;, .. ~~ /~ - ~~. NO. 5005 ~;~~~ . .b J F~ ~~~ ~~\ :~~ Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 12/17/08 2X-10 11978476 PRODUCTION PROFILE / - / . 08/17/08 1 1 2V-09 12100460 PRODUCTION PROFILE (p 11/16/08 1 1 1Y-06A 12100461 PRODUCTION PROFILE 11/17/08 1 1 2X-12A 12100464 PRODUCTION PROFILE 9 '- 11/21/08 1 1 2U-08 12096574 PRODUCTION PROFILE - 11/28/08 1 1 3K-108 12100466 USIT 11/23/08 1 1 3K-30 12097433 LDL _ / "~ 11/28/08 1 1 0-01 12097434 LDL 11/29/08 1 1 1 E-04 12097436 LDL 11/30/08 1 1 3A-04 12097432 INJECTION PROFILE L - 11/27/08 1 1 1 H-16 12096581 PRODUCTION PROFILE ) - 12/05/08 1 1 3A-06 12114994 BAKER LOWER STRADDLE PACKER 11/26/08 1 1 2U-14 12096578 INJECTION PROFILE C - j 12/02/08 1 1 iG-06 12096580 INJECTION PROFILE 12/04/08 1 1 2V-10 12096582 PRODUCTION PROFILE - 12/06/08 1 1 3F-01 12086694 PRODUCTION PROFILE ~' 12/07/08 1 1 2W-14 12086695 INJECTION PROFILE -~+ 12/08/08 1 1 1J-102 12086701 INJECTION PROFILE 12/14/08 1 1 i D-07 12114999 USIT _ ~ 12/15/08 1 1 3C-02 12114997 INJECTION PROFILE _ ~ 3 12/13/08 1 1 2T-18 12086703 INJECTION PROFILE ~ = 12/17/08 1 1 C J CJ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 09/15/08 ~~ ~~~[11~~~r~~i Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth p~~" g~ i ~~ ,f i di„t~~~~g' Well Job # Log Description N0.4871 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD iC-172A 11978478 PRODUCTION PROFILE ~- 08/19/08 1 1 1C-172A 12080429 GLS/FBHP - 08/19/08 1 1 3M-26 12096533 SBHP SURVEY 08/20/08 1 1 3N-02A 11996652 SBHP SURVEY 08/20/08 1 1 3M-22 11966276 SBHP SURVEY - 08/20/08 1 1 3C-17 11996657 SCMT (~ - /(n 9 ~L/ 08/25/08 1 1 3C-15A 11996659 PERF/SBHP SURVEY ~a0~-Q~~ r~G3i~ 08/27/08 1 1 2U-06 12080428 LDL _p( - 08/29/08 1 1 2V-15 11996661 PRODUCTION PROFILE ~ =p 08/29/08 1 1 2T-19 11996663 PRODUCTION PROFILE 08/31/08 1 1 2D-07 11975790 INJECTION PROFILE - ~ 3 / Q 09/07/08 1 1 2H-09 11975788 PRODUCTION PROFILE ~p 09/05/08 1 1 iC-174 12096539 INJECTION PROFILE - p 09/07/08 1 1 2H-12 12096540 PRODUCTION PROFILE '- ~ 09/09/08 1 1 30-01 11975792 LDL -Q'~ 09/09/08 1 1 3F-10 11975789 LDL [ 09/06/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. r: • VV~LL LSO f T~~4~~/44~1~4L ProActive Diagnostic Services, Inc. To: ACC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing tnspection(Caliper/ MTV The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 ~~~~~~ ~~~ 1- s3 ~~~~ Fax: (907) 245-8952 1 ] Caliper Report 2] Caliper Report 30-Aug-0$ 1 G05 31 Aug-08 30-01 Irk-o~3 l rob~U ~ u:~e, c~3 -oaU lla'~5~5~ Signed Print Name: r~ l ~ 1 Report / EDE 1 Report / EDE 50-029-20908-00 50-029-21836-00 Date ~ ~ ~ ~~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (947)245-8951 FAX: (9Q7)245~8952 E-MAIL : ~ds~.~~I:~rSC~~sa?~rla~r~rl~g.c®r~a WEBSITE : vs^~r~,s~®ar~arVina.c~t~a C:\Docoments and Settings)Owner\Desktop\7Yansmit_Conoco.doc Nfemory Mini-finger Caliper Lag Results ~ummalry Company: ConocoPhillips Alaska, Inc. Well: 30-01 Log Date: August 31, 2008 Field: Kuparuk Log No.: 7731 State: Alaska Run No.; 1 API No.: 50-029-21836-00 Pipet Desc.: 3.5" 9.3 Ib. J-55 8RD EUE AB MOD Top Log Intvl: Surtace Pipet Use: Tubing Bot. Log Intvt: 8,745 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the Tubing Tail @ 8,745' (FEND). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing is in good to poor condition with respect to corrosive damage, with a maximum wall penetration of 54% recorded in an area of corrosion near the upset in joint 235 (7,650'). Other recorded damage appears as scattered pitting, and intermittent areas of broader corrosion. No significant areas of cross-sectional wall loss are recorded. Deposits restrict the I.D. to 2.60" in joint 161 (5,261'). MAXIMUM RECORDED WALL PENETRATIONS Corrosion (54°~) Jt. 235 @ 7,650 Ft. (MD) Isolated Pitting (45%) Jt. 248 @ 8,072 Ft. (MD) Corrosion (45%) Jt. 258 @ 8,422 Ft. (MD} Isolated Pitting (42%) Jt. 255 @ 8,328 Ft. (MD) Isolated Pitting (40%) Jt. 259 @ 8,461 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 6%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS Deposits Minimum I.D. = 2.60" Jt. 161 @ 5,261 Ft. (MD) No other significant I.D. restrictions are recorded. ~~. SEA 20118 Field Engineer: J. Halvorsen Analyst; M. Lawrence Witness: S. Ferguson ProACtive Diaynastic Services, Inc. / P.O. Box 1369, Stafford, Tx 77497 Phone: {281j or (888) 565-9085 Fax; {281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: {907) 659-2307 Fax: {907) 659-2314 ~~~-0~3 ~ ic~~~~ Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (38.3' - 8745.2') Well: 30-01 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: August 31, 2008 ^ A pprox. Tool D eviatio n ^ Approx. Boreh ole Prof ile 1 42 25 820 50 1626 75 2455 GLM 1 100 3266 ~ 125 E 4075 ,~ ~ z _ •- ~ .a 150 s 4886 GLM 2 17' 5706 200 ~ 6517 GLM 3 22 ' GI_,'vl 4 7320 C ~I M 5 250 8139 GLM 6 267.2 8745 0 50 10 0 Dam age Pro file (% wall) / Tool De viation (degre es) Bottom of Survey = 267.2 PDS Report Overview ~ ~w Body Region Analysis Well: 30-01 Survey Date: August 31, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.2 f -55 BTC AB-MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (%wall) ~ penetration body metal loss body 2 SO 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of "oints anal sed total = 270 pene. 0 130 123 13 4 0 loss 228 42 0 0 0 0 Damage Configuration (body ) 80 60 40 20 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of ~oirtts damn ed total = 91 78 13 0 0 0 Damage Profile (% wall) ~ penetration body _,., metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 Bottom of Survey = 267.2 Analysis Overview page 2 PDS REPORT JOINTTABI. Pipe: 3.5 in 9.2 ppf )-55 BTC AB-MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: iLATION SHEET 30-01 Kuparuk Conoco Phillips Alaska, Inc. USA August 31, 2008 Joint No. Jt. Depth (Ft.) I'~•n. l Jt~s~~! (ln~.) Pen. Body (Ins.) Pc~n. °~~, ~1~~I,il Lcs~ `%, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 38 (! 0.01 4 !~ 2.95 PUP 1 42 (~ 0.01 G U 2.94 2 74 (~ 0.01 (! a 2.93 3 107 U 0.01 r, ~ ~ 2.93 4 139 (! 0.01 ~; !~~ 2.93 5 172 ~! 0.01 5 i ! 2.93 6 204 ! ! 0.02 ~ ~ 2.94 7 237 t! 0.01 (~ a 2.93 8 269 ~? 0.02 7 U 2.93 9 302 U 0.02 I 2.94 10 333 0 0.01 > ~! .92 11 366 ~ 0.02 ~ ~ 2.93 12 399 a 0.02 is ~! 2.94 13 431 n 0.02 ~ ~ 2.93 14 463 i! 0.02 - I 2.93 15 496 ~ ! 0.0 - I 2.92 16 528 ~! 0 02 i I 2.93 17 5 1 ~? 0.0 ~ i! 2.93 18 593 ~! 0.02 7 l! 2.93 19 6 i! 0.0 7 U 2.93 20 657 ~! 0.02 7 1 2.93 21 690 ~! 0.01 5 1 2. 3 22 722 ~! 0.02 7 I! 2.93 23 755 !! 0.02 t3 1 2.94 24 787 n 0.01 t, _' 2.92 25 820 ~! 0.02 ti _' 2.91 26 852 ~! 0.02 I 2.93 27 885 a 0.02 7 ~! 2.92 28 917 t) 0.02 7 I 2.93 29 949 (! 0.02 ~! 2.92 30 982 ~? 0.02 t) I 2.94 31 1014 ~! 0.02 ~~ 1 2.91 32 1047 ~! 0.02 ~~ ~ 2.91 33 1079 ~! 0.02 ~~ 3 2.92 34 1112 n 0.02 ~) 3 2.92 35 1144 ! ~ 0.03 13 1 2.90 Shallow ittin . 36 1177 ~! 0.0 0 1 2.91 37 1209 t) 0.03 1~-) 1 2.91 38 1238 I! 0.02 ~) 1 2.91 39 1270 I! 0.02 tt 4 2.92 40 1302 l! 0.02 ~~ 1 2.92 41 1334 (! 0.01 (~ 1 2.93 42 1367 U 0.02 ~! ~! 2.93 43 1399 !! 0.02 ~) ~ 2.91 44 1431 l! 0. 2 t3 U 2.92 45 1464 U 0.02 ~) (1 2.91 46 1496 U 0.02 t3 ~ 2.90 47 1529 U 0.03 I1 I 2.91 48 1 61 ~) 0.02 t3 I 2.91 49 1594 i! 0.02 ~) 1 2.91 _ Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC AB•MOD Well: 30-01 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 31, 2008 Joint No. Jt. Depth (Ft.) 14~n. I11>~E~t (Ins.) Pen. Body (Ins.) I'c~n. % 'vtct,il Ir~~ti ~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 50 1626 t? 0.0 ti I 2.92 51 1659 (t 0.03 1 _' I 2.90 Shallow ittin Lt. De sits. 52 1689 tt 0.03 to a 2.9 53 172 2 t ~ 0.02 `) 2.92 54 1753 tt 0.02 I 2.91 54.1 1786 tt 0.02 ~> 2.93 PUP 54.2 1792 tt 0 ~~ ±~ 2.81 SSSV 54.3 1804 a 0.03 1 u 2.93 PUP 55 1810 t ~ 0.02 U 2.91 56 1843 t I 0.03 1 1 ~' 2.91 57 1875 a 0.03 10 1 2.89 58 1908 t I 0.02 t3 1 2.91 59 1940 U 0.02 ti I 2.95 60 1972 ~~ 0.04 14 a 2.91 Shallow ittin . 61 2005 t t 0.03 1 U I 2.93 62 2035 a 0.04 14 1 2.94 Shallo ittin . 63 2068 U 0.03 t t t 2.91 4 2101 a 0.03 I I I 2.93 65 2133 tt 0.0 1Z 1 2.91 Shallow ittin . 66 165 i) 0.02 ~> 1 .91 67 2198 a 0.02 <I I 2.95 68 2230 U 0.03 11 I 2.91 69 2262 t) 0.04 14 U 2.9 Shallow orrosion. 70 2295 a 0.03 11 I 2.93 71 2327 a 0.0 `> 2.93 72 2359 ~ t 0.03 1 1 I 2.93 73 2390 ~ t 0.04 14 1 2.91 Shallow ittin . 74 242 3 ~ ~ 0.02 ~) 1 2.93 75 2455 U 0.02 7 I .95 76 2487 tt 0.03 12 I 2.89 77 2520 tt 0.03 13 I 2.91 Shallow ittin . 78 2552 n 0.02 `) I 2.93 79 2584 tt 0.03 11 a 2.91 80 2617 a 0.02 t3 ? 2.91 81 2649 U 0.03 13 1 2.90 Shallow ittin . 82 2682 tl 0.03 l:~ ~' 2.89 Shallow ittin . 83 2713 t~ 0.02 ~~ I 2.92 84 2 745 t l 0.02 9 n 2.92 85 2777 U 0.03 13 I 2.89 Shallow ittin . 86 2809 tl 0.03 1U ? 2.93 87 2840 a 0.04 14 tt 2.90 Shallow ittin . 88 2873 U 0.02 `) 1 2.93 89 2905 U 0.02 `~ I 2.92 90 2938 l) 0.02 t3 1 2.95 91 2970 tt 0.0 `~ 1 .95 92 3002 ~ t 0.03 1 I 2.92 92.1 3034 U 0 t) tt N A GLM 1 Latch 3:30 93 3041 ll 0.03 I1 ? 2.90 94 3074 U 0.02 is I 2.94 95 3105 a 0.02 2.92 _ Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 30-01 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 31, 2008 Joint No. Jt. Depth (Ft.) Pen. I II ~Se! (Ins.) Pen. Body (Ins.) I'~~n. ° ~, ~1~~i.~l I ~ ~.~ ~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 6 3138 t) 0.02 ti I 2.94 97 3169 tl 0.02 ~) ~' 2.8 98 3202 t t 0.03 1(1 a 2.93 99 3234 t) 0.02 ti I 2.94 100 3266 !! 0.03 1 ~ I 2.91 101 3299 U 0.03 L1 1 2.94 Sh Ilow ittin . 102 3331 t? 0.03 L, ! 2.88 Shallow ittin . 103 3364 U 0.02 ~~ I 2.93 104 3397 ~) 0.02 ~) I 2.95 105 3429 t? 0.02 ~! I 2.93 106 3461 O 0.02 ~> _' 2.93 107 3494 U 0.02 ~) i 2.92 108 3527 !) 0.02 ~~ I 2.96 109 3558 t) 0.03 1 1 2.88 Shallow ittin . 110 3592 t) 0.02 ti I 2.94 111 3622 ~) 0.03 Li I 2.89 Shallow ittin . 112 3655 t) 0.03 I ~' 2.91 113 3687 i! 0.03 I ~ I 2. 0 114 37 0 !! 0.04 15 _' 2.91 Shallow ittin . 11 3752 !) 0.03 I Z I 2. 0 116 3786 t) 0.03 1u 1 2.94 117 3818 U 0.03 1 Z I 2.94 118 3850 t) 0.02 ~> I 2.94 119 3882 !) 0.03 I _' ! 2.88 120 3915 !? 0.03 lit 2.89 121 3948 !~ 0.03 l.i _' 2.91 Shallow ittin . 122 3977 U 0.03 13 1 2.93 Shallow ittin . 123 4010 O 0.03 I1 I 2.93 124 4042 U 0.02 ~) 1 2.94 125 4075 tt 0.02 9 1 2.90 126 4108 U 0.03 I:i 1 2.93 Shallow ittin . 127 4140 l~ 0.03 11 U 2.90 1 8 4173 i1 0.03 1_> I 2.88 129 4205 i? 0.04 1.~ I 2.89 Shallow ittin . 130 4237 !) 0.03 II I 2.90 131 4269 U 0.03 11 I 2.93 132 4302 U 0.03 12 I 2. 9 133 4335 ! ~ 0.03 11 U 2.93 134 4366 t) 0.03 Ill 1 .91 135 4399 t) 0.02 ti 1 2.93 136 4431 U 0.02 ~) I 2.94 137 4464 O 0.02 7 I 2.95 138 4496 U 0.02 ~) I 2.94 139 4529 U 0.03 I U l) 2.93 140 4561 U 0.03 1 I I ,93 L. i 141 4594 U 0.03 11 2 2.94 142 462 7 U 0.02 ~1 I 2.93 Lt. De osi 143 4659 !) 0.03 1 l l t) 2.93 144 4692 !) 0.02 9 ~) 2.92 145 472 5 ~) 0.02 9 I 2.94 _ Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 30-01 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 31, 2008 Joint No. Jt. Depth (Ft) I'~•n. ! II ~~~ i tlm_i Pen. Body (Ins.) Pc•n. °-'~~ ~Ic•i.~l I rx~ ~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 146 4756 ~ ! 0.03 I c) I 2.92 147 4788 U 0.03 1 I t 1 2.91 Lt. D osi ts. 148 4821 t ! 0.02 ~) t) 2.94 149 4853 ct 0.03 II I 2.91 150 4886 a 0.03 11 I 2.94 151 4919 (1 0.03 I1 !! 2.92 152 4951 !) 0.02 ~! ~ ~ 2.93 153 4984 ~) 0.03 I I ~ ! 2.90 154 5017 a 0.03 I c) i ! 2.92 155 5049 a 0.02 ~+ I 2.94 156 5081 t ~ .02 ~~ I 2.92 157 5113 ~ ~ 0.02 ' ~ I 2.93 158 5146 !) 0. 3 1 ~ I 2.93 159 5179 ~) 0.02 ' ~ i 2.93 160 5211 ~ ! 0.02 ~~ i ! 2.91 161 5244 !! 0.07 ~t, I 2.60 Corrosion. De sits. 162 5277 ! ~ 0.02 ti 1 2.93 163 5309 i! 0.02 ti l) 2.92 164 5342 ~) 0.02 l) 2.93 165 5374 t) 0.02 ti U 2.93 166 5406 a 0.02 ~) U 2.91 167 5439 t) 003 11 1 2.93 168 5472 t) 0.03 10 ? .93 168.1 5504 t) 0 (1 tl N A GLM 2 Latch ~ 2:00 169 5511 t) 0.02 9 t) 2.93 170 5543 a 0.03 1 1 t) 2.91 171 5576 t) 0.03 11 t) 2.92 172 5608 U 0.03 l i t 1 2.92 Shallow ittin . 173 5641 U 0.03 l:3 1 2.9 Shallo ittin . 174 5673 (~ 0.02 ~) t) 2.90 175 5706 t) 0.03 11 1 2.91 176 5738 t) 0.03 11 I 2.93 177 5771 t) 0.02 ~) U 2.92 178 5803 t) 0.02 ~) a 2.91 179 5835 t) 004 I.1 U 2.90 Shallow ittin . 180 5869 t1 0.03 la I 2.92 Shallow ittin . 181 5901 t) 0.03 13 t1 2.88 Shallow ittin . 182 5934 U 0.03 12 t) 2.91 183 596 t 1 0.03 1 t) t) 2.93 184 5999 O 0.03 1 U 1 2.93 185 6030 U 0.03 1O a .88 186 6062 U 0.03 13 l) 2.87 Shallow ittin . 187 609 U 0.03 13 a 2.87 Shall w ittin . 188 6128 t) 0.03 1t) a 2.93 189 6 60 u 0. ~) tl .91 190 6193 t) 0.02 ~1 a 2.93 191 6224 n 0.0 I z u 2.90 192 6257 t) 0.03 1t) t) 2.90 193 6290 ~) 0.04 I > I 2.86 Shal-ow corros'on. 194 63 3 u 0.03 1:1 t) 2.92 Shallow ittin . _ Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: iLATION SHEET 30-01 Kuparuk ConocoPhillips Alaska, Inc USA August 31, 2008 Joint No. Jt. Depth (Ft.) I'~~n. Ilp,e~t (In.i Pen. Body (Ins.) I'c~n. ",4~ ~t~~t.il lo~ti ~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 195 6354 t? 0.03 I ; i i 2.88 Shallow ittin . 196 6387 ti 0.03 1I U 2.91 197 6420 t1 0.04 17 ti 2.88 Shall w itti Lt De osi 198 6452 a 0.04 15 tt 2.88 Shallow ittin . Lt. De sits. 199 6485 [I 0.03 1 Z u 2.88 00 6517 i! 0.03 i ; U 2.88 Shallow ittin . 201 6549 U 0.04 i ~ 2 2.87 Shallow ittin . 202 6580 U 0.03 l ; O 2.88 Shallow ittin . 203 6612 i? 0.03 1 ' 11 2.85 204 6644 t1 0.04 17 t) 2.91 Shallow ittin . 205 6676 t) 0.03 13 (I 2.92 Shallow ittin . 206 6707 t1 0.03 I ; U 2.85 Shallow ittin . 207 6738 { t 0.04 I ~ t ~ 2.91 Shallow ittin . 208 6768 tI 0.03 I ; ti 2.87 Shallow ittin . 209 6 O1 U 0.03 I.; tt 2.88 Shallow ittin Lt. De osits. 10 6832 t) 0.05 I~) t) 2.86 Shallow ittin . 211 6866 i) 0.03 I ; tI 2.91 Shallow ittin . 211.1 6898 U 0 t) t1 N A GLM 3 Latch @ 9:30 212 6904 (I 0.04 1 i I 2.87 Shallow ittin Lt. De sits. 213 6938 t I 0.04 I~ i i 2.92 Shallow i ti 214 6969 ~) 0.04 I d u 2.88 Shallow ittin Lt. De sits. 215 7001 ti 0.04 1 ~ ~. i .89 Shallow ittin Lt. De sits. 216 7033 U 0.03 1 S ! ~ 2.87 Shallow it 'n . Lt. De sits. 217 7064 l) 0.04 I.5 t i 2.90 Shallow corrosion. 218 7097 (1.Ur, 0.03 I _~ U 2.91 Shallow it ~n . 219 7129 t) 0.04 15 ti 2.92 Shallow ittin . 