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184-082
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVE® ' F 2019 WELL COMPLETION OR RECOMPLETION REPORT AND LQG -, 1a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑� Suspended ❑ 20AAC 25.105 20AAc 25.110 GINJ❑ WINJ❑ WAG❑ WDSPL❑ No. of Completions: 1b. Well Class: Development 0 Exploratory ❑ Service E] Straligraphic Test C] 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 3/1/2019 14. Permit to Drill Number / Sundry: 184-082/319-065 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 611111984 15, API Number: 50-029-21121.00.00 4a. Location of Well (Governmental Section): Surface: 547' FSL, 236' FWL, Sec 32, T11 N, R9E, UM Top of Productive Interval: 1387' FNL, 1339' FEL, Sec 32, T11 N, R9E, UM Total Depth: 1268' FNL, 1198' FEL, Sec 32, T11 N, R9E, UM 8. Date TD Reached: 6116/1984 16. Well Name and Number: KRU 2G-06 9. Ref Elevations: KBA40 GL:104 BF: 17. Field/ Pool(s): . Kuparuk River Field/Kuparuk Oil Pool 10. Plug Back Depth MD/TVD: 8368/6158 18. Property Designation: ADL 25666 0 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 508930 y- 5944135 Zone- 4 TPI: x- 512619 y- 5947486 Zone- 4 Total Depth: x- 512760 y- 5947605 Zone- 4 11. Total Depth MD/TVD: 8486/6252 19. DNR Approval Number: ALK 2582 12, SSSV Depth MD/TVD: WA 20. Thickness of Permafrost MD/TVD: 150011470 5. Directional or Inclination Survey: Yes ❑ (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: WA (ft MSL) 21. Re-drill/Lateral Top Window MD1TVD: NIA 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 N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE CASING FT SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H40 38 110 39 110 24 202 sx Cold Set II 95/8 36 J-55 37 3134 37 2774 12 1/4 1035 sx Permafrost E & 250 ax Psnafrost 7'. 7 26 J-55 36 8449 36 6224 81/2 575 sx Class G, 250 sx PPrm.fmqt r. 24. Open to production or injection? Yes ❑ No El If Yes, list each interval open (MDrrVD of Top and Bottom; Perforation Size and Number; Date Perfd): ALL PERFS PLUGGED BACK AID44 DATE 5 / �(,j VERIFIED Hl~✓ 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDITVD) 31/2 8044 7968/5841 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27, PRODUCTION TEST Date First Production: NIA Method of Operation (Flowing, gas lift, etc.): PLUGGED BACK Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity -API (corr): Form 10-407 Revised 5/2017 VTL/`�_9/ CONTINUED ON PAGE 2 RBDMS A� APR 6 2019 Submit ORIGINAL I only �.8.` 41 I, �� 28. CORE DATA Conventional Core(s): Yes ❑ No El Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presenceof 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 ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1500 1470 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval N/A N/A information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk A4 TD 8465 6252 Formation at total de the N/A 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontolooical report, production or well test results, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: Keith Herrin Authorized Title: Staff CTD Engineer Contact Email: Keith. E. Herrin co .com Authorized` Contact Phone: 263-4321 Signature: Date: INSTRUCTIONS General: This form and the 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 1a: 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 1b: 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 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. 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 5/2017 Submit ORIGINAL Only 2G-06 Final CTD Schematic shoe 49 MD &ilii•38#-s whoa 8184' MD Pnllal Willow ® 918]'-8189' MD FFaigW High EMe.ion We49e Lan Tag 488136' MD High E�paiubn Wetlge 8134' MD mr Pad'ar M1om (a8 conpbnon ® 813C MD n6o.nd aadw eweama 8188'-a199'MD aerd saueema 8218'-8248'45' MD r26#3.9s venae 49 8440' Mp 3-12" 9.3# L -BO EUE Ertl Tubing t swia. 3-12" DS landing nipple @ 525' MD (2.875" min ID) 3-1/2" Cam. MMG gas lift mandrel ® 2952', 4946', 6250', 7246', and 7898' MD Baker 3-12" PBR Q 795T MD (2.98" ID) Baker FHL packer @ 7968' MD (3.03" ID) 3.12" DS landing nipple @ MIT MO (2.813" min ID) 3-12" tubing til @ 8043.6' MD (8048' PDC) 3- Kuperuk Liner Top Packer ® BOW PDC 2O 12 TD=1=1'MD 2. .1oded I blank Iner Me seabom dapbymenl.kava TM = NOW MD, BOL= 94W' MD Tppolwbfed fear= MT MD -- 2''P'l '-- TO®6., C..r WasboM.Oarings,iind Peckafla a-alia MD KUP PROD WELLNAME 2G-06 WELLBORE 213.06 �prkLr�' COMIA' "'hipsK'KName Well Attributes Max Angles MD TD NBSka.InCKUPARUK fto��'ianppim WeIIMrePW W WNine"SoNs MOInN81 aM lfl al RIVER UNIT 500292112100 PPOD 4.60 4,00000 8,4850 OahAnnotems EndDab XSGoido RopmeaseUme 12/192017 Last WO'. ]11412010 36.00 611811984 2Goe41157199+4s5AM I Last Tag v«ard edwremle tm) Annomeon DepthmKe) 1 End Date .11. Lesions ar Lest Tag: RED 8,13UD 10172019 213-06 Idetpusp FaNGER as l...- - Last Rev Reason Annompam IEnd DaR I WNleme Lameness, Rev Reawn: New OLD IX23,2um 2134)6 Jbansen8 Casing Strings Casing Dewnetlen oDlim 10 (m,) 30POIMe) SH Cepm gets) set Depth ITV01..WVLen IL.. Dade Top Tnmd CONDUCTOR 16 150fi 38.0 1100 110.0 62.58 H40 Welded! Casing Deenlstem wfin ) ID tai roe(me) Set Damn mo, Set DepN nWl--wmlen (l...Gta. Top Tnmtl SURFACE 9518 921 372 3,1339 2,773] 3600 J-55 BTC wxwaroR: aeanpo Casing Dmedptian loops) IDgnl roPIfko) sepopmnam,-stepNITVO)-. WULen(I I mde ,-Thmd PRODUCTION 7 6.28 359 8.4491 6,223.8 2600 J-55 BTC Tubing Strings rumne oescnWon sttlng Ma... 1016) Tdp lnleel sef Demn ryL sm cepm mDl l... WtPlan) Dmae Top Co nnecfbn TUBING wO 312 2.99 301 5.8414 9.30 L-80 EUE8mABMOD NIIWIf; 524.7 Completion Details Top IWD) Top met Naminel Top (fK8) andi ('1 Item Des Cam 10 (In) 30.1 301 009 HANGER Ve1c0lGmy an II TUBING HANGER 2.930 GAS LIFT: 29519 526.7 5246 1.10 INIPPUE 3.5" Camw-DS" Nipple ed 2.875 profile 2.875 7, .8 5,8316 39.63 PBReel ssembly lsheared wespace out TABBEDI 2980 PACKER ASSEMBLY Testing Dewnmbn Shing Ma...10(m) TUBING PACKER 3112 2.99 TaPmKa) 7,968.3 Set Oepunt-joeseashoslo,]WI(Ion, 8,043.6 5,899.1 930 Gmde L-00 Top Comampon 8RD FILE ASSY Completion Details aURFACE; 3T as 13m- roIF 1TVD1 Top and Neese' IFdml I.,on pl Item Dee Co. In pn) DAs LIFT; 4,945.4 7,968.3 $.BdDJ 3950 PACKER FHL Packer 3.030 801121 5,8]3.8 3903 NIPPLE 12,813"DSNippie 2.813 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) Top mKB) Top (rvD) I+IKES I Topmcl (') Oes Co. Bungee ID (in) CASUFT;6,2503 8,006.0 5,869.8 39.10 PACKER Set 3" Kuparuk Liner win packer( 5" AL,eel 3/192019 Assembly 45" OAL, 4 Ave Seats, 1625" Min ID Thro DSD Packae Set 3 -Slip Stop on lop Packer GasuW: T.24aw 8,096.0 5,9394 01 WEDGE N HgM1 Expansion WMge WS. m-30eg ROHS. &252019 OOm 8,097.5 5,9414 37.98 WINDOW HEW WS faile0 & fell down hoe, IesaamF indm 1W21 2.600 exposed in T casifq 8 8,132.0 5,968.7 3754 WEDGE NIS High Expansion Wedge WS 1011 0.000 B GAS LIFP, 7.81 Note: WS Slid down -hole. Likely top at 8136MO (1023118) 8,136.0 5,9718 3749 WEDGE N High Expansion Wedge WS 10116= 0000 8 1 PBR:7,M6 8,158.0 5,9893 41.21 FISM LOWER PACKERF MPLETI N, PU 11612008 PLUG, 8 REST OF TUBING DOWN TO WIRELINE RE- 0.000 I 1 ENTRY GUIDE IS IN FILL. TAGGED HARD MUD PAOKER:79m s 8158 SUM. Perforations & Slots Derm Dms Top leKe) aM199B TeWB) 6011 eening mKB) Linked IDne Oefe Isnoblrt 1 TyPa Co. MFPLE em 12 ,1 .0 6,1980 601. 8,0213 A5,2G-06 W2411988 6.0 (PERF um aeing4" Schlumbeyer Canal 8=.5.0 8,2460 6,035) 6,059.9 Aa,2G-06 924/1988 d. (PERF eg. asmg; " Schlumberger Casi .�vaERucoavLETwx: Tee9aa,mo Mandrellnsens at WEDGE; eM0 on Toprom)WM LMcn Pod Size Tfl0 flan N TeP(me) (Me) Mese Model 000n) sentType Ties pnl Wh Run DNe Com 1 2,951.5 2,6554 Camco MMG 11 AS LIFT GLV RK 0.188 1,24].0 &2N2019 930 2 ,9415 3.8519 Camco MMG 112 GA LIT GLV RK 0.188 1,2460 32012019 10:30 3 6,2503 4.6462 Camco MMG 112 A LI T OV RK 0250 00 311 19 1100 wsgGE: e.+aao 4 7248.0 5,3106 Camco MMG 112 GAS LIFT OMV RK 0.000 00 2/182019 5 7,898.2 5.]868 Camco MMG 11/2 SLIFT DMV RK 0.000 um 2/192019 WEDGE;emm Nclass: General B Safety End Dane I Annolmbn 1/22000 NOTE: WORK DVER 12/102007 NOTE '.^ MIT TESTING WILL HAVE TO USE DS NIPPLE @ 808 121102007 NOTE: WORKOVER 722009 NUTE:5 6=TIGHT SPOT, UNABLE TO WORK 26' GAUGE RING PAST 6272009 4/82019 NOTE: View Schema0cw/Alaska dlematid0.0 Flemselem- IPERF: 9,1ffim-k mom IFERF.8.2160$246.0-a, PROWCTION. 3964191 2G-06 CEMENT TO PLUG PERFS DTTMSTAJOBTYP SUMMARYOPS 2/28/19 DRILLING MIRU CTU. MU DUMMY PLUG ASSEMBLY. RIH WITH DUMMY PLUG SUPPORT- ASSEMBLY AND TAG 2.813" DS NIPPLE AT 8,011' RKB. (7,992' CTMD). CAPITAL FLAG COILED TUBING. POOH. RDFN. 3/1/19 DRILLING RIH W/ CEMENT JET NOZZLE TO 8,086' RKB. RU HES CEMENTERS. SUPPORT- CIRC WELL TO SEAWATER. MIX 15.8#/GAL CEMENT. PUMP SPACER, CAPITAL 10 BBLS. OF CEMENT AND SPACER. SQUEEZE CEMENT TO 1500 PSI. LAY IN CEMENT & POOH TO 7,000' WITH CT, APPLY SQUEEZE PRESSURE TO CEMENT FOR TWO 30 MINUTE INTERVALS. RIH AND CLEAN OUT TO 8,086' RKB. CIRC WELL CLEAN AND WASH OUT OF HOLE CLEAN GLM'S. INCREASE PRESSURE TO 1,730 PSI. SHUT IN WELL. RDMO CTU. 3/2/19 DRILLING TREE VALVE POSITIVE TEST SV, MV (PASS), TREE VALVE NEGATIVE SUPPORT- TEST MV, SSV, SV (PASS) CAPITAL 3/5/19 DRILLING RD & move to 2G SIDETRACK 3/6/19 DRILLING Complete move to 2G -Pad, spot over well, begin RU, unstab coil, pick SIDETRACK injector & replace w/ new injector, MU injector electirical & hydraulic plumbing, NU BOPE Rig Accept: 3/6/19 @ 00:00 hrs (to accomadate Nabors & COP on Code 8 hours for reel swap on 3M-26 & Injector swap on 2G-06) 3/7/19 DRILLING Continue working injector line installation, grease surface valves & tree, SIDETRACK inspect chokes & mud pumps, test BOP's, install gripper blocks, install stripper, begin stabbing pipe 3/8/19 DRILLING Complete stabbing pipe, re -head a -line, test IRV, PT TT line & PDL's, MU SIDETRACK nozzle & test injector to -300', POOH, PU BHA #16 Window Milling Assembly, RIH, log RA for -2' correction, mill cement from 8085' to TOW at 8098.3', begin milling window to midnight depth of 8101.5' 3/9/19 DRILLING Complete milling window & rat hole to 8124', peform reaming pass HS, 30L, SIDETRACK 30R, & LS, POOH, PUD BHA #16, MU nozzle & jet stack, PD BHA #17 Build/Turn Assembly, RIH, log K1 for -5.5' correction, drilled from 8124' to 8403', pulled into cased hole & replaced sheared pillow block bolts (ODS), drill to called EOB at 8450', POOH, PUD BHA #17, begin PD BHA #18 "A" Lateral Assembly (NOV agitator, 0.50 AKO motor, & RB HYC A3 bit) Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Capin Start Time End Time our (hr) Phase op Code Activity Code Time P -T -X openmon (fixe) End Oepih (WEI) 10/14/2018 10/14/2018 3.00 MIRU MOVE MOB P Trucks on location, Load shop on 0.0 0.0 06:00 09:00 flatbed, PJSM with Peak for rig move. Move pits & sub off well 31-01, Jeep up, R/D cellar berm and herculite 10114/2018 10/14/2018 5.00 MIRU MOVE MOB P Move rig 31 to 2G pad 0.0 0.0 09:00 14:00 10/1412018 1011412018 1.00 MIRU MOVE MOB P On 2 G pad, De jeep rig, Rig up 0.0 0.0 14:00 15:00 herculite in cellar, Scaffolding crew here. 10/14/2018 10/14/2018 2.00 MIRU MOVE MOB P Spot sub and pits 0.0 0.0 15:00 17:00 10/1412018 1011412018 1.00 MIRU MOVE MOB P Start pre spud check list, Safe out rig, 0.0 0.0 17:00 18:00 stairs down. Ensure egress routes clear. 