220 7161 t) 0.04 17 tI 2.87 Shallow corrosion. Lt. De osits. 221 7194 C) 0.03 I _; ii 2.90 Shallow ittin . 222 7226 U 0.03 11 ii 2.89 223 7258 ti 0.03 13 ii 2.88 Shallow ittin Lt. De sits. 224 7291 tl 0.03 I ; ~~ 2.87 Shallow it ~n Lt. De sits. 225 7320 tt 0.03 lam' ~? 2.86 226 7 53 U 0.04 14 a 2.91 Shallow ittin . 227 7385 U 0.03 12 (1 2.89 228 7417 U 0.03 13 U 2.86 Shallow ittin . 229 7451 t) 0.03 1 a 1 2.92 Shallow ittin . 2 0 7482 t) 0.03 1 "; lI 2.91 Shallow ittin . 231 7514 i1 0.03 11 U 2.86 231.1 7548 tl 0 U ti N A GLM 4 Latch ®7:00 232 7555 0 0.02 ~t ~t 2.87 233 7587 U 0.03 13 U 2.85 Shallow ittin . 234 7616 i) 0.02 ~) U 2.90 235 7648 U 0.14 54 _' .87 C rrosion at U set. Lt. De osits. 236 7682 t I.1 (1 0.04 1 i 1 2.86 Shallow corrosion. 237 7713 U 0.03 1 ; 1 Z.87 Shallow ittin Lt. D sits. 238 7746 a 0.03 1 ; tt 2.89 Shallow ittin . 239 7779 tl 0.03 11 tl 2.87 240 7811 ~? 0.04 16 fI 2.92 Shallow ittin . 241 7844 ~~ 0.04 15 ~ 2.90 Shallow corrosion. Lt. De o its. 242 7876 ~ ~ 0.03 1 1 Z 2.88 Lt. De osits. _ Penetration Body Metal Loss Body Page 5 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: ELATION SHEET 30-01 Kuparuk ConocoPhillips Alaska, Inc. USA August 31, 2008 Joint No. Jt. Depth (Ft.) I~'e•n. 111~~~~1 (Ins.) Pen. Body (Ins.) Pc~n. "/, M~~I,~I I os~ ~~ Min. LD• (Ins.) Comments Damage Profile (%walQ 0 50 100 243 7909 t1.t); 0.05 21 1 2.92 Isolated ittin . 244 7940 l) 0.05 lt?' t) 2.89 Shallow ittin . 245 7970 t) 0.04 14 t) 2.87 Shallow ittin . 246 8002 i~.lt1 0.04 15 l) 2. 9 Sh Ilow ittin Lt. e sits. 247 8034 tt 0.04 17 I 2.86 Shallow ittin . 248 8067 t) 0.11 -15 2.90 Isolated ittin . 248.1 8099 i t 0 (I t l N A GLM 5 Latch @ 8:30 249 8106 h 0.05 I ~I ~, 2.76 Shallow ittin De sits. 250 8139 t) 0.0 12 a 2.90 251 8169 a 0.03 12 I 2.90 252 8202 t).U5 0.04 I ~ ~~ 2.88 Shallow ittin . 53 8234 t? 0.04 I ; I 2.85 Shallow ittin . 254 8267 U 0.06 ?) ~ 2.84 Isolated ittin Lt. De sits. 255 8299 t) 0.11 -1_' i 2.85 Isolated ittin . Lt. De sits. 256 8332 tl 0.06 ~-t U 2.84 Isolated ittin . 257 8365 U.tlti 0.09 37 I 2.86 Isolated ittin . 258 8396 tl 0.11 d5 2.87 Corrosion. 59 8429 l).O7 0.10 40 I 2.84 Isolated ittin Lt De sits. 26 8462 u.t); 0.10 1~) _' 2.90 Isolated ittin Lt. De sits. 261 8494 tl.uh 0.10 -1U I 2.84 Corrosion. Lt. De osits. 262 8526 t) 0.08 ,? _' 2.85 Corrosion. Lt. De o its. 263 8559 O.Ub 0.07 ~- I 2.87 Isolated ittin . 264 8592 O.U6 0.06 ?~' I 2.88 Isolated ittin . 264.1 8623 O 0 U U N A GLM 6 Latch ~ 2:00 265 8635 O 0.05 1 ti tl 2.90 Shal ow ittin . 265.1 8666 U 0 0 U 3.00 AVA PBR 265.2 8675 U 0 0 U 3.00 AVA'RHS' Packer 266 8683 U 0.08 3(1 I 2.88 Corrosion. Lt. De osits. 266.1 8714 t~ 0 (1 U 2.75 D Ni le NO GO 267 8715 !t.tttt 0.08 ~ I I 2.85 Corrosion. Lt. De osits. 267.1 8743 u 0 t t ;~ N A SOS 267.2 8745 u 0 n ~~ N A TTL _ Penetration Body Metal Loss Body Page 6 PDS Report Cross Sections ,~ . Well: 30-01 Survey Date: August 31, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.2 f -55 8RD EUE AB MOD Anal st: M. Lawrence Cross Section for Joint 235 at depth 7649.894 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 98 Tool deviation = 43 ° Finger 8 Penetration = 0.137 ins Corrosion at Upset 0.74 ins = 54% Wall Penetration HIGH SIDE = UP Cross Sections page 1 ~ . .. .. ~ ~ . . .. ~ .. .. r . ~~ ~ ~+~ PDS Report Cross Sections Well: 30-01 Survey Date: August 31, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.2 f -55 8RD EUE AB MOD Anal st: M. Lawrence Cross Section for Joint 258 at depth 8422.163 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 98 Tool deviation = 39 ° Finger 6 Penetration = 0.114 ins Isolated Pitting 0.11 ins = 45% Wall Penetration HIGH SIDE = UP Cross Sections page 2 PDS Report Cross Sections ~1u ~~ „ Well: 30-01 Survey Date: August 31, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.2 ppf I-55 8RD EUE AB MOD Analyst: M. Lawrence Cross Section for Joint 161 at depth 5260.874 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 100 Tool deviation = 47 ° Finger 22 Projection =-0.27 ins Deposits Minimum I.D. = 2.60 ins HIGH SIDE = UP Cross Sections page 3 ConacoPhillips Alaska, Inc. KRU 30-01 30-01 API: 500292183600 Well T : PROD An le TS: 39 d 8789 sssv SSSV Type: TRDP Orig Com letion: 8/5/1988 Angle @ TD: 38 deg @ 9173 (t7as-t7a7, Annular Fluid: Last W/O: Rev Reason: TTL ELMD oD:3.5o0) Reference L Ref L Date: Last U te: 3/29/2008 Last Ta : 9007 TD: 9173 ftK6 Last Ta Date: 5/26/2005 Max Hole An le: 53 d 3700 Cas'n Strin -ALL STRINGS Gas LAt Descri lion Size To Bottom ND Wt Grade Thread MandrelNalve CONDUCTOR 16.000 0 115 115 62.50 H-40 t 3027 3o2a + SUR. CASING 9.625 0 5305 4066 36.00 J-55 - ( , PROD. CASING 7.000 0 9148 6871 26.00 J-55 Tubin Strin -TUBING Size To Bottum ND Wt Grade Thread Gas Lift 3.500 0 8736 6548 9.30 J-55 8RD EUE AB MOD MarareWalve © ~ Perforations Summa 2 (5a9s-5497 Interval TVD Zone Status Ft SPF Date T e Comment , 8832 - 8847 6623 - 6634 A-3 15 12 4/28!1989 IPERF 2 1/8" EnerJet; 60 d h 8850 - 8866 6637 - 6649 A-2 16 12 4/28/1989 IPERF 2 1/8" EnerJet• 60 de h 8890 - 8910 6668 - 6684 A-1 20 8 10/3/1988 IPERF 4.5" C Gun 45 de h Gas Lift , Ga s Lift M andr els/Valve s '^~~~^"~y Valve 3 ~&~9 St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt ( ' OD:5.313) 1 3027 2569 MMH FHMO GLV 1.0 BK 0.156 1289 7/29/2001 2 5496 4194 MMH FHMO OV 1.0 BK 0.188 0 1/20/2005 3 6888 5148 MMH FHMO DMY 1.0 BK 0.000 0 5/2/1998 cas Lift 4 7536 5633 MMH FHMO DMY 1.0 BK 0.000 0 10!3/1988 irxtrel/Dummy 5 8087 6050 MMH FHMO DMY 1.0 BK 0.000 0 5/2/1998 valve4 7536 7537 - 6 8611 6451 Otis LBX DMY 1.5 RM 0.000 0 5/2/1998 ( - , OD:5.313) Oth er u s ui .et c. - JEWE RY D® th ND T e Descri lion 10 1786 1698 SSSV Camco'TRDP' 2.812 Gas LiR 8652 6483 PBR AVA 3.000 irnNel/DUmmY - ] 8666 6494 PKR AVA'RHS' 3.000 valves ( 8702 6522 NIP Camco'D' Ni le NO GO 2.750 OD75.383) 8735 6547 SOS Baker 2.992 8736 6548 TTL ELMD 8745' SWS 8/4/1988 2.992 Gas Lift i rxtrellDUmmy VeNe 6 (S6t t-a6i2, OD:5.940) PBR (8652-8653, OD:3.500) PKR (8666-8667, OD:6.151) NIP ~ (8702-8703, OD:3.500) TUBING (0736 , OD:3.500, ID:2.992) SOS (8735-8736, OD:3.500) Pere (8832847) Pert (8850.8866) ~rt (easo-asto) • C011000Pf'1l I I l p5 Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 30, 2008 '~ All G ~ ~ Z~fJ8 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • I~`~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 27, 2008. The corrosion inhibitor/sealant was pumped July 3 and July 30, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, /f~~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ., Date Kuparuk Field 7/30/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1Y-06A 197-134 6" NA 6" NA 1 7/3/2008 1Y-08 183-062 6" NA 6" NA 1 7/3/2008 1Y-18 193-106 15" NA 15" NA 1.7 7/3/2008 1Y-19 193-107 25" NA 25" NA 4.25 7/3/2008 1 Y-23 193-071 14" NA 14" NA 1.7 7/3/2008 1 Y-25 188-089 12" NA 12" NA 2.5 7/3/2008 30-01 188-073 SF NA 16" NA 3.5 7/30/2008 30-02A 207-158 SF NA 15" NA 3.1 7/30/2008 30-03 188-075 SF NA 16" NA 3.2 7/30/2008 30-06 188-060 18' 4.90 18" 7/27/2008 5.25 7/30/2008 30-08 188-064 9' 4" 9.50 36" 7/27/2008 25 7/30/2008 30-10 188-059 15' 3.00 16" 7/27/2008 6.3 7/30/2008 30-11 188-042 53' 5.90 46" 7/27/2008 12 7/30/2008 30-13 188-040 SF NA 12" NA 2 7/30/2008 30-15 188-031 32' 5.80 23" 7/27/2008 5.3 7/30/2008 30-18 188-026 39' 5.30 18" 7/27/2008 10 7/30/2008 ) ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 1. Operations Performed: P. O. Box 100360 7. KB Elevation (ft): RKB 59' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth measured true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR SUR. CASING PROD. CASING Length 115' 5246' 9089' Repair Well 0 Pull Tubing 0 Operat. ShutdownD Stimulate 0 Other 0 Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 188-073 6. API Number: 50-029-21836-00 Plug Perforations 0 Perforate New Pool D Perforate D 4. Current Well Status: Development - 0 Stratigraphic D Exploratory D SeNiee D 9. Well Name and Number: 30-01 10. Field/Pool(s): Kuparuk Oil Pool 9173' feet 6890' feet 9173' feet 6276' feet Size MD 16" 9-5/8" 7" Plugs (measured) Junk (measured) Burst TVD Collapse 115' 115' 5305' 4066' SCAN~~D FEB 0 4: 2~a~1' Perforation depth: Measured depth: 8832-8847',8850-8866',8890-8910' RE EI\/E FEB 0 :~ 2005 true vertical depth: 6623-6634',6637-6649',6668-6684' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 8736' MD. Alaska Oil & Commission Anchorage Packers & SSSV (type & measured depth) pkr= AVA 'RHS' pkr= 8666' sssv= SSSV SSSV= 1786' 12. Stimulation or cement squeeze summary: Intervals treated (measured) SCANNED FEB U 4 zoû~ Treatment descriptions including volumes used and final pressure: N/A Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 200 600 200 600 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: IY/ ¡j Contact Brad Gathman/MJ Loveland @ 659-7224 Printed Name MJ Lovelan~ / / Title Signature ~ ~!'. Phone Form 1 0-40~Vised 04/2004 13. Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Oil-Bbl 250 250 Casinq Pressure 1184 1184 Tubinq Pressure 166 166 WDSPLD Problem Wells Supervisor 907-659-7224 Date ~~ ~JfM}~ S- . RBDMS 8Ft FEB 0 ~1 700~ Submit Original Only ) 30-01 DESCRIPTION OF WORK COMPLETED SUMMARY ) Date Event Summary 1/20/2005 DRIFT TBG W/2.79" GAUGE RING TO 8680' SLM(87021 RKB). SET 2.751' A-2 PLUG @ 87021 RKB. TEST TO 2500 PSI. PASSED. PULL 1" OGLV @ 5496' RKB(STA #2). LOAD & TBG/IA W /200 BBLS DIESEL. SET 1" OGL V @ ST A #2(5496' RKB. TEST TBG TO 2500 PSI. PASSED. BLEED DOWN TBG/IA TO 300 PSI 1./21/2005 Prep for BH weld, R&R internal checks on Tubing and IC hanger test and PO ports. T/I/O = 100/150/550 Bled TBG, IA and OA to 0 psi, pulled IA & OA VR plugs and installed BV's. OA FL is around 501. Will need to top off with diesel in the A.M. (Tri-Plex ran out of diesel). DSM removed floor kit, hard line loop and placed heater trunk in cellar. 1/22/2005 Continue BH weld prep, TIIIO= 10010/25 Bleed down OA and liquid pack OA with diesel to 2' of weld area. Remove floorkit, Drill 1/211 hole in conductor, cement at surface. Ready for BH welding. 1/2412025 Bradenhead weld, Initial TIIIO= 1001010 make three welding passes as per procedure around BH while purging N2 accross IA x OA 1/25/20051 Normal well back up, reinstall VR plugs etc, MITOA to 1800 psi - good test MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner THRU: DATE: Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector January 26, 2001 Safety Valve Tests Kuparuk River Unit 30 Pad F. ridav, January 26, 200.1.: i traveled to the Kuparuk River Field and witnessed the 90-day retest of the safety valve systems on 30 Pad. As the attached AOGCC Safety Valve System Test Report indicates i witnessed the testing of 12 wells and 24 components With one failure observed. The Low pressure pilot on WAG injector 30-05 tripped below the required set point. This pilot was retested and passed at the the time of this test. Eamie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with All the wellhouses entered at this location were clean and all related equipment appeared to be in good condition. Summary:. I witnessed the 90-day SVS testing at 30 Pad in the Kuparuk River Field. KRU 30 Pad, t2 wells, 24 components, 1 failure 4.1% failure rate 12 wellhouse inspections Attachment: SVS KRU 30 Pad 1-26-01 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 30 Pad 1-26-01CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: PhilliPs Operator Rep: Eamie Barndt AOGCC Rep: Chuck Scheve Submitted By: '"dh~ck Scheve Field/Unit/Pad: Kupamk../,KRU,/, 30, Separator psi: LPS 67 Date: 1/26/01 liPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number psI' . PSI Trip , Code. ,, Code Code,_ Passed, GAS or CYC,LE 30-01 1880730 67 70 80, P V OIL 30-02 ' 1880740"' ~ '' 70 " 60 P P ...... OiL 30-03 1880756 '' 67. ' 70 ' "60 P P , , , 30-04 1880620' ' 6,7 70 "6'5,,'P 'P" , , , ,OIL 30-06 1880600 30-08. ', 1880640. , 67 , 70, . '70, ,' , P", P. ........... , .., .., , , ~iL 30-09 1880610 67 70 40 P P OIL 30-11 " 1880i2b 6~ ' '70 '" 60 P ..... P ..... 0iL 30-13' 1880400 67 70 60 'P P .... OIL 30.14 ' 1880390 ............. ~0-15" 1880310 ' - 67! 70 '" 70' ' P "' P OIL 30-18 1880260 6~i 70 55 P P OIL 30-20' ' '19704~0' 67:" 70 ' ~0' P ' P' '' OIL 30-05 1880760 3750:' ' 2000" ' 11'00 ..... 3" P "' 1/26/01 WA~ Wells: 12 Components: 24 Failures: 1 Failure Rate: 4.17% [] oo Oar Remarks: Pilot on WAG injector 30-05 tripped below required set pressure. Pilot was retested and passed this date. RJF 1/16/01 Page 1 ofl SVS KRU 30 Pad 1-26-01 CS.xls MICROFILMED 10/12/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__~X Pull tubing _ Alter casing _ 5. Type of Well: Development Exploratory Stratagrapic _~. Service 2. Name of Operator: ARCO Alaska, Inc, 3. Address: P.O. Box 100360 Anchorage, AK 9.9510-0360 4. Location of well at surface: 724' FNL, 1842' FWL, Sec 22, T13N, R9E, UM At top of productive interval: 1206' FNL, 594' FEL, Sec 16, T13N, R9E, UM At effective depth: 1062' FNL, 696' FEL, Sec 16, T13N, R9E, UM At total depth: 1008' FNL, 735' FEL, Sec 16, T13N, RgE, UM Plugging _ Perforate _ Repair well _ Other _ 6. Datum of elavation (DF or KB feet): 60' RKE 7. Unit or Property: Kuparuk River Unit 8. Well number: 30-01 9. Permit number/approval number: 88-73 10. APl number: 50-029-21836-00 11. Field/Pool: Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured true vertical Effective Deptt measured true vertical Casing Length Conductor 80' Surface 5270' Production 9113' Liner 9173 feet 6889 feet 9065 feet 6805 feet Plugs (measured) None Junk (measured) None Size Cemented Measured depth True vertical depth 16" 200 Sx AS II 115' 115' 9-5/8" 1250 Sx AS III & 5305' 4066' 370 Sx Class G w/80 Sx AS I top job 7" 200 Sx Class G 9148' 6870' Perforation Depth measured true vertical 8832'-8847',8850'-8866',8890'-8910' 6623'-6634',6637'-6650',6669'-6684' Tubing (size, grade, and measured depth) 3.5", 9.3 Ib/ft, J-55 @ 8736' Packers and SSSV (type and measured depth) Packer: AVA RHS @ 8666'; SSSV: Camco TRDP @ 1786' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sands on 5/4/98. Intervals treated (measured) OF IGINAL 8832'-8847', 8850'-8866', 8890'-8910' Treatment description including volumes used and final pressure Pumped 210,765 lbs of 16/20 and 12/18 ceramic proppant into formation, fp was 5750psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 615 348 709 1410 206 Subsequent to operation 732 472 978 1277 207 15. Attachments MIT form 116. Status of well classification as: Copies of Logs and Surveys run _ I Daily Report of Well Operations _~X Oil _X Gas _ Suspended _ Service _ 17. I hereby ~certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ Title: Production Engineering Supervisor Date '~/~/~ '~ , Form 10-404 Re~ 06}~15/88 SUBMIT IN DUPLICA~ b' ARCO Alaska, Inc. ~-~' ,KUPARUK RIVER UNIT · ~, .