10/14/2018 10/14/2018 3.00 MIRU WHDBOP RGRP P Swap out swab #2 on stack, Work rig 0.0 0.0 18:00 21:00 up check lists 10/14/2018 10/1412018 2.00 MIRU WHDBOP NUND P Nipple up stack, change out riser, 0.0 0.0 21:00 23:00 Obtain RKB's, RIG ACCEPT 21:00 10/14/2018 1011512018 1.00 MIRU WHDBOP SVRG P Grease stack, R valves, and drilling 0.0 0.0 23:00 00:00 1 choke 10/1512018 10115/2018 0.50 MIRU WHDBOP SFTY P PJSM to perform full BOPE test, Test 0.0 0.0 00:00 00:30 1 witness waived by Adam Earl, AOGCC 10/15/2018 10/15/2018 8.00 MIRU WHDBOP BOPE P Start full BOPE lest, Test pressure 5K, 0.0 0.0 00:30 08:30 stab INJH, test inner reel iron, inner reel valve, and pac-off. 10/15/2018 10/1512018 0.50 MIRU WHDBOP CTOP P Valve crew on location load lubricator 0.0 0.0 08:30 09:00 into pipeshed, Unstab INJH, changeout UQV floats. 10/15/2018 10/15/2018 1.50 MIRU WHDBOP PRTS P Perform valve check -list, test PDL's 0.0 0.0 09:00 10:30 and tiger tank line. 10/15/2018 1011512018 1.20 MIRU WHDBOP PRTS P PJSM, PIT Lube, pull BPV 0.0 0.0 10:30 11:42 10/15/2018 10115/2018 0.30 MIRU WHDBOP CTOP P Load out Valve crew eqiupment 0.0 0.0 11:42 12:00 10/1512018 10115/2018 0.30 SLOT WELLPR CTOP P Move INJH forward remove UQC, 0.0 0.0 12:00 12:18 boot a -line, stab INJH 10/15/2018 10/15/2018 0.60 SLOT WELLPR CTOP P Line up and pump slack 0.0 0.0 12:18 12:54 manangement. 10115/2018 10/15/2018 0.30 SLOT WELLPR CTOP P Un -stab INJH, rig up hydraulic CT 0.0 0.0 12:54 13:12 cutter 10/1512018 1011512018 3.80 SLOT WELLPR CTOP P PJSM, start trimming coil, found wire, 0.0 0.0 13:12 17:00 continue trimming coil, RD cutter and dress CT for CTC. "' Note: Found wire @ 28' 10/15/2018 10/15/2018 1.50 SLOT WELLPR CTOP P PJSM, install CTC, pull test to 35 k 0.0 0.0 17:00 18:30 10/15/2018 10/15/2018 0.60 SLOT WELLPR CTOP P Re -head BHI upper quick connect, 0.0 0.0 18:30 19:06 1 test a -line (good -lest), install floats 10/15/2018 10/1512018 0.40 SLOT WELLPR CTOP P PT connections and re -head 4,500 psi 0.0 0.0 19:06 19:30 (good test) 10/15/2018 10/15/2018 1.00 SLOT WELLPR PULD P PJSM, slide cart back, load both 0.0 0.0 19:30 20:30 PDL's 10/15/2018 10/15/2018 1.30 SLOT WELLPR PULD P PD cleanout BHA#1, perform surface 0.0 51.3 20:30 21:48 test (good test) 10/15/2018 10/1512018 1.90 SLOT WELLPR TRIP P Tag up, reset counters, RIH with 51.3 7,990.0 21:48 23:42 Cleanout BHA, PUW Q 4,0007 24 k 10/15/2018 10/1512018 0.10 SLOT 1 WELLPR DLOG P Log the K1 marker correction of +2', 7,990.0 8,019.0 23:42 23:48 PUW=38K 10/15/2018 10/16/2016 0.20 SLOT WELLPR PRTS P Start static BHP, TVD 5872, 8,019.0 8,030.0 23:48 00:00 Ann=3778, EMW=12.38 Page 1/19 Report Printed: 411512019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth start Tian End Tune Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/16/2018 10/16/2018 0.20 SLOT WELLPR PRTS P Static BHP, TVD 5872, Ann=3778, 8,030.0 8,030.0 00:00 00:12 EMW=12.38 10/16/2018 10/16/2018 0.30 SLOT WELLPR TRIP P Trip in to 8158 dry. PUH to 8000 for 8,030.0 8,000.0 00:12 00:30 CCL pass 10/16/2018 10116/2018 0.20 SLOT WELLPR DLOG P Log CCL down to 8158, Bit to CCL 8,000.0 8,158.0 00:30 00:42 39.5 10116/2018 10/16/2018 0.40 SLOT WELLPR CIRC P recip CT waiting on sweeps 8,158.0 8,158.0 00:42 01:06 10/16/2018 10/16/2018 1.60 SLOT WELLPR TRIP P Sweeps out trip out displacing well to 8,158.0 56.8 01:06 02:42 used PwrPro 10/16/2018 10/16/2018 1.10 SLOT WELLPR PULD P At surface, PJSM PUD BHA #1 56.8 0.0 02:42 03:48 10/16/2018 10/16/2018 1.90 PROD1 RPEQPT PULD P Assemble Northern High Expansion 0.0 73.5 03:48 05:42 Wedge whipstock, M/U to Coil track and deploy. M/U to coil and surface test. Check pack offs. 10/1612018 10/1612018 1.60 PROD1 RPEQPT TRIP P RIH BHA #2 NS HEW whip stock 73.5 8,020.0 05:42 07:18 10/16/2018 10/1612018 0.20 PRODi RPEOPT DLOG P Tie into Kt marker for -1', PUW=37K 8,020.0 8,043.0 07:18 07:30 10/16/2018 10/1612018 0.10 PROD1 RPEOPT TRIP P Continue in hole to setting depth 8,043.0 8,142.8 07:30 07:36 10/16/2018 10/16/2018 0.10 PROD1 RPEQPT TRIP P 8142, at set depth oriented to HS. 8,142.8 8,142.8 07:36 07:42 Close EDC pull slack from CT. Pumps on .5 BPM see tool shift 4200 PSI Set down lightly on whipstock 10/16/2018 10/16/2018 1.50 PROD1 RPEQPT TRIP P POOH after setting whip stock 8,142.8 61.0 07:42 09:12 10116/2018 10/16/2018 0.90 PROD1 RPEQPT PULD P Tag up at surface. Space out. PJSM 61.0 0.0 09:12 10:06 j PUD BHA#2 10/16/2018 10/16/2018 1.10 PROD1 WHPST PULD P M/U and PD BHA#3 to mill window. 0.0 76.8 10:06 11:12 WFT 1' fixed bend motor, 2.80 window mill, and 2.79 string reamer. M/U to coil and surface test 10/16/2018 10/16/2018 4.20 PROW WHPST TRIP P RIH BHA#3 to mill window, close EDC 76.8 8,025.0 11:12 15:24 @ 500' Pumps on @ 1.80 BPM @ 4111 PSI. Take screen shots. Continue in well, Stacked out hard @ 4790'. Nothing in the area. PUH Inspect pipe and injector. Good. Trip in. Stack out. Roll pump @ ,7 BPM and roll TF to HS. Taking weight every -30 feet. Continue in well pumping at reduced speed 10/16/2018 10116/2018 0.20 PROD1 WHPST DLOG P Log Kt for -3', PUW=34K 8,025.0 8,049.0 15:24 15:36 10/16/2018 1011612018 0.50 PROD1 WHPST TRIP P Continue in well, Dry tag pinch point 8,049.0 8,137.0 15:36 16:06 @ 8137.8', PUH 10/16/2018 10/16/2018 2.70 PROD1 WHPST MILL P Bring pumps on 1.8 BPM @ 3803 PSI 8,137.4 8,140.0 16:06 18:48 FS, Start milling @ 8137.4 10116/2018 10/16/2018 1.50 PROD1 WHPST MILL P Continue milling window per 8,140.0 8,142.0 18:48 20:18 procedure, 1.8 bpm, BHP = 3986 psi, WHIP = 394 psi, BOW called at 8140.2' (WOB & dp fall oft), string reamer through window 10/16/2018 10/16/2018 3.20 PROD1 WHPST MILL P Begin pushing, milling rat -hole, CWT= 8,142.0 8,163.0 20:18 23:30 11.8K, WOB=0.7K-3K, BHP =3846 psi, WHIP = 406 psi, -5.5 bph losses, pump 5 x 5 sweeps 10/16/2018 10117/2018 0.50 PROD1 WHPST REAM P Begin reaming passes per procedure 8,163.0 8,163.0 23:30 00:00 (HS, 30L, & 30R) Page 2119 Report Printed: 4/15120191 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Siert Depth Start Time EM Too Our (M Phase Op code I Aclirey Code Time P-T-x Operation (i1KS) End Depin(nKB) 10/17/2018 10/17/2018 0.80 PROD1 WHPST REAM P Complete reaming passes per 8,163.0 8,163.0 00:00 00:48 procedure (HS, 30L & 30R), dry drift v window, clean up & down, PUW = 35K 10/17/2018 10/17/2018 2.10 PROD1 WHPST TRIP P POOH, slight overpull at 4781', 8,163.0 76.0 00:48 02:54 slowed, Gose EDC, PJSM 10/17/2018 10/17/2018 1.10 PROD1 WHPST PULD P PUD BHA#3 (1.8° AKO motor, RB 76.0 0.0 02:54 04:00 Hughes bit), mill & string reamer came out 2.79" no-go 10/17/2018 10/17/2018 1.10 PROD1 DRILL PULD P PD BHA#3 Build/Turn Assembly (1.8o 0.0 72.0 04:00 05:06 AKO motor, RB Hughes bit), slide in cart, check pack-offs, MU to coil, tag up, set counters 10/17/2018 10/17/2018 1.70 PROD1 DRILL TRIP P RIH w/ BHA #4, Set down (di 5077 72.0 8,031.0 05:06 06:48 10/17/2018 10/17/2018 0.10 PROD1 DRILL DLOG P Log K1 for-1.5', PUW=35K 8,031.0 8,031.0 06:48 06:54 10/17/2018 10/17/2018 0.10 PROD1 DRILL TRIP P Continue in well, clean pass through 8,031.0 8,165.0 06:54 07:00 window, Tag up and drill from 8165 10/17/2018 10/17/2018 0.50 PROD1 DRILL DRLG P 8165', Drill 1.77 BPM (a] 3790 PSI FS, 8,165.0 8,180.0 07:00 07:30 BHP=3810 10/1712018 10/17/2018 1.20 PROD1 DRILL DRLG P 8180 stall, Pick up, PUW=40K loosing 8,180.0 8,010.0 07:30 08:42 returns,pulling heavy, DHWOB=-14K, Pull up into casing. Orion shut down. WITTS running very slowly. Restart BHI and orlon computers - Gas in returns at surface. Divert to tiger tank. Pump bottoms up. PUH 10/17/2018 10/17/2018 0.40 PROD1 DRILL WPRT P PUH to log K1 for+1', trip in and log 8,010.0 8,029.0 08:42 09:06 RA@ 8141, TOWS=6134, TOW=8137, BOW=8140 10/17/2018 10/17/2018 0.20 PROD1 DRILL WPRT P RBIH to drill, returns fall off -8178'. 8,029.0 8,181.5- 09:06 09:18 Work to bottom 10/17/2018 10/17/2018 0.20 PROD1 DRILL DRLG P 8181', Drill 1.78 BPM @ 4010 PSI FS, 8,181.0 8,195.0 09:18 09:30 BHP=4130, RIW=12.8K 10/17/2016 10/17/2018 0.20 PRODt DRILL WPRT P 8195 Pick up stacking, Overpulling, 8,195.0 8,175.0 09:30 09:42 DHWOB=-1 OK, Initial PUW=55K with - 20K DHWOB 10/17/2018 10/17/2018 1.70 PROD1 DRILL WPRT T 8175 Stuck, work pipe, Try to orient 8,175.0 8,175.0 09:42 11:24 looks bit stuck. Diminshed / no returns. Reduce well head. Shut down pump to relax. Circulate 8 BBIs LVT down CT. Spot 2 BBIa out, let soak. Work pipe. Spot 3 more bbls out. Let soak. Work pipe and pop free 10/17/2018 10/17/2018 0.10 PROD1 DRILL WPRT P Continue wiper to cased hole 8,175.0 8,122.0 11:24 11:30 10/17/2018 10/17/2018 1.80 PROD1 DRILL CIRC P Pump 10 X 10 sweeps and circulate 8,122.0 8,013.0 11:30 13:18 bottoms up. Little material coming overshaker 10/17/2018 10/17/2018 0.10 PROD1 DRILL DLOG P 8013 tie into K1 for 1.5' correction 8,013.0 8,030.0 13:18 13:24 10/17/2018 10/17/2018 0.50 PROD1 DRILL WPRT P RBIH, stop @ 8127 and perfor static 8,030.0 8,127.0 13:24 13:54 pressure test, TVD 5931.4, Annular pressure 3935, EMW=12.7. Holding 12.8 PPG at window 10/17/2018 10/17/2018 0.10 PROD1 DRILL WPRT P RBIH to drill, stack and loose returns 8,127.0 8,195.0 13:54 14:00 78 work through 10/17/2018 10/17/2018 0.30 PROD1 DRILL DRLG P 8195', Drill, 1.77 BPM @ 3860 PSI 8,195.0 8,205.0 14:00 14:18 1 1 FS, BHP=3850 10/17/2018 10/17/2018 0.90 PROD1 DRILL WPRT P 8205, PUH into casing. Pressures all 8,205.0 8,111.0 14:18 75:12 over. Circ bootoms up. Sample to geo. Calls it B shale. Blow down micro motion Page 3119 Report Printed: 4115/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth StenTme EM Time Dur (hr) Phase Op code Activity Code Time P -T -X Operation (WB) End Depth (ftKB) 10/17/2018 10/17/2018 0.20 PROD1 DRILL WPRT P RBIH to drill 8,111.0 8,207.0 15:12 15:24 10/17/2618 10/17/2018 0.70 PROD1 DRILL DRLG P 8207', Drill, 1.76 BPM @ 3860 PSI 8,207.0 8,210.0 15:24 16:06 FS, BHP=4250, frequent pick ups. On pick up from 8210 became stuck 8190. Work pipe up to 50K, DHWOB=- 16K. Down to zero. DHWOB=6K 10117/2018 1011712018 0.60 PROD1 DRILL DRLG T Pipe stuck, Pump 8 BBIs LVT down 8,210.0 8,210.0 16:06 16:42 1 1 CT 10/17/2018 10/1712018 1.60 PROD1 DRILL WPRT P Get two We out CT let soak. Work 8,210.0 8,075.0 16:42 18:16 pipe. Pump 3 more bbls out let soak. Pull free. Trip to cased hole. Pump 10 X 10 sweeps, circulate multiple bottoms up, pump additioal sweep 10/17/2018 10/17/2018 1.80 PROD1 DRILL TRIP T Decision mae to POOH for cleanout 8,075.0 72.0 18:18 20:06 assembly, siltishale over shakers, not sticky, low clay content, fairly benign 10117/2018 10/17/2018 0.80 PRODi DRILL PULD T PJSM, PUD BHA #4 72.0 0.0 20:06 20:54 10117/2018 10/17/2018 1.90 PROD? DRILL PULD T PJSM, make up new tools, PD BHA 0.0 63.0 20:54 22:48 #5 (1.0" AKO motor, string reamer, D331 w/ridge-set, no Res tool), slide in cart, check pack -offs, MU to coil, tag up, set counters, blow down choke & micro -motion 10/17/2018 10/18/2018 1.20 PROD1 DRILL TRIP T RIH w/ BHA #5 63.0 5,500.0 22:48 00:00 10/18/2018 10/18/2018 0.50 PROD1 DRILL TRIP T RIH w/ BHA #5 5,500.0 8,005.0 00:00 00:30 10/18/2018 10/18/2018 0.10 PROD1 DRILL DLOG T Log K1 for -1' correction 8,005.0 8,037.0 00:30 00:36 10/18/2018 10/18/2018 0.50 PR0D1 DRILL DLOG T Continue RIH to 8100, Gose EDC, 8,037.0 8,137.0 00:36 01:06 PUW = 35K Slop, obtain