-,,ELL SERVICE REPORT ~' K1(30-01(W4-6)) WELL JOB SCOPE JOB NUMBER 30-O1 FRAC, FRAC SUPPORT 0421980509.1 DATE DAILY WORK UNIT NUMBER 05/04/98 PUMP "A" SANDS REFRAAC DAY OPERATION COMPLETE ! SUCCESSFUL KEY PERSON SUPERVISOR 3 (~) Yes O NoI (~ Yes (~ No DS-YOKUM JOHNS FIELD AFC# CC# DAILY CO ST AC CUM COST Sign ed~, ~------~ ~ ESTI MATE KD2105 23ODS36OL $133,391 $157,597 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Anr~ '1 Final O~ter Ann 1200 PSI 1800 PSI 500 PSI 500 PSII 50PSII 100PSI DAILY SUMMARY PUMPED "A" SANDS REFRAC WITH 210'765# PROPPANT 12/18 ' 14 PPA TO PERFS' FLUSHED TO COMPLETION ' LEFT524 # PROPPANT IN PIPE. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP., HOT OIL PUMP AND APC SUPPORT. 08:02 HELD JOB SITE SAFETY MEETING. 08:19 PRESSURE TEST TREATING LINE TO 9900 PSI. 08:24 PUMP BREAKDOWN WITH 112 BBLS 50# GEL AT 30 BPM AND 8435 PSI TO 5400 PSI. 08:29 PUMP 3017# OF 16/20 PROPPANT 1 PPA FOR SCOUR AT 15 BPM AND 4930 PSI. 08:31 PUMP 50 BBLS CONDITION STAGE AT 15BPM AND 4765 PSI. 08:34 PUMP 5790# OF16/20 PROPPANT 2 PPA FOR SCOUR AT15 BPM AND4820 PSI. 08:38 PUMP 50 BBLS GEL AND122 BBLS SEAWATER FOR FLUSH AT 15 BPM AND 5479 PSI. SHUTDOWN ISIP 2163 . PSI. PUMP PULSE TEST.' 10:00 PUMP DISPLACEMENT , DATA FRAC AND FLUSH , WITH 100 BBLS GEL AND92 BBLS SEAWATER. SHUTDOWN ISIP 2115 PSI. . 11:06 PUMP500 BBLS PAD OF 50# GEL, 5 TO 1'5 BPM AND 4692 PSI. 11:48 PUMP 21000 #-OF 16/20 PROPPANT AT 2 PPA ,. 15 BPM AND 5254 PSI. 11:57 PUMP 190,289 # OF.12/18,6 PPA TO 14 PPA TO PERFS. 12:55 PUMP FLUSH TO COMPLETION, LEAVING 43 BBLS DIESEL CAP ON TUBING. 12:59 SHUT DOWN AND RDMO. NOTIFIED LEAD OPERATOR WELL WAS FLUSHED AND READY TO PUT ON PRODUC . - ,. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $824.00 APC $7,700.00 $12,700.00 ARCO $500.00 $500.00 DOWELL $123,591.00 $130,591.00 HALLIBURTON $0.00 $6,542.00 LITTLE RED $1,600.00 $6,440.00 TOTAL FIELD ESTIMATE $133,391.00 $157,597.00 TONY KNOWLES, GOVERNOR ST.XTE PIPELINE COORDINATOR'S OFFICE i Del3artment of Environmental Conservation : Department of Natural Resources -- Department of Fish and Game 411 WEST 4th AVENUE. SUITE 2C ANCHORAGE, ALASKA 99501 PHONE: (9073 2788594 (9073 278-8595 FAX: (9073 272.-0690 August 25, 1995 File #' 300.15.051 Letter #: 959arco.irc Mr. Donald Puckett Kuparuk Production Manager .x~RCO Alaska. Inc. Post Office Box 196105 Anchora_~e. A.K 99519 Dear 5Ir. Dackea: Re: Kuparuk Drill Site 30 Post-Closure Monitoring Reserve Pit Closure Approval The Alaska Department of Environmental Conservation (ADEC) has received your annual post- closure monitoring report for the Drill Site 30 reserve pits, dated November 28. 1994, and your request for written approval for closure of the drilling waste facility.. This is the rifT& and f'mal annual report for the drill site, as required bv Solid Waste Permit #8736-BA016. Upon review of the submitted thermistor and water quality monitoring data. ADEC agrees with your assessment that freeze-back of the drilling wastes and adjacent overburden has been maintained at the 30 reserve pits. Consequently, .~RCO Alaska. Inc. has complied with the stipulations of the closure plan def'med in_Pern'fit #8736-BA016. and with all post-closure monitoring requirements. The Department's decision upon the request submitted bv ARCO Alaska. Inc. is to approve for closure the drilling waste facility. (reserve pits) at Drill Site 30. The site was inspected by the Alaska Department of Natural Resources (ADNR) on August 23, 1995. This decision is supported by ADNR: the agency agrees with and expresses no concern with closure of the site. The approval granted by this letter is for closure of the drilling waste :eserve pits only, as required under 18 AAC 60.500(b) and 60.520(g). Closure of the pad as a whole must be coordinated between the owner/operator and the appropriate state (ADNR, ADF&G. AOGCC), or federal (BLM) agency. Additionally, should anv contamination from historic spills be found on the pad outside the drilling waste site (reserve pit area), notification needs to be made to the ADEC/SP,~aR Contaminated Sites Section (1269-7659). Should additional information concerning environmental conditions ar the facility make further actions necessary to protect human health or the environment, the Department reserves the right to require additional investigation, assessment, monitoring, or remediation at the facility. Notwithstanding any other'provisions or requirements of this closure approval, a person causing or permitting the discharge of oil or other hazardous substances is required by law to mediately contain and clean-up the discharge (AS 46.04.020: 46.09.020). If you have any further questions, please contact James Chatham at 271-4339. Sincerely, C-"~TTom ~ 5 Chapple Manager, Lndustrv Preparedness and Pipeline Program .CC' TC/JRC Randy Kanadv..~d~CO Alaska. Inc.",,Anchorage Joe Saumer. ADEC',Anchorage Heather Stockard. ADEC'Juneau Nancy Welch. ADNR',Fairbanks A10tt. ,4,DFG'xFairbanks Jim Haynes. ADNR\Anchorage Keith Mueller, USFWS\Anchorage Jessie Kaleak Sr.. Mayor NSB\Barrow STATE OF ALASKA Al .... '~A OIL AND GAS CONSERVATION COMP 'iON REPOh I' OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Stimulate X Pull tubing Alter casing Repair well Plugging Perforate Other 2. Name of Operator ARCO Alaska, In(;;. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 724' FNL, 1842' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1206' FNL, 594' FEL, Sec. 16, T13N, R9E, UM At effective depth 1206' FNL, 594' FEL, Sec. 16, T13N, R9E, UM At total depth 1008' FNL, 735' FEL, Sec. 16, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 91 73' feet Plugs (measured) 6889' feet Effective depth: measured 9065' feet Junk (measured) true vertical 6805' feet Casing Length Size Cemented Conductor 1 1 5' 1 6" 200 Sx AS II Surface 5305' 9 5/8" 1250 Sx AS III & 370 Sx Class G Top job w/80 Sx AS I Production 91 4 8' 7" 200 Sx Class G & Perforation depth: measured 8832'-8847', 8850'-8866' & 8890'-8910' true vertical 6623'-6634', 6637'-6650' & 6669'-6684' Tubing (size, grade, and measured depth) 3.5" 9.3# J-55, EUE 8 RD, ABMOD, Tail @ 8736' Packers and SSSV (type and measured depth) SSSV: Camco TRDP, 1786', Packer: AVA RHS, 8666' 6. Datum elevation (DF or KB) 60' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 30-01 9. Permit number/approval number 88-73 10. APl number 50-029-21836 11. Field/Pool Kuparuk River Oil Pool Measured depth True ve~ical depth 115' 115' 5305' 4066' 9148' 6870' 13. Stimulation or cement squeeze summary 14. REE£1VED AU G 4199 Alaska Oil & Gas Cons. C,0mmt~o'"" Intervals treated (measured) Anchorage Perforated interval. Treatment description including volumes used and final pressure Refractured A Sand w/112.0 M LBS proppant & 930 BBL gelled sea water. Final pressure 8000 psi. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 1301 785 0 - 1 1 20 142 Prior to well operation 2154 1449 22 1120 142 Subsequent to operation 16. Status of well classification as: Water Injector__ Oil x Gas Suspended Service 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date SUBMIT IN DUPLICATE Si~ned C, ~J, ~ Title, ~':,~3e' Engineer Form 10-404 Rev 09/12/90 ~RCO Alaska, Inc.~ S'~*osidiary of Atlantic Richfield Compare, WELL SERVICE REPORT WELL CONTRACTOR REMARKS I PBDT FIELD- DISTRICT- STATE I DAYS ;OPERATION AT REPORT TIME DATE I# /:CEIVED Alaska Oil & 6as Cons. Commission knots ~uuJJUrag8 APR-18-'90 10:28 ID:KRU/CI/NU/DRILLING TEL N0:907-265-6218 . , NOTE8 T. 1~ ~, R. 9 ~, UMIAT MErIDiAN. 6. HO, IZONTn~ MONUMENTS ........................ O,ST. 'OiST. "gA_... "i' D Well Y A $P$ X LATITUDE~,~_.. LONGITUDE E NL ~WL I 6,02 2,095. Zl525~478.27 70~8' 17,358' 1490 47' $0.897" 724* 164~' t?.5' 23,9' 2 6,022,073.89 $25,490.94 700 ?.8' 17.128" i 49047'~0.5~'' 745' 1855'I I 6,021,965.~ 5~5~553.~ !~9 14~47 28 $~ eS~; 1917, 18.~, . 14g_ 47,~8.~, 87[ 19~, , 6,0~l ,943, 75 5,,~.~ ~, ~ ' ' ~ 6,021 ~a. 12 5~ t578.~7 i5.6~Z 149;47 ~7,~74,, ~7 1941 18.4 I0 6tOZ t ,84~ ~ 525,623.61 ~28' 14.~3" 149e47'Z6.6~ 975' 1986' 18.?' I I 6,0~ I ,822. ~ 525 ~635.71 ~' 14.651" 149° 47'Z6.zg~" 1998' 18. 8' 23.5' 13 6,0Z ,7T9. 16 525 ~661 ,~ ~e~, 14, ZZ~' 149047,25.~. 1041. ZOZ4, ~4.0~0~ ~o~, ! 5 6~0~ ~048, ,735. ?6 5~5 ,~6. I2 t3.~5 149°47 24.~ 1064: I~.0, 16 6,0~ I)?14. I~ 5Z5~698.17 ~e~8' I~.~" 149~47'~4.4~" I1~ ~0~, 19.1 17 6,0~1,69Z.~ 5Z5,710.85 ~M* 13,~69" 149e47'Z4.0~' 112~ ~073 19.0' 2[9' 18 6,0~ I ,670.97 5~5,7~,~ ~28' 1~. t57" 149°47'~.7~" 1149' Z~5' 19.0' ............. iii I HEI~BY CERTIFY THAT I AM PROPERLY RI[GISTEREC) ANC) UCENSED TO PRAC- TICE LAND SURV~ING IN 'THE dl,'~"~ t%F J~i ~1.~ STATE Of *LASKA ANO THAT THiS PLAT REPRESENTS A .lOCATiON SUlkilY UADE BY ME ON UNDER. _a"'/.TM; ' ' ' '.,~'~ DIMENSIOM ANO OTHF. R OETNI,~ a ~ ' " .,, '~:~ '...,,...,. Alaska Inc. D.S. 3.0 WELL CONDUCTOR AS-BUILT LOUNSBURY 6 Associates ~ AJR ADDENDUM WELL: 9/09/88 2/lo/89 2/19/89 30-1 Rn CBL and gyro (no depths available). Fsh out E-line tool string w/JB. Frac Kuparuk "A" sand perfs 8890'-8910' in seven stages per procedured dated 1/16/89 as follows: Stage 1: Pmp pre-pad w/150 bbls gelled diesel at 0-17 BPM, 500-6200 psi Stage 2: Pmp 600-620 bbls gelled diesel @ 25 BPM, 3380 psi Stage 3: 65 bbls gelled diesel, 2 ppg 16/20 Carbolite @ 25 BPM, 3460 psi Stage 4: 80 bbls gelled diesel, 4 ppg 16/20 Carbolite @ 25 B?M, 3360 psi Stage 5: 90 bbls gelled diesel, 6 ppg 16/20 Carbolite @ 25 BPM, 3340 psi Stage 6: 100 bbls gelled diesel, 8 ppg 16/20 Carbolite @ 25 BPM, 3340-3400-3800 psi Stage 7: 76 bbls gelled diesel flush Frac pressure started increasing rapidly at end of 8 ppg slurry stage w/9.9 ppg at well. Cut slurry early and went to flush. Fluid to Recover: 1100 bbls Sand in Zone: ±60,000# Sand in Csg: ±2000# RU CTU, tst BOP & hardline to 4000 psi. TIH, tag hard bridge @ ±5800'. Inc rate to 1.25 BPM, wsh bridge to ±5950'. Cont in hole to TT. Wsh small amount of sand to 9045' CTM. POOH. Secure well. Drilling ~upervi~or 9ate ARCO Alaska, Inc. Date: April 5, 1989 Transmittal Ct: 7457 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 O- 01 Kuparuk Well Pressure Report 3 - 26 - 89 Sand 'A' 30-06 Kuparuk Well Pressure Report Sand'A' 30-09 Kuparuk Well Pressure Report 2- 1 5-89 Sand'A' 30-02 Kuparuk Well Pressure Report 2- 1 9-89 Sand'A' 2 Z - 13 Kuparuk Well Pressure Report 3 - 24 - 89 Both Sands 2 Z- 13 Kuparuk Well Pressure Report 3 - 24 - 89 Sand 'A' 2 Z - 01 Kuparuk Fluid Level Report 3 - 21 - 89 Tubing 2 D- 16 Camco BHP Report 3 - 09 - 89 BHP 2 D - 14 Camco BHP Report 3 - 09 - 89 BHP 30-02 Sub-Surface Pressure Report 2-1 9-89 #64613 30-09 Sub-Surface Pressure Report 2-1 9-89 ct64613 30-06 Sub-Surface Pressure Report 2-20-89 ct29855 Receipt Acknowledged: DISTRIBUTION; D&M State of Alaska SAPC Mobil Chevron Unocal STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ 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. 88-73 3. Address 8. APl Number P.0. Box 100360, Anchorage, AK 99510-0360 50- 029-21836 4. Location of well at surface 9. Unit or Lease Name 724' FNL, 1842' FWL, 5ec.22, T13N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1206' FNL, 594' FEL, Sec.16, T13N, R9E, UM 30-1 At Total Depth 11. Field and Pool 1008' FNL, 735' FEL, Sec.16, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 59'J ADL 25513 ALK 2554 12. Date Spudded07/27/88 13. Date T.D. Reached08/03/88 14. Date Comp., Susp. or Aband.02/10/89* 115' water Depth' if °ffsh°reN/A feet MS L 116' N°' °f C°mpleti°nsl 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 9173'MD/6889'TVD 9065'MD/6805'TVD YES ~ NO [] 1786' feet MD 1700' (annrn×~ , 22. Type Electric or Other Logs Run SFL/DIL/SP/CNL/Cal/GR~ CBL~ Gyro 23. CASING, LINER AND CEMENTING RECORD ,, SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE !TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 5,,rf 115' 2~" 200 sx AS II 9-5/8" 36.0# J-55 Surf R~I3R' !2-!/a.'' !250 SX AS !I! & ~70 ~, Clas;, C Top .fob .../~n ^¢ . · ,, -,v ~,X ,,.., , 7" 26.0# J-55 Surf 91~,R' R-1/9', 9n~ ~, r'l =~ n 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) Perforated w/8 spf, 45° phasing 3-1/2" 8736' 8666' 8890 ' -8910 'MD/6667 ' -6683 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Adden(um, dated 2-17-89 for fractule data. 27. N/A PRODUCTION TEST Date First Production I Method of Operation {Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD e I Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. F t;_ i:.::', ~. ....... NOTE: Drilled RR 8/5/88. Perforated well and ran tubing 10/03/88. Fractured well 02/10/89. ,Ja~J(a .0il .& Gas Cons. .u,~.,~,,d,~,~,u~,r'"' '' Anchorage Form 10407 002/WC6 Submit in duplica~l~ ~ Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC'MARKERS · - "- ' ' ,':' ' . - FORMATION TESTS ,- ~. . .:.'- . . ...- ~ .... ~ : .... -..- __;,. : . ,-,. . ~-' - . · ...- :.: .... . ..... . ~.- . ,,': ;~.: ~' .....,.? . . . . . . · ,, · . . ' . , .. · NAME ' ' ' Include interval tested, pressure data, all fluids recovered and gravity, . . MEAs.'DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8~81' 6582' N/A Base Kuparuk C 8809' 6604' Top Kuparuk A 8.820' 6612' Base Kuparuk A 8952' 6716' ! .- .. 31. LIST-OF ATTACHMENTS Addendum (2/17/89) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~)~ ~ .