SBHP (15 min): MD = 8120.6', TVD -senor = 5932.9', BHP = 4050 psi, WHP = 1367 psi, EMW = 13.13 ppg, pressure climbed during test 10/18/2018 10/18/2018 2.30 PROD1 DRILL REAM T Work to end of rat -hole in 10' bites, 8,137.0 8,137.0 01:06 03:24 PUW's = 35K, FS = 394 psi (off 1.8 bpm, BHP = 4071 psi Perfrom reaming passes of window & rat -hole (8137' to 8166'): HS down- hole. 30L, 30R, HS, & 2 passes LS all up -hole It fpm through window, 5 fpm in rat -hole), pump multiple sweeps 10/1812018 10/18/2018 1.90 PROD1 DRILL TRIP T POOH, open EDC, pre -loaded DS 8,137.0 59.0 03:24 05:18 1 9 1 PDL 10/1812018 10118/2018 1.00 PROD1 DRILL PULD T At surface, Tag up and space out. 59.0 0.0 05:18 06:18 PUD BHA#5 10/1812018 1011812018 0.40 PRODi DRILL PULD T Reconfigure pre loaded tool to remove 0.0 0.0 06:18 06:42 UltraSlimResistivity tool from BHA 10/1812018 10/1812018 1.10 PRODi DRILL PULD T Pressure deploy BHA #6 with 1.8" 0.0 62.6 06:42 07:48 AKO motor, RR HCC bi center. No agitator or USR. Make up to coil and surface test. Check pack offs 10/18/2018 10/18/2018 1.70 PROD1 DRILL TRIP T Trip in hole, BHA #6, Test HOT on 62.6 8,010.0 07:48 09:30 1 1 stop 10/18/2018 10/18/2018 0.10 PROD1 DRILL DLOG T Log K1 for -1/2', Close EDC, 8,010.0 8,030.0 09:30 09:36 PUW=34K Page 4119 Report Printed: 4/1512019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth sted T,me End TIme our (hr) Phase Op Code Activity Code Time P-T-X OperadonMKB) End Depth (WB) 10/18/2018 10/18/2018 0.40 PROD? DRILL TRIP T Trip in well, initial tag up @ 8176 work 8,030.0 8,210.0 09:36 10:00 down to next tag up @ 8195. Work down to 8209. recip up to 8160. Clear on way up. No overpulls on DHWOB. RBIH stack at 8179. work pipe down to 8210 10/18/2018 10/18/2018 0.40 PROD1 DRILL DRLG T 82101, Drill, 1.79 BPM @ 3850 PSI 8,210.0 8,216.0 10:00 10:24 FS, BHP=4075, Hard to maintain differential pressure. Able to gel all DHWOB. Tool is hanging up above bit. Multiple pick ups to gel back to bottom with Diff pressure 10/18/2018 10/18/2018 0.60 PROD1 DRILL WPRT T 8216, stacking out. PUH, PUW=50K. 8,216.0 8,216.0 10:24 11:00 Stuck @ 8190. Work pipe within limits of HOT. Seeing negative weight. Unable to orient. Work free. PUH to 8150. RIH to drill. Have to work 8178 down 10/18/2018 1011812018 1.40 PROD1 DRILL DRLG T 8216', Drill, 1.8 BPM 3995 PSI FS. 8,216.0 8,236.0 11:00 12:24 Returns coming and going. Start get gas in returns. Ship returns to tiger tank, Frequent pickups to get differential pressure. Unable to maintain steady state drilling 10/18/2018 10/18/2018 0.20 PROD1 DRILL WPRT T One of many pickups over pull and 8,236.0 8,236.0 12:24 12:36 stuck, Not showing any WOB. Able to orient freely. Work pipe. Little returns. Not showing any pull on HOT. Work free @ 70K 10/18/2018 10/18/2018 1.40 PROD1 DRILL WPRT T After pulled free BHA shorted out. 8,236.0 8,075.0 12:36 14:00 PUH to cased hole. Pump 10 X 10 sweeps. Circulate gas out of well Trouble shoot surface electrical componets. Shorted down hole 10/18/2018 10/18/2018 2.30 PROD1 DRILL TRIP T Trip out maintain 1 to 1. At 500' well 8,075.0 63.0 14:00 16:18 unloaded heavy shales. Jog back in hole. Pull to surface, Tag up and space out. Swap chokes and lost all WHIR Open up tangos. MP line showed zero. Open up whitey valve on riser. No pressure 10/18/2018 10/18/2018 1.00 PROD1 DRILL TRIP T Trip in hole to find pack off/ bridge 63.0 63.0 16:18 17:18 holding 1100 PSI WHIP. RIH to 750'.Saw nothing. Blleed off WHIP to 650 PSI. Bridge must be down much lower. POOH 10/18/2018 10118/2018 1.30 PROD1 DRILL PULD T PUD BHA #6, DBV bent (pictures on 63.0 0.0 17:18 18:36 S: drive), bit came out a 1-3 (7 broken reamer cutters & 1 plugged nozzle) 10/18/2018 1011812018 1.00 PROD1 DRILL PULD T Decision made to PU build assembly, 0.0 63.0 18:36 19:36 PD BHA #7 Build Assembly #3 (1.8° AKO motor, RR Dynamus bit, no RES tool), slide in cart, check pack-offs, MU to coil, tag up, set coutnem 10/18/2018 10/1812018 2.00 PROD1 DRILL TRIP T RIH w/ BHA#7, EDC closed, RIH 63.0 8,005.0 19:36 21:36 pumping anticipating bridge-off at unknown depth 10/18/2018 10/18/2018 0.20 PRODi DRILL DLOG T Log K1 for-0.5' correction, PUW = 8,005.0 8,030.0 21:36 21:48 134K 10/18/2018 10/18/2018 0.50 PRODi DRILL TRIP T Continue RIH, clean down to 8120', 8,030.0 8,100.0 21:48 22:18 pump 5x5 sweeps 10/18/2018 10/18/2018 0.40 PROD1 DRILL TRIP P Begin working through window, stack 8,100.0 8,133.0 2218 2242 8K WOB at 8133' (believe found bridge-off at window stopping flow to surface), allow sweeps to exit bit Page 5119 Report Printed: 411512078 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depen Start Time End Time our (m) Phese Op Code Acivily Code Time P-T-X Operabon (fiKB) End Depth (flKS) 10/18/2018 10119/2018 1.30 PROD? DRILL TRIP T EDC open, POOH for FCO assembly 8,133.0 600.0 22:42 00:00 10/19/2018 10/19/2018 0.50 PROD? DRILL TRIP T EDC open, POOH for FCO assembly, 600.0 63.0 00:00 00:30 tag up, PJSM 10/19/2018 10/19/2018 0.80 PROD? DRILL PULD T PUD BHA#7, bit came out balled up 63.0 0.0 00:30 01:18 with clay from seldown at TOWS, 2 plugged nozzles 10/19/2018 10/19/2018 1.20 PRODi DRILL PULD T PD BHA#8 FCO Assembly(1.0'AKO 0.0 63.0 01:18 02:30 motor, D331 w/ ridge-set), slide in cart, check pack-offs, MU to coil, tag up, set counters 10/19/2018 10/19/2018 1.80 PROD1 DRILL TRIP T RIH w/ BHA #8, corrupt data on Baker 63.0 8,005.0 02:30 04:18 screen, trouble-shoot & resolve issue 10/19/2018 10/19/2018 0.10 PROD1 DRILL DLOG T Log K1 for+4.5' correction, close EDC 8,005.0 8,027.0 04:18 04:24 10/19/2018 10/19/2018 0.20 PROD1 DRILL TRIP T RIH to TOWS, PEW = 35K 8,027.0 8,130.0 04:24 04:36 10/19/2018 10/19/2018 0.70 PROD1 DRILL TRIP T FCO from TOWS, 1.8 bpm, FS = 360 8,130.0 8,163.0 04:36 05:18 psi, circ = 3792, BHP = 4080 psi, WHP = 780 psi, 390 lb molorwork beginning at 8146', PUW = 37K from 8147', pull up through window. Continue in-hole to end of rat-hole (8163'), PUH to BOW, PUW = 37K 10119/2018 10/19/2018 1.00 PROD1 DRILL TRIP T Continue FCO, 1.77 BPM. Set down 8,163.0 8,150.0 05:18 06:18 @ 8186, Pull heavy 52K, -61K DHWOB. PUH pack off RBIH to 8173. PUH to window. 10/19/2018 10/19/2018 0.10 PRODt DRILL DLOG T Log RA for+t'comection 8,150.0 8,173.0 06:18 06:24 10/19/2018 10/19/2018 2.80 PROD1 DRILL WPRT T RBIH, stckout @ 8175 recip up hole to 8,173.0 7,960.0 06:24 09:12 8098. RBIH to 8216. Packoff with overpull, 70K. PUH to 8150. RBIH to bottom @ 8234, Pumping multiple sweeps. Getting medium amount of shales on shaker. Pull up through window at full rate. PUH through 7" to 7960, 10/19/2018 10/19/2018 0.20 PROD1 DRILL WPRT T RBIH, clean pass through window 7,960.0 8,139.0 09:12 09:24 stack at 8175. PUH stuck at window 8139. 10/19/2018 10/19/2018 1.10 PROD1 DRILL WPRT T Work pipe out of window, PUH to 8,139.0 7,960.0 09:24 10:30 8070. RBIH clean through window. Stack out at 8175. Pick up sticky 65K with -17K DHWOB. PUH to TT at full rate with more sweeps 10119/2018 10119/2018 2.00 PROD1 DRILL WPRT T 7960 RBIH dean through window. run 7,960.0 8,063.0 10:30 12:30 past 8275 @ 4 FPM with 90% returns. Full returns back @ 8285. Continue to bottom @ 8126. Recipt twice to 8143. Pumping sweeps. Maintaining full returns. Hole looks clean. Not stacking or over pulls. Pump 10 X 10 sweeps 10/19/2018 1011912018 1.80 PROD1 DRILL WPRT T Sweeps out, Chase to swab. Jog @ 8,063.0 60.0 12:30 14:18 729' Hole unloading. Same shales as yesterday 10/19/2018 10/192018 1.50 PROD1 DRILL WPRT T Tag up at surface, Set counters, RBIH 60.0 8,010.0 14:18 15:48 10/19/2018 10/19/2018 0.10 PROD1 DRILL DLOG T Log K1 for +11', PUW=32K 8,010.0 8,030.0 15:48 15:54 10/19/2018 10/192018 0.10 PROD1 DRILL WPRT T Continue in well. Clean through 8,030.0 8,234.0 15:54 16:00 window and past 8175 to 8185 area with returns Page 6119 Report Printed: 4/15/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depn StartTine End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation MKB) End Depth (BKS) 10/19/2018 10/19/2018 0.40 PRODt DRILL WPRT T PUH to 7". Clean trip through build 8,234.0 8,130.0 16:00 16:24 with no overpulls no packoff events. Start sweeps down CT 10/19/2018 10/19/2018 0.10 PRODt DRILL WPRT T Sweeps close to bit. RBIH to 8200. 8,130.0 8,200.0 16:24 16:30 Clean trip to 8200 10/19/2018 10/19/2018 1.70 PRODt DRILL WPRT T Sweeps at bit, POOH pumping 1.8 8,200.0 63.0 16:30 18:12 BPM, PUW=33K, open EDC, PJSM 10/19/2018 10/19/2018 0.90 PROD1 DRILL PULD T PUD BHA #8, mill came out 2.80" no- 63.0 0.0 18:12 19:06 1 Igo 10/19/2018 10/19/2018 1.00 PROD1 DRILL PULD T PD BHA#9 (Build Assembly, 1.8° AKO 0.0 63.0 19:06 20:06 motor, RR P104 bit, & no res tool), slide in cart MU to coil, change out pack -offs, tag up, set counters 10/19/2018 10/1912018 1.60 PROD1 DRILL TRIP T RIH w/ BHA#9, lost COMMS to BHA 63.0 7,975.0 20:06 21:42 at 4146', stop trouble -shoot, resolved 10/19/2018 10119/2018 0.60 PROM DRILL DLOG T Did not see K1 on first pass, PUH to 7,975.0 8,025.0 21:42 22:18 7975 to re -log, +34.5' correction 10/19/2018 10/19/2018 0.40 PROD1 DRILL TRIP T Continue RIH, PUW = 38K, log RA for 8,025.0 8,236.0 22:18 22:42 1 1 1+1' correction, bring up rate 10/19/2018 10/19/2018 0.80 PROD? DRILL DRLG P OBD, 1.88 bpm, FS = 525 psi, circ = 8,236.0 8,330.0 22:42 23:30 4313 psi, CWT = 13K, WOB = 1.81K, BHP = 4120 psi, WHP = 710 psi, pump sweeps, Begin packing off at 8330', losing returns 10/19/2018 10/20/2018 0.50 PROD1 DRILL WPRT P Wiper, PUW = 45K, continue to pull 8,330.0 8,050.0 23:30 00:00 heavy, working up & down to release pack -off, pulling up to 68K, density out drops, Gear packoff, pull up through window, begin taking returns to TT, begin circulating bottoms up 10/20/2018 10/20/2018 0.50 PROD1 DRILL WPRT P Continue circulating bottoms up in 7" 8,050.0 8,050.0 00:00 00:30 casing, sweeps coming to surface, density out climbs to 8.94 ppg, bring returns back inside after 42 bbls Sample to geo: —50% cavings, remaining 50% mixutre of cuttings (shale & sand) 10/20/2018 10/20/2018 0.40 PROD? DRILL WPRT P RBIH, stack weight at 8164', PUW = 8,050.0 8,175.0 00:30 00:54 38K, stack again at 8169', again at 8170', begin packing off, begin losing returns, pull -1 OK WOB, wiper to bottom of window, tum around 10/20/2018 10/20/2018 0.90 PROD1 DRILL WPRT P RBIH at 7 fpm, taking bites & PUH, 8,175.0 7,835.0 00:54 01:48 begin packing off at 8205', erratic returns, recipreate pipe to clear pack - off, PUW = 45K, pulling heavy up to 66K Pull up to tubing tail & circulate, 8.9 ppg slug over shakers, rate out drops while in 7", circulate bottoms up, pull 500' into tubing tail 10/20/2018 10/20/2018 1.40 PROD1 DRILL WPRT T Circulating, pins/ retaining -stops on 6 7,835.0 7,835.0 01:48 03:12 gripper block plates sheared pff, elastomers worn, circulate awaiting mechanic, 10/20/2018 10/20/2018 4.70 PROM DRILL TRIP T POOH @ 50 fpm, EDC open 7,835.0 63.0 03:12 07:54 Decision made to POOH, replace failed gripper block plates & elastomers on Nabors rig repair time Page 7119 Report Printetl: 4/15/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Dapih Swarm End Time Dur (hr) Phase Op Code Activity Cade True P -T -X Operation (flK8) End DeW (WB) 10/20/2018 10/20/2018 1.60 PROW DRILL PULD T PJSM, PUD BHA #9, Lay down BHA 63.0 0.0 07:54 09:30 10/20/2018 10/20/2018 3.00 PROD1 DRILL RGRP T Continue with repairs to chains, 0.0 0.0 09:30 12:30 Change out all elastomers Confer with town asset, drilling, & dg. Decision made to cleanout down to 7" & set backup .. 