__ TitleArea Drillin§ Engr' 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 (D.F, 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~,07 ADDENDUM WELL: 9~09~88 2110/89 30-1 Rn CBL and gyro (no depths available). Fsh out E-line tool string w/JB. Frac Kuparuk "A" sand perfs 8890'-8910' in seven stages per procedured dated 1/16/89 as follows: Stage 1: Pmp pre-pad w/150 bbls gelled diesel at 0-17 BPM, 500-6200 psi Stage 2: Pmp 600-620 bbls gelled diesel @ 25 BPM, 3380 psi Stage 3: 65 bbls gelled diesel, 2 ppg 16/20 Carbolite @ 25 BPM, 3460 psi Stage 4: 80 bbls gelled diesel, 4 ppg 16/20 Carbolitc @ 25 BPM, 3360 psi Stage 5: 90 bbls gelled diesel, 6 ppg 16/20 Carbolite @ 25 BPM, 3340 psi Stage 6: 100 bbls gelled diesel, 8 ppg 16/20 Carbolite @ 25 BPM, 3340-3400-3800 psi Stage 7: 76 bbls gelled diesel flush Frac pressure started increasing rapidly at end of 8 ppg slurry stage w/9.9 ppg at well. Cut slurry early and went to flush. Fluid to Recover: 1100 bbls Sand in Zone: ±60,000# Sand in Csg: ±2000# ' Drilling gupervisdr ~ Da{:e ' STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report in__~2ec tor Operator ~j ~ C...C..~ Location; Sec Z~- T.l]~.~_~ff M Drillin~ontractor 'L~cation, General Well Si General Housekeeping ~'""Rig Reserve Pit Visual Audio · . · Mud Systems -- 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 wen ~o- L Represent at ire_ _ ~,V£ CMIdaffOtX/ Permit I ~-~3 t iV ~resentative~( ~ ACCU~LATOR SYSTEM Full Charge Pressure .... ~~ _~ psig. Pressure After Closure~(~O _ psi~ Pump incr. clos. pres. 200 psi~ min~sec. Full Charge Pressure Attained:~_ ~ ~in[O sec. s2~,Z~oO _ ~.-zqO, O ~ I-Z~O psis "Remote ~'~ Blinds s~itch cover Ke!ly ~n~ Floor safety Valve~ Test Pressure ~0 Test Pressure ~00O Upper Kelly ~ ~ Lower Kelly ~ Test Pressure_ ~(~OO Ball Type { Test Pressure ~300 Inside BOP [ Test Pressure ~00(~ Choke Manifold_ ¥~ _Test Pressure_ No. Valves I~ No. flanges__?~-- Adjustable Chokes 1 ,drauicallx_~erated choke~ Test Time _,,,~- _hrs. Test Results: Failures Repair or Replacement of failed equipmint to. be made within days and Inspector/ Commission office notified. ~- ~~ ~z~'l l~ Remarks: . Distribution ~rig. - AO&c'cC cc - Operator cc - Supervisor Inspector October 10, 1988 Mr. Randy Ruedrich ARCO Alaska, Inc. P..O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-80095 Well: 3-o-1 Field: Kuparuk Survey Date: September 8, 1988 Operator: T. McGuire Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic 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 Enclosure NI. Sperry. Sun/NL Industries, Inc. RO. Box 231649, Anchorage, Alaska 99523-1649 Tel. (907) 522-1737 ANCHORAGE ALAoKA ARCO ALASKA, I NC DATE OF SURVEY SEPTEMBER 8, . KUPARUK FIELD SEPTEMBER '~, 1~8:B ,_lOB NUMBERAK-Bu-c,(.)O" - '-" "~, ._ ALASKA KELLY BIJSHING ELEV. = 5S~. 00 FT. ...................................................... . .............. ................................ TRUE .... _:~~ ......... COURSE,. C.O~!RS~ ~E~.SURED VERT[C~L VERT[C~L INC:LIN~TION DIRECTION SEVERITY RECT~N'GL~L~R C:OORDI N~TES VERTICAL DEPTH DEPTH DEPTH DEG M Z N DEGREES DEG/1 O0 NORTH/SOUTH E~ST/~EST SECT Z ON o o. oo -5~ o6 o 0 N o' o E 0. O0 O, 00 O. O0 O. O0 100 100.00 41.00 0 :36 N ~ . 0 05 ~6.69 E 0 60 0.29 N 0.44 E . 200 1 $~9. ~g 140.5~'~ 0 40 N = . :-~= O, 0.~ .... C), '~ ~. N .... !~.~:~,.. ~. ................... 0,.1.~ ·· ;~,4, 6(~. E :~(')0 ..... 2'~t~. ~8 240. ~8 0 57 N~.=,'-"~' 60 E 0. ~ 1 2.01 N 2.16 E 0.8(]. 400 3'~. 'P6 340. ~6 I 30 N 4.1 C) E 0.6'P 4. (:)'~ N 2.5'~ E 2.45 500 49~.87 440.87 3 3 N 8. 0 W 1.63 8. C)6 N 2.40 E 6.06 ~,50 ~,49.77 4'~0 77 4 4 N 11 8'~ W 2 10 11 11 N 1 "=' ....... ~,.00 5~'~.62 540.62 4. 54 N. 13_ ...... 0 ~ ~ 6'~ . .~4.,'~'~ . . . . ~.~ N ........... ~, ~)(). ~ .................... 1..~ .......... 700 6t~ 02 640 "-' '- (.)~ 7 ~5 N 16 8t~ W 2 = -- . .~,4 25 .-,o N 1 84 W ~:~:.31 800 7~7.82 738.82 10 16 N 14.50 W 2.o.~'~5 40.10 N 5."=~, W 38.37 900 '-'~'= o7~, ~4 836 t~4 11 54 N 1~'~ · _ ....... . c. :~:~ W ~ =c, ~.=. ...... ~~.~ N ._~ .... 57. 1000 '~3.2~ ~34.2~ 14 23 N 13.80 W 2.4~ 80.8~ N 15.'R4 W 7~.20 1100 108~.20 1030.20 18 24 N 16.60 W 4.0~ 108.11 N 23.42 W 106.82 1200 ..... ~ ~8~.,.00 ~_!.2~,._s~ __ 22 6 _. N .! 6. ~. W ........... ~..T~ .......... ~.~ ........... ~~....W ...........~ ..... 1300 1275.14 1216.14 23 35 N 14.30 W 1.7~ 178.66 N 43.82 W 178.87 1400 1366.14 1307.14 25 22 N 12.1 t~ W 1. ~'~ 218. t~t~ N 53.2?/ W 21 t~. 06 . ....~6~. N 62.87 W . . 262.48 1500 1455 46 13~6.46 28 3 N 12.3~ W ... 2.67 ....... '~ ~ ~1 ............. 1600 1542.44 1483.44 31 3 N 13.30 W 3.03 310. ~8 N 73.85 W 310. 24 1700 1627.08 1568.08 33 16 N 15. 0 W 2.40 362.58 N 86.88 W 362.07 ............. ~_~.0~_ ~7_0~.~4 .~6~.~}.__~ ............. >~ ........ ~? ....... ~_. 17.50 W ........... Z.'B3 ____~0.~ .......... I(~.~,B_ W ............ ~17.78 .... 1 ~00 1788. ~3 172~. ~3 38 ~ . :_~. ._1 N 17 1~ W - 04 474.8~ N 120.87 W 477.47 2000 1864. :B~ 1805.8'~ 42 15 N 18.1 '~ W 3.46 536.82 N 14(). 65 W 541.58 2100 1~37.56 1878.56 44 ~P ....... ~~~ __ 2.36 .............. 6().~ _N ........ 16~..Z4 N ............ ~~~ 2200 2008.46 1'P4~. 46 45 12 N 23.50 W 3.05 667.47 N 188.48 W 67~. 62 2300 .2077. ~1 2018. ~1 46 48 N 25.80 W ::.,,.~..~.:~::~.~?~.~. 30 732.84 N 218· 4~ W 751.47 .............. ~400 2!46. ~4 ~.8~.1.~ ........ 4Z ...... ~ .......... N_ 25.80 _.N 0.50 ....... 7'~._80_ _N ............. Z~.O..~_ W ....... ~.__ -- m -- m m I ~m~ 2500 ~213 81 ~154 81 47 40 N 24 50 W 0 7Sx 86~ ~7 N 281 02 W 898.11 26C)0 '~ ~"~ . ' ...... . ..... ~1 10 ~.10 47 45 N 24 10 W 0.31 t~32 99 N 311 46 W ~71 ~:B 2700 2348.48 ~.~ ~ 4:~ 47 ~ 1 N ':"-' c.~ .~._ 0 ~? 1 1C)C)~ 7~ N 3~0..~.. W ............. lO~Z1. ~ m~ m m ANCHORAGE ALASKA ARCO ALASKA, INC. 3-0-1 ALASKA VERTICAL SECTION C:ALCULATED :;ALONG CLOSURE MEA.:,URED VERTICAL DEPTH DEPTH 2800 2416.62 ~. ~0o ..-404.91 3000 2551.24 :'-:1 O0 2615.76 :::200 2679.67 3300 2742.75 3400 2805.14 3500 2867.15 3600 2928.61 3700 2989.54 3800 '-~ ' '=' · .,(.)o0.5:3 4000 3180.31 4100 3247.65 4.:, .)0 3382.2,3 DATE OF SURVEY SEPTEMBER .8, 1988 SEPTEMBER ':?, 1988 dOB NUMBER AK-Bn-80095 KELLY BUSHING ELEV. = 59.00 FT. QP_g_R_n_T~?MCG U I RE VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH BEG MIN DEGREES BEG/lO0 NORTH/SOUTH EAST/WEST SECTION '-' '--'= 91 - ~:4,-~.. 47 1 :~' N,-'r"l . 89 W .................... o 19 2492? 2_4 49 ::.~6 N ~/_.,, ...... W · -'~'= N 28.5(') W .,:..:,..,6.76 50 '-'" 'Ts '-.~ ' '-"~-~ .~.6.,:.o. 67 50 "~' ' · -,0 N 0 W ."0. 2683.75 ......... DJ. 16 N '-'-' :r' ~. .............. ~L!.'_ '.-" .-f., W z748..14 51 30 N 27, 0 W ~80,:,. 15 51 50 N 26..:,0 W · -,o/.,,.-, 61 :--,~ 18 N '-'= 80 W ...... .- :'::7 N ,~,.. 0 W 2.°91 5:3 52 .. . ,:, N 24 . I.; ~W .-,..,~. · ....--.,0.-.- O~ ........... 4_? ....... .4,_ .......... N 27 80 W 3121.31 47 55 N 27. 0W 316:8.65 47 24 N 25.39 W :~255, 97 .47 ...... ~Z ........... ~_ ':.~L4.,.~ ..J~ 332:_:;, 33 47 20 N 25.30 N .......... 9.,.7.1 ......... 2.O:~._, 6:3__N ...... 8_.4_(! ~_Q~__. W. O. 72 20'::78.58 N 871 . 38 N O. 77 11 ,:,6.09 N ,:, ~6. :30 W 1191 .. 7 · ~ , '-= 'T.,' 'T{,- · _,~.::, .... 1 ~04 ..... ..~ N _42~,..,.'_8_C'L_.W_ ....... 1.81 1272. _:.--'3' N 461 .9:3 W 1342 .45 - - - 4 ~:d '-"- 0.61 1 :d:_~w. '.~:R N '- '- .... _.:_~ W 1419.'~=...._, O. o6 14oc~. 6., N .... 4.4,_. W 0.45 1478.12 N 570.24 W 1575.09 O. 64 1548.24 N 605.42 W 1653.53 Q.~..6!_ 1-61._?, .l_..!.._N .. 64.C~.Q(:,_...W. ........... _17~.3_?_ ......... 0.71 1690.74 N 674.C)7 W 1811.65 0.51 1762..~,'--' . ._o N 707 42 W 1890.79 ~ '~": 1831.86 N 741,~1 W '.; - 0;3 ~-~ m 1.29 1898.35 N 776.08 W 2042.92 1.29 1964.67 N 808.72 W 2116.82 ........ 2.190~.Z/ ..... 4400 3450.15 4500 3517.59 3391.15 47 15 N 25.19 W 3458.59 47 55 N 24,19.~.. . 3525.14 48 37 N 23.39 W 3592.07 47 20 N 24.60 W 3660.63 46 6 N 27.80 W 3729.65 46 35 N 28.30 W 3798.29 46 43 N 27.69 W 3866.89 46 38 N 27.30 W 3935.29 47 2 N 26.50 W 4003.07 47 37 N 26.39 W 4070.27 47 56 N 26.69 W 4137.40 47 43 N 27.19 W 4204.68 47 43 N 27.80 W 4600 4700 4800 4900 5000 5100 3584.14 3651.07 3719.63 3788.65 3857.29 3~25.89 5200 5300 5400 5500 5600 5700 3994.29 .4062.07 4129.27 41~6.40 4263.68 4330.98 0.12 2165.05 N 902.72 W . !. OC) ..... 2232.12 N._~_ t233.._57 N ... O. 92 2300.42 N 96:3.69 W 1.57 2368.28 N 993.90 W 2.63 2433.60 ~ ......... _1_0.'__26~.t_]!. W 0.60 2497.46 N 1060.04 W · 0.46 2561.67 N 1094.18 W .~ D.-2_ .-, O. 30 .'/: .'6,_.~ 1 _]3! ........ 1 l.'-,~Z,.7~_.. W. .......... 2691.26 N 1160.78 W 2757.09 N 1193.-=,q W . '_2823, :_~4 N_ ....... _I_.~26, _6:._3 .W ........ 0.43 2889.40 N 1260.22 W 0.44 2955.0:3 N 1294.38 W .. _0, ..0.~_ ..... ':.~ !.-'..~ 20, .N 2338.00 2411.75___ 2486.25 2560.42 2705.54 2778.26 2851.02 .... 2923.97 2~97.48 3145.65 3219.63 .13~,~.....~ ........ ~,~... ................................................................................................ ANCHORAGE ALASKA ARCO ALASKA, INC. DATE OF SURVEY SEPTEMBER 8, 1988 ...... :3_~.0_~.~. ~~:!J~I.~N.. ~T.E ~U~__.O~~~_suR~[¥. KUPARLIK FIELD SEPTEMBER 9~ 1988 dOB NUMBER AK-BO-8OOgE ~LA._K~ KELLY BUSHING ELEV. = 59.00 FT. OPER~~~~.._ VERT I C~L SECT I ON ~AL~UL~T[~ :AL. UN~ CLOSURE : TRUE 8LIB~SEA ~OU.RF~E ..... '-'MEA~LiRED VER¥'~CAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH DEG M I N DEGREES DEG/1 O0 NORTH/SOUTH EAST/~EST SECT I ON ..... 53i50 4398':29 4:339. ~-" ................. ~7 '4.~- ........ N-'27" 8o w o, 09 3085, 94 N lS6S, 26 W 3367.55 5900 4465 == . ~, 4406.55 47 43 N 27.8~ W O. 07 3151.36 N 13~7.82 W 3441.54 ....... 6Q~] 4532,87 ........... _4.~.7~.~8__~ ................... ~ ~ ......... ~.__~Z_~_ ~.~;L_.~ ~., ~ ..........;321.6..,. ~.._,N ......... ~;~.~ ............. ~1.~.,.~8 ....... 6100 6200 6300 6400 6500 6600 4600.19. 4541.19 47 43 N 28. 0 W O. 31 ~.?,'c'P,~' 22 N 1466.74 W 3589.43 4667 43 4608 43 47 4.5 N 28.10 W 0.08 3347. ..... ,4 N 1501.55 W 3663.44 4734,5.7 ........... 4~.....7.5_!.~_7 47 52 _ N 28, 4801.67 4742.67 47 50 N 28.50 W 0.30 3478.19 N 1571.61 W 3811.67 4868.62 480:-]. 62 48 5 N 28 89 W O. . o~,~._~. 34 N 1607.27 W 3885.92 493~,:~.~ .... 4_8...76,8'_2.. 4..7. ,28. ........ ~.. ~.~:..~.__W 0.,..6=5 ........ ~.~Q...8, (~.~.~_ .............. 6650 6700 6750 4970.46 4911.46 44 47 N ,c,L '-~' ]. ~0" ' W 5006.71 4947.71 42 16 N 32.39 W ~,.~0~'--'~._~. 89 4984.89 41 37 N :_--:3.19 W 6800 6900 7000 5081.27 5022.27 41 37 N 33.10 5156.11 5097.11 41 28 N 32,89 5230.96 5171.96 41 36 · N 33,1~ 7100 7200 7300 5305.70 ~,z46.70 41 39 N 33.19 5380.50 5321.50 41 31 N 33.19 5455.41 5396.41 41 2~ N ~3,~ 5471.41 41 2s N 33.10 5546.50 41 17 N 33.60 ..... 5621.67 41 13 _.___8_.33,69 5696.78 41 23 N 33.80 5772.02 41 0 N 33.89 5847.75 40 31 N 33.80 : 7400 5530.41 7500 5605.50 ......... ............ 67 7700 5755.78 7800 5831.02 7900 5906.75 8000 5982.67 5923.67 8100 .6058.70 5999.70 8200 6135.02 6076.02 8300 6211.44 ~' 61._z.44 8400 6.~o~. 10 6229.10 ......... ..... 00. c)o ...... 40 40 40 40 W W W W W 5.61 3639.38 N 1661.11W ~.'-"~'~M._.96 5.79 3668.80 N 1679.02 W 4030.31 __~.,70 __3696,8~.J~i ....... ~m6~d[2,_~ ...... ~ ..... 0.13 3724.70 N 1715.28 W 4096.61 0.19 3780.32 N 1751.40 W 4162.61 0.23 ..... ~835.91..N ...... ~ ........ 4228.58 ......... 0.06 3891.50 N 1823.95 W 4294.66 0.14 3~47.04 N 1860.29 W 4360.69 0,1~ ...... 4002,.40 N _ 1896.66 W . 442&,5.6 0.21 . 4057.72 N 1932.92 W 4492.34: 0.34 4112.89 N 1~69.23 W 4558.02 0.09 ....... ~16Y~? ~ .... ~005,77_W ...... ~ ........ 0.18 4222.68 N 2042.45 W 4689.16 0.40 4277.39 N 2079.15 W 4754.61 W ...... 0,..4~ .......... ~~'~._ ...... SZCll.~... l~ 481_ 9.48 ....... 40 N 34. 0 W 0.20 4385.64 N 2151.82 W 4884.13 20 N 34. 0 W :~i~i~i~ii~,,:i~:~.34 4439.50 N 2188.15 W 4948.64 10 N 34. o~ W ii: ~0'3~ ...... 4._41~2~.?_4_.1~L .......... ~,224,_&7_~ ......... ~_(~l~,_Z'~ 8 N 34.50 W 0.07 4546.12 N 2260.95 W 5076.77 45 N 34.69 W 0.41 4598.98 N 2297.41 W 5140.47 465..1. ,~1.. N . 2..~'~_~ ~_~ .It ............ ~2'P:~.85 .... :39 3.._9. ..... 4_2_ .......... N.. 3___4_._. _8_C2_H ~,..0~: ANCHORAGE ALASKA ARCO ALASKA, INC. DATE OF SURVEY SEPTEMBER 8, 1'~-'-' 3-0-1 ~ · !~:!~M?I-_!];AT_~O_~_ D~TE B~!~ ......... _ KUPARUK FIELD SEPTEMBER 9, 1'-'~"' ~7,~,~ ,JOB NUMBER AK-BO-800~5 ~LASKA KELLY BUSHING ELEV. = 59.00 FT. OPERATOR-MCGU I RE '~'ER'TIC~L-SECTION CALCULATEB'~-~ONG ~ ~ i u L 0 ~ L R E ' TRUE SUB-SEA ~.~ ........ C~E;~ DQ~.~.~E~ ..................... T~.TAL MEAo JRED VERT I CAL VERT I CAL I NCL I NAT I ON D I RECT I ON SEVER I TY RECTANGULAR COORD I NATES VERT I CAL DEPTH DEPTH DEPTH DEG M I N DEGREES DEG/1 O0 NORTH/SOUTH EASTZWEST SECT I ON 8700 8800 8900 8920 9000 9100 ~173 6442 ¢]5 '--"--- .... '-'- '-~"= '-' '-"~ 6.519.. :30 6460.30 3~ 21 N 34. 8~. W 0. 14 ~._~."~= 89 N 2406.61 W 532~.97 6596 R'" A5'~7 Go .~o ~.~ ~o N :~5 10 W 0 48 4807 58 N 2442.79 W ~392.50 6674 o~, - - .:,,;,~4 N '-'= .:,._,. 19 W 0 48 "'-'=~' 64 N 2478 75 W .:,6 6690 6 :J 66:31 65 '~"- ~:-~ N '-'= 30 W 0 '-"~' 4:~6._.. 79 N ~o._, ~ W 5466.66 6753 44 6694.44 ~,:~ 11 N '-'= :~'~ '-'5 ~,.-, .... 68:32 04 6773 04 38 11 N '-= . :3;_,. 39 W 0. ' '-' . . - ~)z 4959 62 N 2550 42 W 5576.~6 6889.41 6830.41 38 11 N 35.39 W 0.03 49~6.41 N 2576.57 W 5621.64 HORIZONTAL DISPLACEMENT = '~-S621.64 FEET'AT 'NORTH'S27 DEG.~ ..... 16 MIN. WEST AT'MD = 917:--: ARCO ALASKA, INC. KLIPARLII< F I ELD ALA._KA .-,~ -~,11 -,11 I~ III . .......... !gF::~Y_-~I~_]~IF, L.L~ .~. .... F--~LV...F_~..I~_~,~ ~PANY ~-~F' _~.,5 ...... ANCHORAGE ALASKA DATE OF oLRVEY SEPTEMBER C. ODII~.,U]F~T. ION. DATE SEPTEMBER 9, '-'-"-~' 1.-.~,_-,,--, JOB NUMBER AK-BO-800.95 KELLY BUSHING ELEV. = 59.00 FT. ~TE~O~ATED VALUES FOR EVEN 1000 ~EET OF MEASURED DEPT~ TRLIE MEASURED UERT I CAL DEPTH DEPTH SUB-SEA ........ TOTAL ' VERT I CAL RECTANGULAR COORD I NATES MD-TVD DEPTH NORTH~?~LL:'- ITH EAST/WE:ST DIFFERENC:E VERT I C:AL ~ (:ORRE. C;I.I g!N 0 1000 :3000 4000 5000 6000 7000 80A0 9000 9173 0.00 -59. O0 0. O0 0.00 O. O0 :-~ 1 o64 .... o~'~'~' l'8U.:,'= 89 536 '~'"'~ N 140 ~._, W 1 11 1 40 ~,51 24 2492.24 1204 .-,c, .~,/. . .o~, N 4l_,. W 448 76 ':' ~.c ..... 1:3.65 3180 31 3121 '~ ~"~':' '-'= ............. , ...................... .._:~.~ .................... ~.