8 hrs agreed upon for Nabors rig repair time (SIMOPS w/ replanning of second WS) 10/20/2018 10/20/2018 1.20 PROD? DRILL PULD T Repairs complete, Start making up 0.0 0.0 12:30 13:42 build section BHA. Plan change going to run whipstock 10/20/2018 10/20/2018 0.90 PROD1 DRILL PULD T M/U BHA#10. FCO BHA with 1° motor 0.0 62.3 13:42 14:36 and D-331. Pressure deploy. Make up Ito coil and surface test 10/20/2018 10/20/2018 1.80 PROD1 DRILL TRIP T Trip in hole to clean 7" casing for 62.3 7,995.0 14:36 16:24 whipstock set 10/20/2018 10/20/2018 0.10 PROD1 DRILL DLOG T 7995', Log K1 for- 1/2', PUW=39K, 7,995.0 8,031.0 16:24 16:30 Pumping sweeps 10/20/2018 10/20/2018 1.80 PROD1 DRILL CIRC T PUH circulating sweeps DH 8,031.0 8,128.0 16:30 18:18 10/20/2018 10/20/2018 1.60 PROD1 DRILL TRIP T POOH, open EDC 8,128.0 62.0 18:18 19:54 10/20/2018 10/20/2018 1.00 PROD1 DRILL PULD T PUD BHA#10 62.0 0.0 19:54 20:54 10/20/2018 10/20/2018 1.90 PROD1 RPEQPT PULD T MU & PU HEW, PD BHA#11 (HEW 0.0 74.0 20:54 22:48 Whipstock #2), slide in cart, MU to coil, tag up, set counters 10/20/2018 10/21/2018 1.20 PRODt RPEQPT TRIP T RIH w/ BHA #11 74.0 5,400.0 22:48 00:00 10/21/2018 10/21/2018 0.40 PROD1 RPEQPT TRIP T Continue RIH w/ BHA#11, EDC open 5,400.0 8,015.0 00:00 00:24 10/21/2018 10/21/2018 0.10 PRODt RPEQPT DLOG T Log K1 for -1' correction 8,015.0 8,043.0 00:24 00:30 10/21/2018 10/21/2018 0.40 PROD1 RPEQPT TRIP T Continue RIH, arrive at setting depth 8,043.0 8,103.8 00:30 00:54 (8103.78'), PUW = 38K, RBIH, close EDC, bring up pump, shear off @ 5100 psi, set down 2K on WS, PUW = 37K, TOWS -8095', oriented HS 10/21/2018 10/21/2018 1.40 PROD1 RPEQPT TRIP T POOH, EDC open, PJSM 8,103.8 65.0 0054 02:18 10/21/2018 10/21/2018 1.10 PROD1 RPEQPT PULD T PUD BHA#11 65.0 0.0 0218 03:24 10/21/2018 10/21/2018 1.50 PROD1 WHPST PULD T PD BHA#12 Window Assembly (1.0° 0.0 77.0 03:24 04:54 AI motor, string reamer, window mill), slide in cart, check pack -offs, clean up metal built around brass & pressure wash, MU to coil, tag up, set counters 10/21/2018 10/21/2018 1.80 PROD1 WHPST TRIP T RIH w/ BHA#12, Tagged up on collar 77.0 8,025.0 04:54 06:42 @ 4965', Work through, Coninue in 10/21/2018 10/21/2018 0.20 PROD1 WHPST DLOG T Log K1 for -1.5' corretion, PUW=36K, 8,025.0 8,046.0 06:42 06:54 close EDC 10/21/2018 10/21/2018 0.10 PROD1 WHPST TRIP T Continue in well, Dry tag pinch point 8,046.0 8,099.5- 06:54 07:00 @ 8099, PUH 10/21/2018 10/21/2018 2.60 PROD1 WHPST MILL T Pumps on 1.8 BPM @ 4530 PSI FS, 8,099.0 8,100.4 07:00 09:36 BHP=4095. Call pinch point 8097.5. Start milling window per procedure Page 8119 ReportPrinted: 4/15/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth start Time EM Time our (hr) Phase Op Code Activity Code Time PJA Operation (WB) EM Depth (ttK6) 10/21/2018 10/21/2018 2.40 PROW WHPST MILL T Call BOW 8100.4 Time Milling 8,100.4 8,100.3 09:36 12:00 formation 10/21/2018 10/21/2018 1.50 PROD1 WHPST MILL T Milling rathole, Stall @ 8103.19 8,100.3 8,103.3 12:00 13:30 Restart and stall here again 10/21/2018 10/21/2018 4.40 PRODi WHPST MILL T Continue milling ralhole, 1.81 BPM @ 8,103.3 8,122.0 13:30 17:54 4620 PSI FS, BHP=4050 10/21/2018 10/21/2018 2.10 PROD1 WHPST REAM T Perform reaming passes 1 fpm 8,122.0 8,122.0 17:54 20:00 through window, 5fpm in rat -hole (HS, 30L, 30R, LS), dry ddtt up & down, clean 10/21/2018 10/21/2018 1.70 PROD1 WHPST TRIP T POOH, EDC open, lost WITS data, 8,122.0 77.0 20:00 21:42 trouble -shoot, reboot Caring server, up & running. 10/21/2018 10/21/2018 1.20 PROD1 WHPST PULD T PUD & LD BHA#12, mill came out 77.0 0.0 21:42 22:54 2.79" no-go, string reamer Came out 2.80" no-go 10/21/2018 10/222018 1.10 PRODt DRILL CTOP T Clear floor, MU nozzle, stab on & jet 0.0 0.5- 22:54 00:00 stacK Sunday Safety Meeting in dog -house (SIMOPS) 10/22/2018 10/222018 0.50 PROD1 DRILL CTOP T Break off nozzle, clear floor, break 0.0 0.0 00:00 00:30 down & snake MM 10/22/2018 10/22/2018 1.30 PROD1 DRILL PULD T PJSM, PD BHA#13 Build Assembly 0.0 62.0 00:30 01:48 (2.4° AKO motor, RR Hughes bit), MU to coil, check pack -offs, tag up, set counters 1022/2018 10/22/2018 1.60 PROD1 DRILL TRIP T RIH w/ BHA#13 62.0 8,010.0 01:48 03:24 10/22/2018 10/22/2018 0.20 PROD1 DRILL DLOG T Log K1 for -1' correction, close EDC, 8,010.0 8,030.0 03:24 03:36 1 1 PUW = 38K 10/22/2018 10/22/2018 0.40 PROD1 DRILL TRIP T Continue RIH, did not find bottom at 8,030.0 8,136.0 03:36 04:00 8122', found it at 8136', stalled, PUW = 38K 10/22/2018 10/222018 0.80 PRODi DRILL TRIP T PUH to log RA, did not see it & tag at 8,136.0 8,136.0 04:00 04:48 8134', PUW = 38, RIH to find bottom, stall 10/222018 10/22/2018 0.30 PRODi DRILL TRIP T PUH to log K1 & find RA. Log K1 for 0' 8,136.0 8,136.0 04:48 05:06 correction, do not see RA tag, PUW = 38K, PUH 10/22/2018 10222018 0.20 PROD? DRILL TRIP T Confer with town, attempt to find RA 8,136.0 8,136.0 05:06 05:18 1 1 an additional time, 10/22/2018 10222018 1.60 PROD1 DRILL TRIP T No sign of RA marker, POOH. Open 8,136.0 65.0 05:18 06:54 EDC @ 8024 10/222018 10/222018 1.20 PROD1 DRILL PULD T Tag up / space out, PJSM. PUD BHA 65.0 0.0 06:54 08:06 #13 10/222018 10222018 0.30 PROD1 DRILL BOPE P Perform Bi Weeekly BOPE function 0.0 0.0 08:06 08:24 test 10/22/2018 10/22/2018 3.10 PROD1 DRILL WAIT T Stand by for Caliper, Inspect CT .195 0.0 0.0 08:24 11:30 min wall thickness found. Pull all gripper blocks and check elastomers - AII good 10/22/2018 10222018 1.00 