= ~..~.:-~.,~ .B ............ Z?.L~ ,..OE~_...W .............. ~.~ ~_, .<~ ........................... ~s_Z~2,.'A~ ................................................................ .:,8o7.29 :3798.29 2561 . 67 N 10'~4. · 18 W 1142 · 71 ~'~'~'~._,. 01 4532.87 4473.87 3216.80 N 1432 . ~':~=.., W 1467.12 324.42 523o.96 5171.~6 ~e~5,.9! N 17.87.57._.._B ........... !767, 04 >~..!, 9~ .j=.'.6.5~,.~ ." 67 Ao'-"-~ 67 4._~:~..,'- '- = . 64 N 2151 '~"-' . o~ W 2017.3:3 '-,~,~ 29 675:3.44 /-.6'D4_ . . 44 490S/. ~.s,=,._. N 2514.61 W 2246.56 22~. 2:3 6889.41 6830.41 4tD96.41 N 2576.57 W '~"-"-"- 59 ~._~ THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. ARCO ALASKA, INC. KLIPARUK FIELD ALASKA TRUE MEASURED DEPTH ANCHORAGE ALASKA DATE OF SURVEY SEPTEMBER 8, C 0 ~IP.L!T_~!~OJ~ ._D_~ YE . ................ SEPTEMBER 9 1988 ,_lOB NUMBER AK-BU-oO0~. KELLY BUSHING ELEV. = 59.0(.') FT. O_PgRA TOR-MC:GU I RE : : : ] :: :: :u;: ::::::::::::::::::::::: INTERPOLATED VALLEo FOR EVEN 100 FEET OF SiJB-SEA DEF'TH SUB-sEA VERT I C:AL VERT ! CAL RECTANGULAR C:00RD ! NATES MD-TVD VERT ! CAL DEPTH DEPTH NORTH / SOUTH EAST / NEST D I FFERENC:E CORRECT I ON 0 0.00 59 59.00 159 159.00 259 259.00 359 359.00 459 459.00 559 559.00 659 659.00 760 759.00 862 85~.00 -59. O0 O. O0 O. O0 o.... 00_ (..~:..05 N 0, 08 E 100.00 0.64 N 0.96 E -00. O0 1 .... :7:9 N 1 ,=.~'-"~ E :::OA O0 ._~.01'~' N '? 51 E 400.00 6 10 N '-' · z.60 E 500.00 11.75 N 1.71 E 600. O0 20.30 N 0. '-'~' .~,.~i W 700 00 33 68 N 4 '-'~ 800.00 ~ '-'' - ~l.zo N 8:.77 W O. O0 .. O, O0 ..... 0 O. O1 0. O1 O. 01 O. O1 0.08 0.05 0.25 0.17 0.65 0.40 1.62 0.97 3.25 1.63 964 959. 1068 1059. 1174 1159. 1282 1259. 13~2 1359. 1504 1459. 1619 1559. O0 900.00 O0 1000.00 O0 1100.00 O0 1200.00 O0 1300.00 O0 1400.00 O0 1500.00 1600.00 1700.00 1738 1659.00 1861 1759.00 .......... 7~.34 N_ ...... '3 '-' ........ ............. 1 ._ ._!=~...4_.__..H .... 5._ 98.85 N 20.73 W 9.30 132.18 N 30.65 W 15.19 .. ~ 7h.~'_s_' .N_ .......... .42_._~!7... W. 2.?.. 37 215.6:3 N 52.57 W 33.10 264.78 N 63...'8 W 45.03 320.69 N 76.14 W ,.,60.33 383.14 N 92.59 W 79.40 452.34 N 113.87 W 102.88 3.70 5.9(.') ~, !9 ....... 9.71 11.93 15.30 ..... 19.07 23.48 ANCHORAGE ALASKA ARCO ALASKA, INC· '"1 ' ' '" '..~ kLIFARUK FIELI] SEF'TEMBER 9 ALASKA DATE OF SURVEY SEPTEMBER 8, 1988 : ,_lOB NUMBER AK-BO-80095 KELLY BUSHING ELEV. = 5:9.00 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ............... TRLIE SUB-SEA ......... TijTAE MEASURED VERT I CAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD D.EP~_H DEPTH ...... D~PTH .......... N.O_~_T_H/...'_-R!.-'_!!.-.!~H _.EAST/W~ST. _D !FFE_~ENEi~ I.:_.'g~BgCTI QB ....................................... - 1 '.-:/'-T/2 1A='-:~ O0 · . .'5 ._l ~ m ..~._, :;.:'. 00 2272 205'~. 00 2418 ~,.~.'-"='~' O0 --'- .-'--' ?, c./' -' 22 ~'~'_...00 :' 71 2359.00 2861 2459. O0 301 I ~,o'-'= ~ -~'~. 00 3167 2659.00 ::~325 '-, 5' .,:..7._ ¥. 00 3486 2859 · 00 3649 3813 3968 4116 4265 4413 1800. O0 531 .79 N 139.01 W 1.:,~.'-"~' 08 30. 20 170!~.:. ~1~_) .................. ~21_,,,71 N 16:.~ .. ~,_:, ....W.. ....... !7!,_1_2 2000. O0 714 .70 N 20'...-T/ .7:3 W 21'-~'._.,. 37 42...-.--,'"-= 21o0. O0 811 34 N 255.'-:' . . . · :.~-.., W 25:9 :'-/2 46 55 '-,~0,', O0 1011 34 N '~' = . ..~4o.40 W 356 59 . .,.-..,,.. ,..,. . 48 45 . '--.~ ~ .-- · . 2400.00 1110 0:3 N ._8o.8~ 14 402 79 46 20 2500.00 1212.56 N 430.85 14 z~.:'_, :~7 50, 18 2600.00 1317.8:3 N 486.55 W 508.49 55. ._,._-, 2700.00 1426.64 N 543.82 W ._6E5 .... 99 ._.=,'-'.¢. 4.9 2:~A(]. 00 1538.94 N 600.83 W 627 ,:, '~' 1 ~0.82 2959.00 2900. 3059.00 3000. 3259.00 320(3. 335~.00 3300. 3459.00 3400. 4561 355~.00 3500· 4711 3659.00 3600. O0 1654.58 N 657.15 W 690.73 O0 1772·28 N 711·97 W 754·62 ~£~ ............... 1877.31 ~ ........... 2'~.,~!..~ ............... 00 1975.83 N 814.02 W 857.78 00 2075.6~ N 860.56 W 906.57 O0 2173.71N 906,80.W .... ?~4.04 O0 2274.21N 952.35 W 1002·96 O0 2376.05 N 997.51W 1052.67 62.93 63.8~ 48.58 48.7~ 48.92 4~.71 ........................................................................................................................ SPERRY-SLIN_.~_E~L_L---.;_UR_'._V_EY I NG COMJ='ANY ANCHORAGE ALASKA ARCO ALASKA, INC. ....... ;3-:0=__1 ...... . C;.C,M~.I.-!TA_T !ON ..._D_.A.T ~ KLIPARUK F I ELD SEPTEMBER 9., 1 oo.-...~..:. ALASKA PAGE .~___ DATE OF SURVEY SEPTEMBER 8, 1988 JOB NUMBER AK-BO-800S/5 I<ELLY BUSHING ELEV. = 59.00 FT. OF'ERATOR-MCGU I RE MEASURED DEPTH INTE TED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH IR'I _IE .................................................................................................................... SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH D~P._T_FI_ ................ NC!.R...T.H./~!~!__TH ..... EA~T/...W.E~!T O~FE.._ER~N.~:_E ............... C_:O~RE..~T.!.ON 4856 5002 5148 52~5 5444 55~3 5741 ............. ~8~0 6038 6187 6336 6485 6633 6770 6903 7037 7171 3759.-]. O0 3700. O0 2469.87 N 3859.00 3800,.Q0_ ~56~._.. 27 N. 3959. O0 '- '-~ ' ' .,~0o. O0 2657.43 N 4059.00 4~=9 O0 ~., ........ 4259.00 4359.00 4459,00 4._5~.00 46._,~.00 4759.00 4859.00 4959.00 5059.00 5159.00 5259.00 5359.00 4000 O0 2754.08 N 11 .~.. 410.0._09 ................ '£:2 5'-' ............... 4200. O0 2950.48 N 4300. O0 3047.71 N 4400. O0 ..... 3 ! 44, ~9....N ..... 4500. O0 ':"-'""=' 2r~ N 4600.00 ._-,~,:,'=~'."'"'._,,.':'~ N 4700. O0 3436.74 N 1045 ~C . .~) W 1097." ~6 45.19 1143.84 W 1189.26 45.77 03 W 1236.45 47.19 44~ ...........1~..~.7 1291.99 W 1334.05 48.68 1343.12 W 1382.60 48 .55 ~8~4,4~..~ ..... 14.~!,~6 ......... 4~,_.66 1445.53 W 1479.78 48...~5'~ 1497.18 W 1528.46 48.68 1549.18 w ......... !~Z~ .....................~,~6 ........................ 09 W 1626.59 49.17 30 W 1674.68 48.09 .~Z.~ .......... 1211,2.1 .......... ~6,.~2 .............................................. 79 W 1744.86 33.65 20 W 1778.50 33.64 87 W 1812.29 "'~ ~.~.79 40 W 1845.79 33.49 68 W 1879.10 33.31 4800.00 3533.95 N 1602. 4900.00 3629.33 N 1655. .~OQ~O0 ........... ~Z~8_~l_~.....li ........... 1Z04, 5100.00 3782.47 N 1752. 5200.00 3856.74 N 1801. 5300.00 3931.12 N 1849. 5400.00 4005,04 N 1898. 5500.00 4078.81 N 1946. 7304 7438 5459.00 555~.00 ANL:HORAGE ALASKA ARCO ALASKA, INC. ~:_0,_.!_ ' .................... ,-.~. MP._ I_U_T_ATI. ON. _.D~IE ..... KUF'ARUK F I ELD SEPTEMBER '.~, 1'-'~,--,~,'--'~' ALASKA INTERPOLATED VALJE~=, FOR EVEN 1OO FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASURED VERT I CAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD VERT I r:AL D ED' TH ....... DEP TH ...... DEPTH .......... ~OR TH_/.~C.!.L_!.TH ....... E_A_~ T/WE t--'_:T DATE OF SURVEY SEPTEMBER 8', 1988 · : i:iii !!ii!:?!:: i, ,: i JOB NUMBER ' - -"' ~'-]~ AK-Bu-~oc .~ ~ KELLY BL.=,HINb ELEV. 59.0A FT 7571 = =" ..~ N 1995 24 W · _,6.J ?/. 00 5600. O0 4151 98 . ....... 77__0.4_ ..... 575..?._90 ...... ~.7.9Q_.,_0_0 ................ ..4:2__2~,_Q.4__N ............ .'_::'..Q.4_4,._c_X~. W 78:--~7 ._ ,: ._.=,, :=: S ':','. . 00 ._,~.-,.,="'='r'A.. O0 4297 .5'.-? N ,'-OP.-. '--' ' ~'-' 72 W 796:--: 5959. O0 ~ 100 A0.~:F~ 00 I~I ~ ~ . . 5900. 6000. 8231 6100. 8362 6200. 8492 6300. 8621 6400. 8751 6500. 8879 6600. 9007 6759.00 6700. 9134 9160 1978.09 32.80 O0 4368.78 N 2140.45 W 2009.79 31.70 00 4439.71N ...... ~;~8.,.~_.~ .................. 20~!:~? ...................... ~1._~ 6159.00 O0 4509.65 N 2235.91W 2072.39 30.99 6259.00 O0 4579.08 N 2283.63 W 2103.15 30.76 6359.00 09 ........... ~7:._4.~..N ~l.,qJ ......~ ~!.~.,~_~ .................... ~@,~ ............................................ 6459.00 O0 4715.27 N 2378.27 W 2162.96 29.77 6559.00 00 4782.54 N 2425.21 W 2192.30 2~.34 _.. ___~~ ........... 66s~ 00 00 484~~~ ......... ~471.L4_~.~,__.W ........... ~.2tl~ ............... 'D'- 'D- O0 4912.79 N 2517.14 W 2248.08 27.47 6859.00 6800.00 4976.92 N 2562.71W 2275.31 27.23 6879.19 ~8_~0,~ ....... ~,86_N ..............2571,.~L_W___ ...... 22~;B~t_ .......................... ~.~50 ............... THE CALC:ULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT M,D ,(,,FROM RADIUS OF CURVATURE) POINTS SPERRY-SUN w~ c'~IRV~YTNA r'OMPANY ANCHORAGE ALASKA ARCO ALASKA, INC. KUPARUK' FIELD ALASKA ..................................... TRL,E MEASURED DEPTH DATE OF SURVEY SEPTEMBER 8, 1988. SEPTEMBER 'P, lC° . :A_.8 dOB NUMBER AK-BO-800c/5 KELLY BUSHING ELEV. = 5?..00 FT. OPERATOR-MCGLI I RE INTER~TEI] VAU_IES FOR '.SPECIAL 'SURVEY POINTS '?~.~'='i. ' SUB-SEA TOTAL VERT I C:AL VERT I CAL RECTANGLILAR COORD I NATES ...... _DE. pTH _[. !.E_F.' .T.._H_ .......... ..N_~ ~ T...H_ _/'-:_iL.-.!._L! T~ ............ _E_A_'S_'.T/_.W_..E_~i.T .... 8781 6582. O.g -='~-'- "-' '- = /:~,~-.,~. 09 47.~7.82 N .:4:3:J.'.~4 W TOP KUPARUK C ~.09 6603, 8~ 6544,.~?_ .................... ~.~ ~_..~0 _ N .......... ~.4~6.~_~_4....W ....... ~.~6g. KLI~'AR_UK_ ~:: '='="=" 8._, N 2450.01 W TOP KUPARUK A :~.:,~0 6612.45 6553.45 4817. '- = ,:.;-c,z 6715.73 6656.73 48:~c,. O1 N 24~7.41 W BASE KLIF'ARLIK A ~0o0 6753 44 /-.694.44 4~')'~. '~:S: N 2514.61 W SURVEY DEP~E . ~065 6804.52 6745.52 4'R41 . ~8 N 2537.89 W PLUG BACK TD ~ 173 688~. 41 6830.41 4 P >~6.41 N 2576.57 W TOTAL DEPTH ARcO ALAoKA,C:, INC. 3-O-1 DERIVED USING DIE nEPTHS AND SPERRY SUN SURVEY DATA MARKER ....... TOP KUPARUK L-: 8781 6582 0'2 /-,52:3 0'2 47'27 82N ~4._-._,.'24W "I ' 9 " BASE KLFARJK C '=' ~'' 660.z,, 8'2 6544. c~(.)W "-' TOP KUPARUK A "°-'-"' 6~,5 .... 45 4817. :~._,N z4.Jo. 01W BASE KUPARUK A 8~52 6715.73 6656.73 4885.01N 24~7.41W PLUG BACK TD '~065 6804 52 6745.52 4Sy41.~ TOTAL DEPTH 917:3 688~. 41 ,~,~, ' 6~o0 41 1) FROM LINEAR EXTRAPOLATION BELOW DEEPEST STATION. 2) COMPUTER PROGRAM - SPERRY SUN THREE DIMENSIONAL RADIUS OF CURVATURE. ..... ~A_T__A_~_LC_.'L_I~AT!_._0N .AND_.._IN_TERPOLATION BY RADILIS___OE_C__U_R_V_~TURE ~.~.O~P-LiTA-:i' i'0~1 -~ATE SEPTEMBER 9, 1988 SPERRY -SUN SCALE :- i INCH TO 1000.00 /'1000.0 KUPRRUK FIELO RRCO RLRSKR. 917~ 3 -0 -1 RK-80-80095 -2o~o. oo -~obo. oo HORiZONTaL ~" :SEPTEMBER 8, . TRUE NORTH -4000. O0 -~000. O0 · -2000.00 ,, -1000.00 -1000.00 PROJECT I ON::; INC. 1988 SPERRY -,.SUN 0.00 1500.00 $000.00 4500.00 KUPRRUK FIELO ~ -0 -1 RK-80-80095 -- 68'89.41 7500.00 { 5CRLE ;- 1 INCH TO 1500.00 / 1500.0 · -~ · - RRCO RLRSK~, INC. SEPTEMBER '6,, 1988 , 917~ I 1500. O0 I 3000. O0 45~0.00 60~0.00 VERT ICFIL PROJECTION ~ '~ STATE OF ALASKA ALA,. .,.t OIL AND GAS CONSERVATION COMMIS,. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate %__. Pull tubing __ Alter casing __ Repair well __ Pull tubing __ Other Z COMPLETE 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 724' FNL, 1842' FWL, 5ec.22, T13N, R9E, UM At top of productive interval 1206' FNL, 594' FEL, Sec.16, T13N, R9E, UM At effective depth 1062' FNL, 696' FEL, Sec.16, T13N, R9E, UM At total depth 1008' FNL, 735' FEL, Sec.16, T13N, R9E, UM 5. Type of Well: Development ..~ Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) RKB 59 ' 7. Unit or Property name Kuparuk River Unit 8. Well number 30-1 9. Permit number/approval number 88-73/8-644 10. APl number 50-- 029-21836 11. Field/Pool Kuparuk River Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9173 ' MD 6889 ' TVD feet feet Plugs (measured) None Effective depth- measured 9065 ' MD true vertical 6805 ' TVD feet feet Junk (measured) None Casing Length Size Structural Conductor 80 ' 16" Surface 5270 ' 9-5/8" Intermediate Production 9113 ' 7" Liner Perforation depth: measured 8890' -891 O'MD true vertical 6667 ' -6683 ' TVD Tubing (size, grade, and measured depth) 3-1/2", J-55, tbg w/tail @ 8736' Packers and SSSV (type and measured depth) AVA 'RHS' pkr ~ 8666' & Camco 'TRDP' SSSV ~ 1786' Cemented Measured depth True vertical depth 200 sx AS II ll5'MD 1250 sx AS Iil & 5305'MD 370 sx Class G - Top Job w/80 sx AS I 200 sx Class G 9148'MD 115'TVD 4065'TVD 6869'TVD 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 14. N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run N..~_ Gy FO Daily Report of Well Operations ~ . 16. Status of well classification as: Oil ~ Gas_ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 ( Dan i ) SW03/048 *NOTE: Completion Well History Date/,¢/z~ ¢¢ ¢ 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 Field ARCO Alaska, Inc. Lease o~[i: 25513 Title cO~LETE 30-1 Iwe, no. KUPARUK RIVER FIELD Auth. or W.OA~2939 50-029-21836 Operator Spudded or ~,8C~1~ Date and depth as of 8:00 a.m. 10/03/88 ( 1 TD .' 9173 ?B: 9065 SUPV: JH , For form preparation and distribL~ToTt) see Proc~ed~'res_~_ anu.al_,_Section ~ I Oate 10/03/88 Complete re[~(f)~c~ay reported JHour 0030 aRS RIH W/ PERF GUNS 7"~ 9148' MW:10.0 NACL MIRU, ACCEPT RIG ~ 0030 HRS, 10/03/88. ND TREE, NU BOPE & TSTD, RU E-LINE, RIH TO PERFORATE DAILY:~22,249 CUM:$911,158 ETD:S911,158 ARCO W.I. 56,0000 Prior status if a W.O. EFC: $1,350,000 IDate / Title ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well ia Plugged, Abandoned, or Sold, "Final Report" should be submitted also when operations are suspended for 8n indefinite or appreciable length of time. On workovera 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. ARCO Alaska, Inc. District KUPARUK RIVER FIELD Field AK2939 Auth. or W.O. no. [~ORTH ICounty or Parish ADL: 255~3 Lease or Unit Title COMP L]~'~ rAccountlng cost center code State ~ 30-1 IWell no. ARCO Operator ACCEPT Spudded or W.O. begun Date and depth as of 8:00 a'm-0-04/881 / ( TD: 9173 PB: 9065 SUPV:JH 56.0000 , IA,R.Co, W,I. 10/03/88 NORDIC #1]]Date Complete record for each day reported .2) Old TD New TD Released rig Date otalnumber of wells (active or inactive) on this Dst center prior to plugging and I bandon~t~f ~.we I I I IHour ......... | Prior status if a W.O, I RIG RELEASED 7"@ FINISH RIH WITH PERF GUNS, PEFORATE*, POH, RIH W/ COMPLETION STRING, SET PKR, RELEASE PBR, LAND TBG, TEST CONTROL LINE, TEST TBG & ANNULUS TO 2500 PSI, TEST SSSV, PUMP OUT SHEAR OUT BALL, SET BPV, ND BOPE, NU TREE, TEST TO 5000 PSI, DISPLACED WELL WITH 310 BBL OF DIESEL, TESTED CV, SET BPV, RIG RELEASED AT 2400 HRS, 10/03/88. DAILY:S187,564 CUM:$1,098,722 ETD=S1,098,722 EFC=$1,350,000 NOTE: CAMCO 'TRDP' SSSV @ 1786', AVA 'RHS' PKR @ 8666', TT @ 8736'. * PERFORATE 8890'-8910' W/ 8 SPY, 45 DEGREE PHASING. =, Classifications (oil, gas, etc.) Producing method IPB Depth Kind of rig IType completion (single, dual, etc,) Official reservoir name(s) 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 Eifectlve date corrected The abov~ is correct Sign ure ' Fir form pr/parali~' and distrib 'd~,, see Procedliresj~anual, Section 10, Drilling, Pag%'~ 86 and 87, 0/04/87 08: ,~TA'I'F, OF J~I.ASEA ALAS KA 0 i l, & GAS -CON S ER VAT 101,1 C()Hi'I J. $ l:; 1 (3tl B,O.P.E. ]nSl, eCtion Report =~t!_~p e c to r Ope~ator~._~_~C_O .... ~.C__,~._q ~'.,~., 7~¢. ~rjl.l$ng Contractor Locag/~n, General Well ~tg,~ ~eneral tlousekeep~ng Rig...._ . ...... Reserva Hud SvsCeme V~ual Audio Tr~p Tank ' · Flow Monitor ~a$ D~tec~ors Test F~essure BOPg St~ck .i,'-~__.:'~.-~- '--- ; Annular Preventer Pipe Ram~ ~ltnd Rams -~ .... Choke L/ne Valves Repre,~e.tat/ve Permit ~ C~sJ. ng Set @ ~/V~t ft. ~/ .~ l{epreseneattve .A_CCUHULA~[_~OI~ SYSI'[2,I Full Charge Pres~ure___~~=__~ Pressur, After Clo~ur, ~g~O pSig__ Pomp incr. clos, pres, 200 psig__~~min~sne, Full Charge Pres.gure Atta.!ned:_~_~__mtn~__sec. Con~toJ.~: Ke~~z an~ Fl~3r Sa~,~3_t Valves .,., ,~, ':'Iest ResulC$: Failures._ ~_ ,-..-~~ .... ' ........... ~ ..... "~//'~ / ..... ~,, Te..t ].':ira,? ,.8'(./~..,~ ),r:; ........ ,. Repair or Replacem-nt of failed equipmettc to be ,node wit'hit~. days ,and Inspector/ · ~ ,-~...-~..: :=~. ~ orig. - AO&OCC 'cc, -'Operator cc - Supervfsor 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 ~ 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 59' 3. Address 6. UnitorProperty name P. 0. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of wellatsurface 724' FNL, 1842' FWL, Sec. 22, T13N, R9E, UN Attop of productiveinterval 1320' FNL, 792' FEL, Sec. 16, T13N, R9E, UM (approx) Ateffective depth 1180' FNL, 847' FEL, Sec. 16, T13N, RgE, UM (approx) Attotaldepth 1126' FNL, 887' FEL, Sec. 16, T13N, R9E UN (approx) 7. Well number 30-1 8. Permit number 88-73 9. APl number 50-- 029-21836 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Length 80' 5270' Casing Conductor Surface Production 9113' 91 73 ' M D feet 6917'TVD feet 9065 'MD 6832'TVD Size 16" 9-5/8" 7" feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth 200 sx AS II 115'MD 1250 sx AS Iil 5305'MD & 370 sx Class G Top job w/80 sx AS I 200 sx Class G 9148'MD Rue Verticaldepth 115'TVD 4084'TVD 6897'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) None None 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch [] WELL HISTORY 13. Estimated date for commencing operation September, 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~(~/y~ ~;~j_~ ) Title Associate Engineer d Commission Use Only (SA3/0031) (Dani) Date Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance I Approved by Form 10-403 Rev 12-1-85 .~pproved Copy :~ Returned Commissioner the commission Date Su~ml~'n triplicate feet 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 JCounty. parish or borough ARCO Alaska, Inc. I NORTH SLOPE Field Lease or Unit KUPARUK RIVER FIELD ADL: 25513 Auth. or W.O. no. ITitle AK2939 I DRILL 30-1 Well no. API: 50-029-21836 Operator ARCO Spudded or W.O. begun IDate SPUD I 07/27/88 Date and depth as of 8:00 a.m. 07/28/88 ( TD: 1508'( 1 SUPV:SLC 07/29/88 ( ; TD: 4103'( 2~ SUPV:SLC 07/30/88 ( TD: 5291'( 07/31/88 ( TD: 5322'( SUPV:SLC o8/ol/88 ( TD: 5322'( SUPV:SLC 08/02/88 ( , TD: 8372'( 31 SUPV:SLC Complete record for each day reposed DOYON 14 IARCO WI. IH°ur1230 HRS J 56'0000 W'O' I Prtor status if a ~) ,08) :) 95) ) 88) ) 31) ) 50) DRILLING 16" @ 115' MW: 9.0 VIS: 66 FINISH MOVING FROM 30-7. NU DIVERTER, FLOWLINE , ETC. CUT DRILL LINE, PU BHA. SPUD WELL @ 1230 HRS, 7/27/88. DRILL 115'-1005'. TOH AND PU BENT SUB AND NAVIDRILL. TIH AND DRILL 1005'-1508'. DAILY:S54,927 CUM:$54,927 ETD:S54,927 EFC:$1,350,000 DRILLING 16" @ 115' MW: 9.1 VIS: 52 CONTINUE KICK OFF 1508'-2330'. TOH AND CHANGE BHA, TIH. DRILL AND SURVEY 2330'-4103'. DAILY:S43,752 CUM:$98,679 ETD:S99,679 EFC:$1,349,000 POH W/FISHING STRING 16" @ 115' MW: 9.1 VIS: 60 DRILLED TO 5291'. LOST 1600 PSI PUMP PRESS. POOH, LOST LOWER SECTION NAVIDRILL IN HOLE. PU OVERSHOT & JARS. RIH. CIRC DOWN TO TOP OF FISH. ATTEMPT TO LATCH FISH. POOH. DAILY:S43,187 CUM:$141,866 ETD:S141,866 EFC:$1,350,000 RUNNING 9-5/8" CASING 9-5/8"@ 5305' MW: 9.3 VIS: 46 FINISH TOH, NO FISH. MARKS ON TOOL INDICATED IT WAS OVER FISH. TIH W/ SAME ASSEMBLY. CIRC OVER FISH. LATCH SAME. TOH WET. LD FISH. PU PACKED ASSY. TIH. WASH AND REAM TIGHT HOLE 2146'-2378'. DRILL AND SURVEY 5291'-5322'. CIRC AND CONDITION WELL. DROP SURVEY, TOH, LD BHA. RU AND RUN 9-5/8" CASING. DAILY:S51,856 CUM:$193,722 ETD:S193,722 EFC:$1,350,000 DRILLING CEMENT 9-5/8"@ 5305' MW: 8.5 VIS: 32 FINISH RUNNING 134 JTS 9-5/8", 30#, J-55, BUTT CASING. SHOE @ 5305', COLLAR @ 5224'. CIRC AND CONDITION HOLE. CEMENT W/ 1250 SX AS III AND 370 SX CLASS G. DISPLACE W/ 404 BBLS WATER. LOST RETURNS AFTER 310 BBLS. BUMP PLUG W/ 2000 OK FLOATS HELD OK. ND DIVERTER AND PERFORM TOP JOB W/80 SX AS I. CIP 1315 HRS, 7/31/88. INSTALL SPEED HEAD AND NU AND TEST BOPE- MU BHA. REPLACE TURBINE. TIH. CUT DRILL LINE AND TIH. DRILL OUT TO COLLAR AND TEST CASING TO 2000 PSI; OK. CONTINUE DRILLING CEMENT. DAILY:S120,978 CUM:$314,700 ETD:SO EFC:$1,664,700 DRILLING 9-5/8"@ 5305' MW: 9.3 VIS: 33 FINISH DRILLING OUT SHOE AND 10' NEW HOLE. DISPLACE WELL W/ 8.4 MUD AND PERFORM LOT TO 12.5 PPG EMW. NO LEAK OFF. DRILL AND SURVEY 5322'-8372'. DAILY:S50,036 CUM:$364,736 ETD:S364,736 EFC:$1,350,000 The above is correct Drilling, Pages 86 and 87. AR3B-459-1-D I Title <~//?./~ ASSOCIATE ENGINEER INumber all daily well history forms consecutively as they are prepared for each well. Page no. 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" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not tess 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 string until completion. County or Parish ARCO Alaska, Inc. NORTH SLOPE Lease or Unit KUPARUK RIVER FIELD 30-1 Complete record for each day while drilling or workover in progress DOYON 14 JStat~ District Field Date and depth as of 8:00 a.m. 08/03/88 ( TD: 9073'( SUPV:SLC 08/04/88 ( TD: 9173'( SUPV:DL 08/05/88 ( TD: 9173'( SUPV:DL ~) '01) ) 00) LOGGING 9-5/8"@ 5305' MW:10.0 VIS: 46 DRILL 8372'-8491'. LOST 500 PSI. TOH, FOUND WASHOUT 40 STANDS DOWN. TIH, WASH TO BOTTOM AND DRILL TO 9073'. SHORT TRIP TO 8074' CIRC AND COND WELL, DROP SURVEY, SPOT PILL AND TOH. RIH W/ LOG 1. DAILY:S162,896 CUM:$527,632 ETD:S527,632 EFC:$1,350,000 RD SCHLUMBERGER 9-5/8"@ 5305' MW:10.1 VIS: 46 RIH W/ LOG 1. UNABLE TO GET BELOW 8836'. POH RD SOS. MU BHA AND TIH. WASH AND REAM 9032'-9073' DRILL 9073'-9173' SHORT TRIP TO 7218'. CIRC AND CONDITION WELL, SPOT PILL AND POH. RU SOS AND LOG W/ SFL/DIL/SP/FDC/CNL/CAL/GR 9158'-8500', DIL/GR/SP 9158'-5300', GR 9158'-1000'. RD SOS. DAILY:S92,293 CUM:$619,925 ETD:S619,925 EFC:$1,350,000 RD DOWELL 7"@ 9148' MW:10.1 VIS: 52 FINISH RD SCHLUMBERGER. TIH, CUT DRILL LINE, FINISH TIH. CIRC AND CONDITION WELL, SPOT PILL AND ?OH LDDP AND BHA. RU AND RUN 229 JTS 7", 26#, J-55 BUTT CASING. SHOE @ 9148', COLLAR @ 9065' CIRC AND CONDITION WELL, TEST LINES TO 3500 PSI AND CEMENT W/ 10 BBL CW100, 20 BBLS 11.0 PPG SPACER 3000, AND 200 SX CLASS G. DISPLACE W/ 347 BBLS 10.0 PPG BRINE. BUMPED PLUG TO 3500 PSI. FLOATS HELD OK. RECIPROCATED SLOWLY THROUGHOUT JOB AND HAD FULL RETURNS ENTIRE JOB. CIP @ 0530 HRS 8/5/88. RD DOWELL. DAILY:S190,396 CUM:$810,321 ETD:S810,321 EFC:$1,350,000 Well no. The above is correct For form preparation ar.~ distribution see Procedures Manua~,~ection 10, Drilling, Pages 86 and'~7 ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History-Final Report Instructions: 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. I Accounting cost center code District State ARCO Alaska, Inc. J AK Field County or Parish NORTH SLOPE ILease or Unit ADL: 25513 Title DRILL KUPARUK RIVER FIELD 30-1 IWell no. Auth. or W.O. no. AK2939 API: 50-029-21836 Operator A.R.Co. W.I. rTotal number of wells (active or inactive) on this, Icost center prior to plugging and ARCO 56,0000 Jabandonment of this well Spudded or W.O. begun Date IHour I Prior status if a W.O. I SPUD 07/27/88 ! 1230 HRS Date and depth Complete record for each day reported as of 8:00 a.m. DOYON 14 08/06/88 (1~)) RIG RELEASED 7"@ 9148' MW:10.0 NACL TD: 9173 SET SLIPS, ND BO?E, BLOW BRINE FROM 120' OF CASING, CUT PB: 9065 CASING. INSTALL PACK OFF AND NU CASING HEAD. TEST TO 3000 SUPV:DL PSI OK. INJECT DIESEL IN ANNULUS AND RELEASE RIG @ 1000 HRS, 8/5/88. DAILY: $78,588 CUM: $888,909 ETD:S888, 909 RFC:S1,350,000 Old TD I New TD PB Depth Released rig I Date IK nd of rg I Classifications (oil, gas, etc.) Type completion (sihgle, dual, etc.) Producing method I Off cia reservoir name(s) I Potential test data .._ Well no. Date Reservoir Producing Interval Oil or gas Test time Production 0ii 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 Signature{~ ~ ~ ~,._.,,, Date For form preparation a(~ distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ASSOCIATE ENGINEER ARCO Alaska, Inc. Date: August 12, 1988 Transmittal #: 7254 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 0 - 0 1 2" Dual Induction 8 - 4 - 8 8 1 0 0 0 - 91 5 0 3 0 - 0 1 5" Dual Induction 8 - 4 - 8 8 1 0 0 0 - 91 5 0 30-01 2" & 5" Porosity FDC 8-4-88 8500-91 27 30-01 2" & 5" Raw FDC 8-4-88 8500-91 27 3 O- 01 Cyberlook 8 - 4 - 8 8 8 5 0 0 - 91 2 7 Receipt Acknowledged: DIS.TRIBUTION: NSK Drilling Franzen D&M State of Alaska(+sepia) L. Johnston(vendor package) ARCO Alaska, Inc. Date: August 12, 1988 Transmittal #: 7259 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 O- 01 OH LIS Tape and Listing 8 - 1 0 - 8 8 # 7 2 8 7 2 Receipt Acknowledged: DISTRIBUTION: Lynn Goettinger State of Alska ~/~ STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Operator Location: Sec ,, Drillin Contractor o~t.._ ?-::ri- ,9& Well ~ O.,L ,,/ Representative... Permit ~ ~-D3 ~57~q Casing Set Representative LScation, General Well Si General Housekeeping e'""~Rig. ~ Reserve Pit / Mud Systems Visual Audio Trip Tank ' Pit Gauge Flow Monitor Gas Detectors , BOPE Stack Annular Preventer Pipe Rams Blind Rams Test Pressure ~o~0 I00O 'Choke Line Valves _ , H. C.R. Valve Kill Line Valves Check Valve , .~0~o ...... . Test Results: Failures C~ ... ACCUMULATOR SYSTEM Full Charge Pressure. ~C~ _ _-psig Pressure After Closure./~)C) psig Pump incr. clos. pres. 200 psig, Full Charge Pressure Attained:~ ~ .... s2Z__,Zzoo - ~.-zq~O f I-zz.t-O ps~ Controls: Haster.:_~5' .-~ -Remote ~f'[ Blinds switch cover Kelly and Floor Safety Valves _._ Upper Kelly. Lower Kelly. Ball Type Inside BOP Test Pressure ,..~_(~30 Test Pressure ~(~(~ O _ 'Test Pressure ~ ~ O0 Test Pressure ~'00~ Choke Manifold Y,~' Test Pressure No. Valves, [,? No. flanges ~- Adjustable Chokes ~ rauicall' )crated choke Test Time ,..,~-,_. hfs ............. Repair or Replacement of failed equipment to. be made within Commission office notified. min~.O~sec. rain ~ O._~sec. days and Inspector/ Remarks: · · ,, ~~_~ Distribution _ , ~ ,,, o-rig, - AO&CCC cc - Operator cc - Supervisor Inspector July 18, 1988 Telecopy: (907) 276-7542 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Res Kuparuk River Unit 30-1 ARCO Alaska, Inc. Permit No. 88-73 Sur. Loc. 724'FNL, 1842'F~, Sec. 22, T13N., R9E, UM. ~ Btmhole Loc. l155'FNL, 885'FEL, Sec. 16, T13N, R9E, ~1. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well -site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. W%ere 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. Ver~% tru .ly ~y~Qurs, Chaiman o f Alaska Oil and Ga~ Conservation Comission BY O~ER OF THE CO~ISSION dlf Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~" STATE OF ALASKA ~ · ALASKA f..,,_ AND GAS CONSERVATION CO,..'vIISSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill I~ Redrill ~1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil ~ Re-Entry [] DeepenE31 Service E~ Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 59', PAD 24'GL feet Kuparuk River Field "3. Address 6. Property Designation Kuparuk River Oil Po P.O. Box 100360 Anchorage, AK 99510-0:360 ADL 25513V'ALK 2554 4. Location of welt at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.O25) 724'FNL,1842'FWL,Sec.22,T13N,R9E,UM Kuparuk River Unit Statewide At top of productive interval(¢ target) 8. Well nu.mber Number I 320' FNL, 792 ' FEL,Sec .1 6,T1 3N, R9E, UM 30-1 #8088-26-27 At total depth 9. Approximate spud date Amount 11 55 ' FNL, 885 ' FEL,Sec. 1 6,T1 3N ,R9E,UM 07/26/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line DS 30-4 8953 'MD 11 55 ' (~ TD feet 75 ' t~ surface feet ;~560 6762 ' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 300 feet Maximum hole angle 45o Maximum surface 2414 psig At total depth (TVD) 3179 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80 35 35 115 115' +200 # cf 12-1/4" 9-5/8" 36.0# J-55 BTC 516.3 35 35 5198 4079' 1250 sx AS Ill & 4F-ERW 370 sx Class G 8-1/2" 7" 26.0# J-55 BTC 8919 34 .34 895.3 6762' 100 sx 50/.50 Poz Lea] tF-ER~ 200 sx Clas.s G tail 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary TK°Puparuk°f G 500' above Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface IntermediateRECEIVED Production Liner .ItlN 2.. 7 1988 Perforation depth: measured true vertical Alaska 0il & Gas Cons. Commission 20. Attachments Filing fee i~ Property plat [] BOP Sketch [] DiverterSketch ~ Drilling program ~ Drilling fluid program [] Time vs depth plot E~ Refraction analysis [] Seabed report [] 20AAC25.050 requirements ,, 21. I hereby~certify that tl'~e foregoing is true and correct to the best of my knowledge )~/'//~f U ~/'~'~~ ~/¢~~.,~ Date ~///~/~ Signed Title ~,,~,,,,:~ n"iil';ng Eng-;necr t - [/ ' Commission'O-s~'(~'l~/~¢~ fTEMI PD3/O04 ,,,, Permit Number I AP, number I APProva, date ! See cover',errOr O~ -7.~ 50-ozg-z.l&~a6 07 / 18 / 88 for other requirements Conditions of approval Samples required [] Yes I~ No Mud log required E} Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey required ~ Yes [] No Required workingj;~r.~ssure.[or BOPE _E~M; ..[~ 3M; [] 5M; [] 10M; [] 15M Other: //~/~ ,,,,~.~,/" / / '~ ' -- by order of Approved by ~ ,f, ( '~ ~'~.~ Commissioner the commission Date Sub~it in triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS ,.. 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) Drill 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casing., Pressure test to 3500 psig. 11) DownsqueeZe Arctic pack"and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. Circulate hole with SHALE _ SHAKERS MUD CLEANER ~ STI STIR RECEIVED JUN 2 7 1988 Alaska Oil & Gas Cons. Commission Anchorage I STIR MUD CLEANER CENTRIFUGE TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 " 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drillin~ Fluid S~st~m: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators RECEIVED JUN 2 7 1988 Alaska DJ[ & Gas Cons. Commission ,, Anchorage Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluiddisposal. LW~5/ih ""'"~' ': "' :?:-..:ii!~ii:K'UPARUK RIVER UNIT 20' DIVERTER SCHEHATIC IIII 4 D£SO:II PTIO~ OF THIS 01VERTEg ~~ AS A VARIANCE FI~0t'"I 20AAC2~.0~) MAI NTENAJ~CE &.OPERATION ! IJP0N INtT~AL INSTALLATION, CL0e~ I=QLrVENTER ,~NC vEP. IF¥ TWAT VALVE 0g~ PIKX)EgLY. 2.CLOSE ANNULAR PI~'VDI'I~R AND ~I,01M AIR THROUG OIVERTER LINES EVE~ 12 3. CLOSE ANNULAR PI~EVENTER IN THE EVENT ~NFLUX OF WE:LLDORE FLUIDS OR 6AS IS ~TECTED. JUN 2 7 ]988 Al~,ska 0il & Gas Cons. Commission _ ^nch[~ NOT SHUT IN WELL I- . ', , . 7 DZAGRAM #1 !~-5/8' 5000 PSI RSI~A BCP STACK I. 16' - 21300 PSI TAI~(CO 5'TAI~IN~ Ff. JID 2. I1' - 3~31:10 PSI ~I~ ~ 4. 1~/8" - ~ ~I PI~ AC~TOR CAPACITY TEST I. CI-[CK ~ FILL ~TCR I:~~IR TO I:~¢::1:~1~ LEVEL WITH HYDRN. LIC FLUID. 2. ~ THAT AC~TCR PRESSLI~ IS ~ PSI WITH 15OO PSI ~Tt;~_/I~ ~ TIE RI~GI.LATOR. 3. CE~E~ TlbE, TI..EN ~ ALL UNITS SII~LT/~I3.1~Y ~ laE(::l::la:) ~ TII~ /Idq3 PEE:SSUI~ REIvI~INING AFTER ALL L.NITS AI~ CLCISED WITH C]-IAEGING ~ CFF. 4. RE:~ (IN ~ RI330RTo TIE ~NN.E k()dI~ LIMIT 5 4 2 13-5/8' BOP STACK TEST I. FILL ~ 5"TAO( ~ ~ lVlI~NZFCLD WITH N:~"'TIC DIESEL. 2. Q-ECl( THAT ALL LOCI( EIIV~ 5CRE~ IN V~I. LFE_/~ ARE FULLY RETRACTED, SE. AT TEST PLUG IN N!LL~ WITH [~I~dlNG JT ~ ~ IN L(XXDCI~ SCI~ 3. CLOSE ~ Pf~'VENTER AhD ~ KILL ~ Llhl[ VALVES ADJACENT TO BCP STACK. ALI. OTI~E VALVES AM) CH(I<ES SHOLLD BE CPEN. 4. PRE~ UP TO 250 PSI AM) Fa.D FOR I0 MIN. IN- CREAS~ PRE~ TO 34300 PSI AFl:) HCLD FCR I0 MIN. BLEED F~E~ TO 0 PSI. 5, CPEN ~ PEEVENTE~ AI~ ~ KILL A~D CHCKE LIkE VALVES. CLOSIk'__ TCP PIPE ~ AM) HCR VALVES CN KILL A~D CHCKE LI~ES. 6. TEST TO 250 PSI ~ 3CI30 PSI AS IN STEP 4, 7. ~IN.E TESTIIMS ALL VALVES, LII~[~ ~ C~S WITH A 250 PSI LOW ~ 3000 PSI HIGH. TEST A~ IN STEP 4. IX) I~DT Pl~'.cLC~l~ TI='RT ~ C3-O<E TI-~T ~ A FULL CLOSING POSITIVE SEAL (;~'ll;~E. CN.Y FIJ~T[CN TE3'T Q-IEKE~ -IHAT EX;) ~ FI, JIfY CLC~E. 8. CPEN TCP PIPE RAI~ AN:) CLClSE BOTTOM PIPE TEST BOTT(~4 PIPE ~ TO 250 PSI AI~ ~XX) PSI. 9. CPEN BOTTCI4 PIPE RAIV~ BACI< OUT ~NG JT AI~ I0. CLOSE BL]~D ~ AI~ 'rEST TO 250 PSI ~ II. CPE'N BL]I~) ~ AI~ RETRIEVE TEST PUJG. Ma~E SURE ~FCI. D AN3 LIliES ARE FLLL C~' N~t-FREEZING FLUID. SET ALL VALVES ]N ERILL]NG P(3SITICN, 12. TEST ST~I~]PE VALVE~ Kl='liy. KELLY COQ(S. DRILL F(:~ SI(~N, ~ Srd~ TO CeZLLINS SU~RV]:SC~. JUN 2 7 !98 EKLY THa AFTE FU :TZCNALLY a . ATE 0it & Gas Cons. Commission .... ,; .A_nci,ora~e 51008400 ARCO ALASKA, !ne. Pad 30. Nell No, 1 Proposed Kupa~-uk Field. North Slope. Alaska 1 000 200Q 3000 4000 5000 RKB ELEVAT[ ION t t KOP TVD'3OO THD"3OO DEP"O 21 27' BUILD 3 DE:G- PER I O0 FT EOC TVD-1636 TH0-17'80 DEP-545 B/ PERHAFROST TVD-17'19 THD-1 896 DEP-626 T/ UGNU SNDS TVD-26ggi THD-3267' DEP-1586 T/ 14 SAK SNDS TVD-3479 THD-4359 DEP=2349 K-12 TVD-3879 THD=4918 DEP-2741 9 5/8" CSG PT TVD-40?9 THD-51 98 DEP-2936 AVERAGE ANGLE 44 DEG 23 MI N RECEIVED JUN 2 ? ]988 K-5 TVD-5859 THD-?689 OEP-46?'9 6000 T/ 'ZONE- D TVD-644+ THD-8508..DEP-5251 T/ ZONE C TVD-6494 THD-8578 DEP-5300 T/ ZONE A TVD=6519 THD-8613 DEP-5325 TARGET CNTR TVD-6569 THD-86831 DEP-537'4 B/ KUP SNDS TVD=6619 THD-8753 DEP-5423 TD (LOG PT) TVD-6762 THD-8953 DEP-5563 ?'000 0ii & Gas Cons. Commission , Anchorage 0 1000 2000 3000 4000 5000 6000 VERTICAL SECTION HOR T--7ONTAL PROJECT ,.,~ALE 1 IN. - 1000 FEET ARCO ALASKA, ! no. Ped 30. Well Not 1 Propoeed Kuperuk Field. North Slope. Ale,Ice 5000. WEST-EAST 4000 3000 2000 1 000 TD LOCAT ! O# t 1155' FILL. 885' FEI. SEC. 16, TI3#. RgE 1 000 4000... Z C:) --I -r' I C) C:: 3000 2000 TARSET CENTER TVO,.65~,g Tt'lD-8~dt3 DEP-53'/'4 !fORTH 4~94. k'EST 2634, TARGET LOOATIONI 1320' FILL. T92' FEL SEC. 16. TI3#. RgE 1 000 1000 RF_CEIV£D JUN 2 7 1988 0~' & Gas Cons. Commission ~ AD.horace SURFACE SURF'A~ LOCAT!OII ~ 7'24' F#L. 1842' Fk'L SEC. 22. T13N. Rg~: · TARGET) ~ 1 750 ! 800 1 850 ! 900 1 9..0 2000 2050 I I I I I I I ~ oc 5si _ ..... , ~ ~9oo ~oo ~/ I ~~! ~ k ~ ~doo / . ~ ~oo ~oo.~, -. .~ ,., / ~ ~ ~o~ k~oo ,~oo ', ~ ~... ~oo /~oo , I~ '~ "-soo / , ~ 7~.. ~ / 7oo, ~ x~2 ' 800 ' 850 . 900 _ 950 . 1000 _ % '""90~,. I / "" t.500· T go0 I ~ 4, "2500 ~ ° 500 4 "~',t 300 I soo b'%~oo 500 I I I I RECEIVED JUN 2 7 ]988 Alaska .Oil & Gas Cons. Commission '. Anchorage I I I I I 750 1800 1 850 1 900 ! 950 2000 I 2050 60C _ 65( _ 70( 80, _ 85 90 _ 95 _10 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2 thru 8) (8) (9 thru 13) 10. z~', ,~. ~t[, ~ -~?-~ 11. (10 and 13) 12. 13. (4) Casg ~~v~, (14 thru 22) Company ~ f~ (. C] Is the permit fee attached .......................................... Lease & Well No. YES NO 2. Is well to be located in a defined pool ............................. d~ 3. Is well located proper distance from property line .................. ~ ... 4. Is well located proper distance from other wells .................... _~ 5. Is sufficient undedicated acreage available in this pool ............ ~ ........... 6. Is well to be deviated and is wellbore plat included ................ ~ . 7. Is operator the only affected party ................................. _ 8. Can permit be approved before fifteen-day wait ...................... ~f~ (5) oPE (23 thru 28) (6) OTHER ~ ~ (29 thru 3~~i Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... ~_ Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~k ....... Does the well have a unique name and number ......................... ~ , 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ /~ Will surface casing protect fresh water zones ....................... z66~ ..... Is enough cement used to circulate on conductor and surface ......... ~ Will cement tie in surface and intermediate or production strings ... .~ .. Will cement cover all known productive horizons ..................... ~ 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 wellbore separation proposed ............................ /~ 23. 24. 25. 26. 27. 28. For 29. 30. 31. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate.~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. .. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones .... ;~''"/en/~d If an offshore loc., are survey results of seabed conditions 32. Additional requirements ............................................. REMARKS 0 mm Geology: EngiBe3~ring: ,.cs . rev: 02/17/88 6.011 INITIAL GEO. UN IT ON / OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: 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 APPENDIXi No 'special'effort has been made to chronologically organize this category of information. F,u?, --,: ...... SCHLUMB~RG£R .... $ LIS T~,P~ VERIFICATION LISTING VP 010.H02 VE~I~.=ICATI~N LISTING .PAGE ~ REEL HEADER ~R-' ERVICE NAME :EDIT ATE :88/08/10 RIGIN :FLIC EEL NAF,!E :72872 ONT!NUA~TI ON .~ REVIOUS REEL OMMEN'TS :EDIT LiS~ARCO KUP.4:RUK 3 0-I, A~! 50-OZg-Z1836 X~ FIL=,~_ HE AD t=.R...-',~-'-.... ILE NAME 'EDIT .001 ERVICE N~.ME :~LIC ERSION ~ :00t~02 ATE :88/08/'!0 AX'IMUM LENGTH "1024 ILE TYP:E :LO REVIOUS FILE * COM'MENT$ ""'" SCHLUMBERGER ALASKA COMPUTING CENTER OMPANY = ~,:RCg &L~SK,~ INC ELL = 3 0-! PI ~' = 50-02~-Zi816 IELO = KUP ~,RUK OUNTY = NORTH SLOPE PODDUGH T~TE = ~L~SK~ VP 01D HO2 VERi~r-ICA'T~gN L".S~rZN'~ 0'3 NUMBER AT AKCC: UN :~1~ DATE LOGGED: 0~-:~U.'~-88 DP: RICK :KRUW~LL ASING LOGGER YPE FLUID ENSZTY ISCOSITY H LUID LD:SS A'TRZX SANOSTONE IELD RE~qARK .5" STA,~4DOFF :4N.D 2' HOLi~FINOER USED ON 3IL. ~TRIX O~NSITY = 2.55 G/CC, FLUID ENSITY := :1 0 tS/CC NEUT:gON H~.TRIX = SAND, HOLE CORRECTION = CALImER OMPUTING CE~'4T ER ..)FILE EDIT.0O! CON'TAZNS DATA OF .DUAL INDUCTION (.DIL), FgRM~TION DENSITY .FDC), CO~'.~PENSAT50 NEUTRON (.CNL), ~ND GA;~M.~ RAY THRU CASiiNG (oCSG) .)FZLE EDIT.O02 CONT&ZN.S ~HI R~S FORMATION DENSITY (.FgH), COMPENSATED EUTRDN (. ~ VP 010.H02 VERiFICATZON LISTING PAGE ~':."-"-'-'"' THIS OAT~ "-HAS NOT BE~N O~EPTH SHIFTED - OVERL&YS FIELD PRINTS SCHL~JMiB:RGER LDGS INCLUDED WITH THIS MAGNETIC 'TAPE': DUALINDUCTION SDH'ERT, CALLY FOCUSED LOG (.DIL) DATA ~VAILABLE: 9150' TO 5298' :ORMAT!ON gENSZTY ~COMPENSA'TED LOG (.FDC.) D&T~ AVAILA~)L:: 9127 CDMP~NSATE9 NEUTRON LQG (.CNL) D~TA AVA~L~3LE: ~A~qM~ RAY THRU CASZNG 9~TA AVA~L~3L~: FDRM~T~ON DENSZTY COMPENSATED LOG HI RJ~S 1.2" (.FDH) O~TA ~VAILA~LE: 912'7 CO~qP~NS ATEO NEUTRDN DATA ,~V~ILABL:'_ 9,11>~ ~ INFORMATION RECORDS ABLE TYP;E :CONS VP 010.HO2 VE~I~ICA'TION LISTING MNEM TUNi VaLU DEFI CN FN WN NATI ST~, T C ,3 U N SECT TOWN Ra. NG L aTi LONG OPER. SON ~P I N 'FL A~LE TYPE :CUDV aRCO AL~SK~ IN'~ CQMPANY NAME KUP,aRUK FIELD N~ME 3 0 - I WELL NAME USA N,aTION ALASK,~ STATE gR PROVI'~ NORTH SLOPE COUNTY 22 SECTION I~N TOWNSHIP 9E RANGE L,~TITUDE L O N G I T U O E .S~RBER OPERATOR'S COD~ 530799 SERVICE ORDER 50-029--Z1~36 APl[ SERIAL NUM~ 72,~' FNL, 18~2t- FIELO LOCATION~ MNEM DE PT SFLU I L~4 ILO SP TEN S RHOS DRH'" DP H T C~LI NFDC FFD£ G~ TENS NPHI TNR~ RTNR RCFT RCNT CFT£ CNTC GR TENS G~ T E N S 0 E ~ I OEPTH CH~NNE'L SFL UN ~'V ER AGEg~ IL-MEDIUM !L-~EEP R 5 S.! S'T~ SP~NTAN~r. gUS PO G~MMA RAY T~NSIgN SULK gENS [TY g~LTa RHO DENSITY POROS'Z C~LIPER NE.~R FgC 'COUNT~ ~R FDC COUNT G ~N?~A R ~Y T 'E N S I O N NEUTRON mOROSI~ C4LI~P~T~g T H E'~ ~W THERMAL Nc~...,. RCFT RCNT CFTC CNTC G ~M~a TENSION T~NS~gN VP 0lO.H02 VErifICATION LISTING $ D,~T,~ FORMAT RECORD NTRY BLOCKS TYPE SIZE REPR CODE 5NTRY 1 ! 66 0 2 ! 66 0 3 4 7~ 104 4 ! 66 1 8 4 68 9 4 65 FT 11 1 66 9 13 1 66 0 14 4 65 FT 15 ! 66 68 116 ! 66 1 0 I 66 0 O. 5000 ATUM SP:ECIFIC,aTID~I !&LOCKS NEM SERVICE S'=_RVIC£ UNIT APl APl APl ,~qP'I FILE SIZE SPL REPR iD ORDSR ~ LOG TYP5 CLASS EP'T =T O0 000 O0 FLU OIL OHMM O0 900 O0 LM OIL OH~ O0 000 00 LD git gHMM O0 DOg 00 P git MV O0 000 O0 R OIL GAPI O0 OOO O0 ENS !OIL L~ O0 000 O0 HOB FOC G/C3 00 goo O0 RHO FDC G/C3 O0 000 PHI FDC DU O0 000 O0 ALI FDC IN O0 000 O0 FDC FDC ,CPS O0 000 O0 FDC FDC CPS O0 000 O0 R FDC GADZ O0 000 O0 ENS FDC LB O0 000 O0 PHI CNL PU O0 000 O0 NRA CNL 00 000 O0 TNR CNL O0 OOO .go CFT CNL CPS gO 000 O0 CNT CNL CPS O0 000 O0 FTC CNL CPS O0 gOO O0 NTC CNL CPS O0 goo O0 R CNL G~PZ O0 000 O0 ENS CNL LB O0 gO0 R ~rS5 G~DT~. 00. goo 30 ENS CSG L~ O0 OOO O0 PROC~ESS CODE (OCTAL) 6B 00000000000000 68 OOO00OO0000OOO ,68 O000000OO00000 68 O0000000000OOO 68 00000000000000 68 O000000OO0000O 68 O00OO000000000 68 00000000000000 58 O00000000OO000 68 O000000000000O 68 00000000000000 68 00000000000000 68 O0000OO0000000 68 O0000OO0000000 68 O00OO0000OO00O 68 O0000OO0000000 68 00000000000000 68 O000090DOOOO00 68 00000000000000 68 00000000000000 68 O000000OOO000O 68 00000000000000 68 00000000000000 68 00000000000000 68 OOOOO000000000 58 O0000OO000000O NTRY 5L:]CKS TYpE SIZE REDP CODE 1 1 68 2 1 66 ~ 4 73 4 1 66 8 4 68 ENTRY 0 0 104 1 0.5000 010.H02 VE~FZC~TZmN,.:~ ~ LZSTING ATUM SPECIFZC~TZON NEM S:RViZr: S!ERV!C: I O 0 R O := ,, EPT FLU DIL LM OIL LO OIL P DIL R DIL ENS OIL HOB FDC RHO PHI FOC ALI FDC FDC FDC FDC FDC R FDC ENS ~Dr PHI CNL NR~ CNL TNR CNL CFT CNL CNT CNL FTC ,."NL NTC CNL R CNL ENS CNL R CSG EMS CSG EPT P RHO FOC NRA FTC R 9 tl 16 0 EPT P RHO FOC NRA F T C 9201.5000 S=LU -17.2500 GR 0.0260 DP~I ~54,2500 Gq 2.75~3 RTNR 757.48Z9 CN'TC -'99~.2500 T E t',,I S ~LOCKS U N l T ~HMM OHMM OHMM MV L~ G/C3 G/C3 PU CPS CPS GaPl LB ~PU CPS CPS C P'S C p S G~oI L~ G~ PI L~ A P I LOG O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 · O 0 O0 O0 O0 O0 O0 O0 O0 O0 OO O0 O0 O0 O0 8 1 05 -99 1 8 2O5 65 66 65 66 66 66 FT 68 1 1 AP1 API API FILE SIZE SPt REPR YPE CLASS MOO NO. COD~ 000 O0 O 1 ¢ 1 ~8 000 O0 0 I 4 1 68 000 O0 0 't 4 I 68 000 O0 0 1 ¢ 1 68 go0 O0 0 I 4 1 68 000 O0 0 1 4 i 68 000 O0 0 ! 4 1 68 000 O0 0 1 ~ 1 68 000 O0 0 1 4 1 68 000 O0 0 I ,~ 1 68 000 O0 O 1 4 1 68 000 O0 0 I 4 1 68 OOO OO 0 I ~¢ 1 68 000 O0 0 I 4 1 68 gO0 90 0 1 4 1 68 000 O0 0 I ~ I 68 000 O0 0 1 4 1 68 009 O0 0 1 4 I 68 000 O0 0 1 ~ 1 68 000 O0 0 I ~ 1 68 000 O0 0 ! 4 1 68 000 O0 0 1 4 1, 68 O00 O0 0 1 4 1 68 000 O0 0 I ~ 1 68 go0 O0 0 1 4 1 68 000 O0 0 1 4 I 68 TENS CALI TENS qC=T GR 3.3440 $.0000 · 9.3251 6.0000 2.8429 O. 28~2 9.Z500 3.3440 6.0000 0.32~1 6.0000 2.8429 0.1~32 2.9696 1650.0090 8.2031 1650.0000 684.2107 86.0000 !.9606 2450.0000 ~.1031 2450.0000 584.2197 85.0000 ILM TENS C~LI TENS RC=T ILD RHOB NFDC NPHI RCNT TENS iLO RHOB NFOC NPHI RCNT 'TENS PAGE PROCESS (OCT4L) 00000000000000 00000000000000 OOOOOOOOO 00000 OOO00000000000 O000000OO00000 O000000000000O O00OO0000OOOOO O0000000000OO0 O00000000OO000 00000000000000 OOO00000000000 O00OO000000OO0 O000000000000O O0000OO000000O 00000000000000 O0000000000OO0 O000000OO00OO0 O000000000000O O000000OO00000 00000000000000 O0000OO0000000 00000900000000 00000000000000 00000000000000 OOO0000OO0000O O00OOOO0000000 3.1106 2.&798 58t.5000 ~0.5736 1969.11~9 1550.0000 3.1118 Z.4798 ~82.5000 30.5736 1969.1189 VP O!O.HOZ VEqI=ICa, TION R -g99. 2500 TENS EPT 9100. 0000 SFLU P '-22.3750 GR RHO 0o00~,3 OPHi FDC 500.5000 GR NRA 2. 9287 RTNR FTC 811. )436 ~CNTC R '-999.2500 TENS EPT 9000.0000 SFLU P -2'3.4219 GR RHO 0.9221 gPHI FDC 53'3.0000 GR NRA 3.4870 PTNR FTC 535.7029 CNTC R -999.2500 TENS EPT 8900.0000 SFLU P -44.2813 GR RHO 0.0066 9PHI FOC 577.0000 GR NRA 3.0054 R'TNP FTC 859.63~9 CNTC R -999.2500 TENS EPT 8.800.0000 SFLU P -23.9531 GR RHO 0.0512 gPHI FDC ¢3 8. 2500 GR NRA 2.8557 RTNR FTC 825.6022 CNTC R -999.~500 TENS EPT 8700ogOOO SFLU P -27.7138 ~R RHO 0.1678 OPHI FOC S29. 5000 GR NRA 2. 6630 RTNR FTC 97~.1118 CNTC R -999.2590 TENS EPT 8600.0000 SFLU P -20.2031 GR RHO 0.0154 gPH! 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RHO -999.2500 DDHI -999. FDC -999.2500 !3~ -999. NR~ --999· 2500 RTMP -999· FTC -999. 2500 CNTC -999. R --999.2500 ~'ENS -99~. 2500 2590 2500 2500 ,2500 7892 4375 2500 2500 2500 25 O0 2500 7259 1875 25 O0 2500 2500 2500 ~500 ,'4. 040 9375 2500 2500 2500 2500 2500 9664 5000 2500 2500 2500 25'00 2500 0542 5000 2500 2500 2500 2500 2500 ~308 q125 2500 2500 2500 2500 2500 CALI T~NS PCFT GR ILM TENS CALI TENS GR ILM 'TENS CALI TENS RC=T GR 'TENS CALI TENS RCFT ILM TENS CfiLI TENS RC~T ILM TENS CALI TENS RCFT ~3 P ILM TENS CfiLi TENS RC:T -999.2500 -999. 2500 -999. 2500 -999.2500 1.8362 5460.0000 -999. 2500 -999.2 500 -999. 2500 -999. 2500 2.6488 5280. 0000 -999.2500 -999. 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FDC -999. 2500 gq -999. NRA -999. 2500 RTHR -999. FTC -999.2500 CNTC -999. 253~ 2500 2500 2500 2500 2500 2500 6848 8125 2500 ~500 2500 2500 2500 18~T !~T5 2500 .2500 !500 Z500 2500 8267 6875 .2500 2500 250O 25 O0 ~.'~ 590 2302 7500 2500 2500 2500 2500 2500 2126 9375 2500 2500 2500 ,590 2500 5789 5625 2500 2500 2500 2500 IL~,I TE NS CALI TENS RCFT GR 'ILM TENS CALI TiNS aC~ GP IL M TENS ~'~LI 'TENS ~ C :T GR ILM 'TENS CALl TENS QCFT gR ILM TENS CALI TENS RCFT ILM TENS CALI TENS RCFT GR TENS CALl T~NS RCCT SR 3.2415 4904.0000 -999.2500 -999.2500 -999.2~00 -999.2500 2.70'!8 4844.0000 -999.2500 -999.2500 -999.2500 -999.2500 3.1651 471Z.0000 - 999.2500 -999.2500 -999.2500 -999. 2500 2.8T96 4604.0000 -999.2500 -999.2500 -999.2500 -999.2500 3.2835 4608.0000 -999.2500 -999.2500 -999. Z 500 -999.2500 3.3420 4448.0000 -999.2500 -999.2500 -999.2500 -999.2500 Z.6964 4304.0000 -999.2500 -999.2500 -999.2500 -999.2500 ILO RHOB NFOC NPHI RCNT TENS ILO NFOC NPHI RCNT TENS ILO RHOB NFDC NPHI RCNT TENS ILO RHOB NFDC NPHI RCNT TENS ILD RHOB NFDC NPHI RCNT TENS ILD RHOB NFDC NPHI RCNT TENS Itg RHOB NFDC NPHI RCNT TENS P~.GE 10 3.2088 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.644'7 -999..2S O0 -999 . 2500 -999 . 2. 5 O 0 · -999. ZSO0 -999.2500 3.1267 .-999.2500 -999.2500 -999.7.500 -999.Z500 -999. Z 500 2.8554 -999. 2500 - 999. .Z ..,: O 0 -999.2500 -999.2.500 - 999.25 O0 3.2816 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.3455 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.7124 -999.2~00 -999.2500 -999.25D0 -999.Z500 -999.Z500 VP OlO.H02 VCqlFIC,~TI:.O.,N,. ., . _ LISTING ,oAGE: ti R -999.2500 T!ENS -999. EPT 6400,0000 SFLU 3. P -18. 1562 SR 77. RHO -999. 2500 DP'MI -999, FDC -99 9. ZSO0 gR -999, N R A - '99:9. Z 5, g 0 R T N P - 99 9. FTC - 99 9. ZSgO CNTC - 999. R -999,2500 TENS -999. EPT 6300.0000 SFLU P -2 O, ! 675 GR 92. RHO -999.2500 DPHI --999. FDC -999.2500 gR -999. NRA -999.:2530 RTNR -999. FTC -999. 2500 CNTC -999, R -9~9. 2500 TENS -999. EPT 6200.0000 S,~LU P -19.28'13 GR 8 7. RHD --999.2500 gPH? -999. FDC -999.2500 5R '-99'9. NRfi -999.2500 ~TNP -999. F'TC - 999. 2500 CNTC -999. R -999. 2500 T~NS -,999. EPT 6102. gO00 SFEU 2, P -1 7.96B7 GR 85. RHO -999. 2500 DPHI ,-999. FDC -999.2500 GR -999. NRA -99'9.2500 ~TN~ -999. FTC -999.2500 CNTC -999. R -999.,2500 T E ~-~S -999. EPT 6 O0 O. 0000 SFLU P -15.9453 GR 85. RHO -999. 2500 OPH! -999, FDC -999. 2590 GR -999. NRA -999. 2~n0.. ~ RTM~. -999. FTC -999. 2500 CNTC -999. R -999. 2500 TENS -999. EPT 5900.0000 S~LU 2. P -I 5. Ol 56 GR 97. RHO -999.2500 OPHI -999. FDC -99'9.2500 '3P -999. NRA -999.2500 RTNR -999. FTC -999.25'90 CNTC -999. R -999.2500 TENS -999. EPT 5300.0000 SFLU 2. F -1 3. 8906 ; ,-'l,. 99. Prig -999.2~00 2 P !~,I -999. 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FTC -999. 2509 CNTC R 45.7500 TENS EPT 1BO0.900O SFLU P -999. 2500 P, HO -999.2590 ,]PHi FDC -999.2590 SR NRA -99 ~). 2500 FTC -999. 2500 CNTC R ~9.2137 T~NS -?99.25,00 -999.2500 -999.2500 -999.2500 1875.0000 - 999.2500 -:999. 2500 .-999.2500 -999.2500 -999.250.9 -'}99.25 O0 1900.0000 -999.2500 -9q9. 2500 -999. 2500 -'999. 2500 -999.2500 -999.2500 1810.0000 -999.2500 -'999.2500 -999.!500 '-99'9.2500 -999.2500 -999.2500 1780.0000 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 1730.0000 -999.~500 -999.2590 -997.2500 -999. 2500 -999.2500 -999.2500 1740.0000 -999.2500 -999.2500 '-999.2500 -999.2500 -999. Z500 -997.2500 1590.0000 CALl TENS ~C~T GR !tM TENS CALl TENS RCmT ILM TENS r~t! TENS RC=T TENS C~LI 'TENS ~C=T I t fq 'TENS C~LI TE NS RC.mT TENS C~LI TENS GR ILM TENS r~tI TENS RC~-T G~ -999.2500 -999.2500 -999.2500 -999.2500 '-999.2500 -999.250,0 -999.250~0 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2.500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9'99.2500 -999.2500 -999.2509 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 NFO~C NPHI RCNT TENS IlO RHOB NPHI RCNT TE:NS RHOB NFOC NPHi qCNT 'TENS ILO RHOB NFDC NPHI RCNT TENS ILD RHOB NFOC NPHI RCNT TENS ILO RHOB NFOC NPHI RCNT TENS ILD RHO8 NFOC NPHI RCNT TENS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.Z500 -999.2500 -999.2500 -999.2500 -'999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25'00 -999.2500 -999.2500 -999.2500 -999.2500 -999.25'00 -999.2500 -99).25Q0 -999.2500 -999.2500 -999.2500 -999.2500 -999.Z500 -999.2500 VP 010.H02 VERI~ICAT!gN LISTING EPT 1700.0000 SFLU P -999.2500 GR RHO -999.2500 gPHI FDC -999. 2500 G~ NRA -999.2500 ,PTNR FTC -999.2500 CNTC R 25.~063 TENS EPT 1600.0000 SFLU P -999.Z500 GR RHO -999.2500 OPHI FDC -999. 2500 GR NRA -999.2500 RTNR FTC -999.2500 CN'TC R 41.7198 TENS EPT 1500.0000 S~LU P - 99 9. 2500 GR RHO -999.2500 gPHI FDC -999. 2500 GR NRA -!999. ,2500 ~TN~ FTC -999. 2590 CNTC R 3;1.7500 TENS EFT 1400.0000 SFLU P -999. 2500 GR RHO -999.2500 gPNI FgC -999.2500 GR NRA -999.2500 RTNR FTC -999.2500 CNTC R 39.0000 TENS EPT 1300.0000 S~LU P - 99'9.,25 O0 GR RHC -999.2500 9PHI FOC -999.2500 GR NRA -999. 2590 RTNR FTC -999.2500 CNTC R 1'~.32~1 TENS EPT 1209.0000 SFLU P -999.2500 SR RHO -999.2500 9PHI FDC -999.2500 GR NRA -999.2500 RTNR FTC -999. 2500 CNTC R 42.6250 TENS EPT 110,9.0000 S:LU P -999. 2500 G~ RHO -99).2500 9PHI FDC -999.Z59C GR NRA -999.2500 RTN~ ;TC -999.2500 CNTC -999.2500 -99'9. 2500 -999.2500 -999.2500 -999. ,2:500 -999.2500 1620.0000 -999. 2500 -999.2500 -999.2500 -999. :2500 -999. 2500 -99'9.2500 1615.D000 -999.2500 -999.2500 -999.,250'0 -999.2500 -999. ,250O -999.2500 !5~5.0000 -999.2500 -999. ~500 -99'9.2500 -999. 2500 '-999.2500 -999.2500 1510.0000 -999.2500 -999.25,90 -999.2500 -999.2500 -999.2500 -999. 2500 lz+50.0000 -'999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 1365.0000 -999.2500 -999.2500, -999.2500 -999.2500 --999.2500 -999.2500 IL M T E NS C~LI 'TENS RCFT 'TENS C~LI TENS RC~T GR ILM TENS CALl TENS GR ILM TE NS C~L! TENS RCFT GR !tM TENS C ~t I TENS RC FT GR ILM TENS TENS eC~T IL~ TENS CALl TE~S ~CFT SR -999.2500 -999.2500 -999.2.500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2900 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999. 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 :ILO NFDC NPHI RCNT TENS RHOB NFDC NPHI RCNT TENS ILO RHOB NFOC NPH1 RCNT TENS TLO RHOB NFDC NPHI RCNT TENS ILD RHOB NFOC NPHI RCNT 'TENS ILO RHOB NFOC NPHI RCNT TENS !LO NFDC NPHI RCNT TENS -999.2500 -999.2500 -999.2500 -999.2500 -999.2'500 -999.25:00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 --999.2500 -999.2500 -999.2500 -999.250.0 -999.2500 .-999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -99).2500 -999.Z500 -999.2500 V? 010.H02 VERIFICATION LISTING R 57.1562 TENS EPT tOOO.OOOO SFLU P -999.2500 GP RHO -?99.2500 OPHI FDC -999.2500 GP NRA -99~.2500 RTNR FTC -999.2500 CNTC R 39.9062 TENS EPT 993.5000 SFLU P -999.2500 GR RHO -999.2500 OPHI FDC -999.2500 GR NRA -999.2500 RTNR FTC -999.2500 CNTC iR 42.6250 'TENS * FILE TRAILER ** ILE NAME :EDIT .OO1 ERVICE NANE :FLtC ERSION ~ :O01A02 ATE :88/08/10 AXIMUM LENGTH :],.024 ILE TYPE EXT FILE NAME : 1295.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 1260.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.Z500 1260.0000 ILM TE NS TENS RC ~T GR ILM TENS CALI TENS GR -999.2500 ILD -999.2500 RHOB -999.2500 NFOC -999.2500 NPHI -999.2500 RCNT -999.2500 TENS · -'999.2500 ILD -999.2500 RHOB -999.2500 NFOC -999.2500 NPHI -999.2500 RCNT -999.2500 TENS ~AGE 19 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 FILE HE~DER *~ ILE NAME :EDIT .OOZ ERVICE NAME :FLIC ERSION ~ : going2 ~'TE :88108/10 AXIMUM LENGTH :lOZ~ ILE TYPE : L9 REVIOUS FIL~ : INFORM~TIDN RECORDS ABLE TYPE :C~NS MN E ~'~, CN FN WN N~T I STAT COUN SECT TOWN RANG T UN 'I V ~,LU &RCO AL.A'SK~ KUP&RUK 3 0 - ! USA ~LASK~ NORTH SLOOE 22 95 'I N, DEFI COMPANY NAME FIEL~ NAME WELL NAME NATION STATE OR PROVI~ COUNTY SECTION TOWNSHI? RANGE VP 010.H02 YE~IFICATIgN LISTING PAGE 20 LATI OPER SON APIN FL ABLE 'TYPE :CU~V LATITUDE LONGITUDE G. SARBER OPERATOR'S 530?99 SERVICE ORDE~ 50-029-'21836 ~P'I SERIAL NUM* 724' FNL~ 18424 FIELD LOC~TIgN~ MNEM DEFi DE'PT gEPTH CHANNEL RHO'S BULK OENSITY D R H 0 D 5 L T ,~ "R H 3 DPH[ gE,~SITY. °gROSI'~ CALZ C~LIPER NFDC NE&R ~gC CDUNT~ FF~C =AR, ~FDC C~UNT GR G~M~A R:~Y TENS T:NSION~ NPH'~ NEUTRON ~POPO SI'~ TNR~ CaLI5R~TSO THE~ RTNR RAW 'THERMAL NE~: RCFT RC~T RCNT RCNT C F T C C F T C CNTC CNTC GR G ~M~A R ~Y TENS Ti~NS~ON DATA FORMAT RECgRO ~ NTRY ~LgCKS TYPE SIZE REPR COD~ ENTRY I 1 6,5 0 2 I 66 0 3 4 73 72 4 1 65 1 8 ~ 68 9 4 65 FT 11 1 66 14 13 1 66 0 '14 4 65 FY 15 1 66 68 16 1 66 1 0 1 66 1 -0.0000 ATUM SPECIFICATION 5LOCKS NEM SERVICE SERVICE UNIT ~oI ~PI API API FILE SIZE SPL REPR PROCESS ID O~OER ~ LOG TYPE CLASS MOD NO. CODE (OCTAL) EPT FT O0 000 'gO 0 2 4 1 68 O000000OO00000 HgB ~DH $/C3 O0 900 O0 0 2 ~ I 68 OOO0000000000O RHO FDH G/C3 O0 900 O0 0 2 ~ 1 68 00900000000000 PHI ~DH PU O0 000 gO 0 ~ 4 I ~8 OOO0000OO00000 VP OlO.H02 VERIFICATION LISTING PAGE 21 ALI FDH IN FOC FDH CPS O0 000 FDC ~DH CPS R FOH ~oI O0 ENS FDH LP O0 OOO PHI CNH gU O0 gOO NRA CNH OD 900 TNR CNH O0 gO0 CFT CNH CPS CN'T CNH CPS gO OOO FTC CNH CPS O0 gO0 NTC CNH CPS R CNH GAPI O0 ENS CNH LB O0 OOO I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 O000000OO00000 1 68 00000000000000 1 68 OOOOOO00000000 1 68 OOO0000OO00OO0 I 68 O00OOOO0000OO0 1 68 OOO0000000000O I 68 O0000OO0000000 1 68 00000000000000 1 68 00000009000000 1 68 00000000000000 1 68 00000000000000 DATA FO~M ~T,R;CgR9.,. .,.-"'"".,, NTRY ~,LOCKS 'TYPE SIZE REaR COD~E 1 1 66 2 1 66 3 4 73 ,4 1 66 8 4 68 9 4 65 II 1 66 I 3 1 66 1~ 4 65 15 1 66 1,6 1 6 6 0 1 66 ENTRY 0 0 72 1 -0.0000 FT 14 0 68 1 1 ~TUM SP~CtFICAT'ION ~LSCXS NEM SERVICE SERVICE UNIT APl 4P! API ~PI FILE SIZE SPL REPR lid ORDER ~ LgG TYPE CL&SS MOO NO. EPT FT O0 000 O0 0 2 4 HOB FDH G/C3 O0 000 O0 0 2 4 RHO FDH G/CB O0 gOO O0 0 2 4 PHI ~DH ~U O0 goo O0 0 2 4 ALI FDH ~N O0 OOO O0 0 2 4 FDC FDH CPS O0 gOO O0 0 2 4 FDC FDH CPS O0 000 00 0 2 4 R FDH 'GAO1 O0 000 O0 0 2 4 ENS ~DH LB O0 000 O0 0 2 4 PHI CNH PU O0 gO0 O0 0 Z .4 NRA CNN O0 000 O0 0 2 4 TNR CNH O0 OOO gO O Z 4 CFT CNH CPS O0 000 O0 0 2 4 CNT CNH CPS O0 OOO O0 0 Z 4 FTC CNH CPS OO 009 O0 0 Z 4 NTC CNH CmS O0 000 O0 0 2 4 R CNH G~P! O0 900 O0 0 2 4 ENS CNH LB O0 OOO O0 0 2 4 PROC[SS CODE (OCTAL) ! 68 O000000OO00000 I 68 O00000000OO000 ! 68 O00000000OO000 1 68 00000000000000 1 68 OOOOO000000OO0 1 68 00000000000000 1 $8 O000000OO00000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 O0000OO0000000 1 68 O00OO00000000O 1 68 O00OOOO0000000 1 68 O0000OO0000OO0 1 68 O00OO00OOOO000 ! 68 O00OOOO0000OO0 1 68 O000000OO0000O ,VP 010.H02 VERIPICA'TION LIS'TiNG PAGE 22 DATA ~EPT 9197.7988 RHOE ALI :8.1953 NFDC ENS 1 43 5. 0000 NPHI CFT 63'1. 3253 RCNT R 94.2500 TENS 'EPT 9100. 2938 RHOB ALI 8.2266 NFDC ENS 6300.0000 NPHI CFT 85!. 7440 RCN7 R 83.12150 TENS EPT 9000.2988 RHOB ALI 3. 9766 NFOC ENS 6132.0000 NPHI CFT 50 2. 3649 RCNT R 93.5000 TENS EPT 8900.2988 RHOB ALI 3. 2109 NFOC ENS 5580. OOOO CFT 851. 7440 RCNT R 4'7. 3750 TENS EPT 8800.2988 RH08 ALI ~.9922 NFDC ENS 6'232.00~0 NPHI C~T 766.2219 RCNT R 92.3125 TENS EPT 8700.29'-88 RHO~ ALi 9.0939 NFOC ENS 5'960.0000 NPHZ CFT 783.9100 RCNT R 70. 5625 'TENS EPT 8600.299~ RHg~ ALI 3.773~ NFDC ENS 5892.0000 NPHI CFT 40!.~395 RCNT R 121.0625 TENS EPT 8500.293~ RHSP ALI 9.6172 NFDC ENS 5589.0000 NDH! C:T 50~.3649 ~CNT R 75.~75 TENS EPT 8~8~.F000 ALI 10. 0313 NFDC ENS 55B8.0000 NPHI CFT ~80.4052 :CNT 2.4456 59~.0000 37. ¢899 2090.9892 1435.0000 2.4405 52:2.5000 33. 7535 24tl.3877 6:300.0000 2.4107 623.0000 4'1.6964 !548.0437 6132.0000 Z.2715 5!,5.5000 31.3823 2540.2578 :380'0000 2.&732 .565.5000 31.2192 2225.2627 623,2.0000 2.9813 386. 2500 29.0133 2926.8120 5960. gO00 2.3550 622.0000 49.1498 !723.9553 5892.9000 2.89,67 63g.5000 39.0071 1971.9717 ~5R8.9000 2.4435 651.0000 44.9716 1701.4695 ORHO ~FOC 'TNRA CFTC 9RHO :FDC 'TNR~ r F'TC ORHO FFDC TNRA CFTC ORHO FFDC TNR~ CFTC ORHO FFDC TNRA CFTC DRHO FFDC TNRA CFTC ~R:HO FFOC CFTC 3RHO FFDC TNR,~ CFTC OPHO ~FOC CFTC 0.0266 ~94.'7500 3.1627 698.9340 0.0433 522.0000 2.9610 849.794~ 0. 0337 548.5000 3.4555 559..7245 -0.0062 700.5090 2.8078 871.3738 0.0119 445.7500 Z. 8609 850.3561 0.0064 126.0625 2.7223 ~o4.8~5o 0.0158 602.0000 3.7922 475.1178 0.2~82 281.5000 3.3623 566.0222 0.0662 548.5000 3.7215 490.08t7 OPHI GR RTNR CNTC DPHI SR RTNR CNTC DPHI GR RTNR CNTC DPHI GR RTNR CNTC OPHI GR RTNR CNTC DPHI SR RTNR CNTC DPHI GR RTNR C N'TC 9PHI SR RTNR CNTC DPHI GR CNTC 12.3988 94.2500 3.2656 21'77.0732 12.7080 83.1250 2.9394 2345.98¢9 14.5094 93.5000 3.3478 185t.0471 22. 9470 4'7.3750 3.2059 2540.6406 10.7219 92.3125 2.7429 233'7.79'74 -20.0657 70.5625 2.5833 2605.8911 17.3895 121.9625 4.4706 1718.2751 -14.9370 75.1875 3.3222 1949.6316 12.5258 99.8125 3.8889 1'738.6204 ~P 010.H02 VERIFIC~TIgN L~STZNG PAGE 23 99.~125 TENS k F',iLE TR~ILER [LE NAM5 :EDIT ~RVICE NAME : '_-2SION ~ :O01~.gZ ~,'TE : 9810~/10 ~XI ~U~ L E i~.~G TH [LE TYPE : LO :XT FIL~ NA~5 558:B.0000 TAP: 'TRAZLE~ ~¢ :RVICE NA~=:,,. 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