PRODt DRILL PULD T HES on location, M/U caliper and put 0.0 25.7 11:30 12:30 in well. Rig up HES computer 10/22/2018 10/22/2018 2.10 PROD1 DRILL TRIP T Trip in with BHA #14 HES caliper 25.7 8,029.0 12:30 14:36 10/22/2018 10/22/2018 0.10 PROD1 DRILL DLOG T Log K1 for+20, Continue in 8,029.0 8,050.0 14:36 14:42 10/22/2018 10/22/2016 0.10 PROD1 DRILL TRIP T Continue in well 8,050.0 8,126.0 14:42 14:48 10/22/2018 10/22/2018 0.30 PROD1 DRILL DLOG T 8126. run 2 logging passes up to 8,126.0 8,000.0 14:48 15:06 8000' Page 8119 ReportPrinted: 4/15/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stad Depth Stan Time End Time our (hr) Phase op Cade Activiy Code Time P -T -X Opereuun (RXB) End Depth (WB) 10122/2018 10/2212018 1.30 PROD1 DRILL TRIP T POOH with HES caliperr 8,000.0 25.0 15:06 16:24 10/2212018 10/22/2018 1.50 PROD1 DRILL PULD T At surface, Lay down BHA#14 HES 25.0 0.0 16:24 17:54 caliper 10/22/2018 10/22/2018 0.20 PROD1 DRILL SFTY P Crew change, PJSM o service dg 0.0 0.0 17:54 18:06 valves 1012212018 10/22/2018 0.90 PRODi DRILL SVRG P Service rig valves 0.0 0.0 18:06 19:00 10122/2018 10122/2018 0.60 PRODt DRILL PULD P PJSM, M/U nozzle and stinger. Put in 0.0 16.8 19:00 19:36 well and hook up coil. M/U injector to well. Tag up 10/22/2018 10/2212018 1.90 DEMOB WHDBOP DISP P Trip in hole. Seawater here load into 16.8 8,050.0 19:36 21:30 suction pit. Start pumping sewater time to get to nozzle @ 8050 10/22/2018 10/22/2018 1.60 PROD1 WHDBOP FRZP P 10 BBIs seawater out of CT. Trip out. 8,050.0 17.0 21:30 23:06 Freeze protect from 2500' with diesel 10122/2018 10/23/2018 0.90 PROD1 WHDBOP PULD P At surface, Tag up and shut swabs. 17.0 0.0 23:06 00:00 Lay down BHA#15 "" 1400 psi WHP 1012312018 10/23/2018 1.00 DEMOB WHDBOP CTOP P Complete jetting stack & surface lines 0.0 0.0 00:00 01:00 10/2312018 10/2312018 2.30 DEMOB WHDBOP CTOP P Await valve crew, crews prepping to 0.0 0.0 01:00 03:18 move rig, boyo -scope stack 1012312018 102312018 1.00 DEMOB WHDBOP RURD P Set BPV 0.0 0.0 03:18 04:18 1023/2018 10/232018 2.70 DEMOB WHDBOP RURD P Clear floor, prep for move, await plan 0.0 0.0 04:18 07:00 forward 10/23/2018 10123/2018 2.50 DEMOB WHDBOP RURD P Freeze protect tree, work RD 0.0 0.0 07:00 09:30 checklist, ND BOPE Rig Released: 10/23/18 @ 9:30 AM 3/5/2019 3/5/2019 4.70 MIRU MOVE MOB P Trucks on location, PJSM Pull off well. 0.0 0.0 13:00 17:42 Sub off @ 16:00, Pits off 16:45. DSO change out on location 17:30. Leave 3M 17:45 3/5/2019 3/6/2019 6.30 MIRU MOVE MOB P Travel to 2G 0.0 0.0 17:42 00:00 3/62019 3/6/2019 3.00 MIRU MOVE MOB P Travel to 2G 0.0 0.0 00:00 03:00 3/62019 3/6/2019 1.00 MIRU MOVE MOB P On 213, De Jeep, Rig up cellar lay 0.0 0.0 03:00 04:00 1 1 Ihercu lite 3/62019 3/6/2019 2.00 MIRU MOVE MOB P Spot sub and pits 0.0 0.0 04:00 06:00 3/62019 3/6/2019 1.00 MIRU MOVE RURD P PJSM, Safe out rig. Start working rig 0.0 0.0 06:00 07:00 up check list 3/62019 3/6/2019 1.50 MIRU MOVE RURD P PJSM, R/U Putz, R/U Steam. R/U to 0.0 0.0 07:00 08:30 unstab Coil 3/62019 3/6/2019 1.50 MIRU MOVE OTHR P Unstab CT and secure to storage 0.0 0.0 08:30 10:00 spool 3/6/2019 3/6/2019 1.50 MIRU MOVE OTHR P remove riser from injector, remove 0.0 0.0 10:00 11:30 stuffing box, remove gripper blocks 3/62019 3/6/2019 3.00 MIRU MOVE OTHR P Disconnect Injector electrical service, 0.0 0.0 11:30 14:30 hydraulic lines, and instrumentation 3/6/2019 3/62019 1.50 MIRU MOVE OTHR P PJSM, Rig up injector to crane, Pull up 0.0 0.0 14:30 16:00 on injector unbolt cart bolts. Lift injector out of rig to ground 3/6/2019 3/6/2019 1.50 MIRU MOVE OTHR P Prep new injector for lift into rig 0.0 0.0 16:00 17:30 3/6/2019 3/62019 1.00 MIRU MOVE OTHR P Pick & set new injector onto rig 0.0 0.0 17:30 18:30 Page 10119 Report Printed: 411512019 Operations Summary (with Timelog Depths) 2G -O6 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log S art Depth Star)Time End Time DH (hr) Phase OP Code AavM Code Time PJA Operation (flKB) EM DeWMKB) 3/6/2019 3/6/2019 3.00 MIRU MOVE O I MR P Begin connecting electrial & hydraulic 0.0 0.0 18:30 21:30 lines, tighten/adjust goose -neck (Nabors electrician & Peter O'Brian houred out, went back to camp to rest), secure injector to cart 3/6/2019 3/7/2019 2.50 MIRU MOVE OTHR P Clear rig floor, slide injector back, NU 0.0 0.0 21:30 00:00 BOPE, continue connecting hydraulic lines, vis'd up seawater for window milling 317/2019 3/712019 1.50 MIRU MOVE OTHR P Grease surface valves in prep for BOP 0.0 0.0 00:00 01:30 test, install BOP riser 3/7/2019 3/7/2019 1.50 MIRU MOVE OTHR P Verify Koomey bottle levels, inspect 0.0 0.0 01:30 03:00 mud pump #1, fill injector fluids, grease master, swabs, & tangos, open up & inspect chokes (both look good) 3!7/2019 317/2019 3.00 MIRU MOVE OTHR P Clean up hammer union "ears", 0.0 0.0 03:00 06:00 change out mud -pump #1 wom valve/seat 3/7/2019 317/2019 7.00 MIRU MOVE OTHR P Crew change, Continue to hook up 0.0 0.0 06:00 13:00 injector, Complete MP #1 reconditioning 3/7/2019 3/712019 1.00 MIRU WHDBOP OTHR P Move injector /1 Prep for full BOPE 0.0 0.0 13:00 14:00 test. Test witness waived by Adam Ead, AOGCC 3/7/2019 3/7/2019 5.00 MIRU WHDBOP BOPE P Start full BOPE test, fail/pass on 0.0 0.0 14:00 19:00 Tango 1 (250 psi low/ 4800 psi high) Working injector in SIMOPS (Nabors/Peter O'Bdna/HydraRig rep) 3/7/2019 3/7/2019 4.00 MIRU WHDBOP BOPE P Continue w/ BOP test, continue 0.0 0.0 19:00 23:00 injector tests in SIMOPS, install gripper blocks, perfrom draw -down test, laydown test jnt, clear floor 3/7/2019 3/7/2019 0.20 MIRU WHDBOP OTHR P PU & install stripper & riser 0.0 0.0 23:00 23:12 3/7/2019 3/8/2019 0.80 MIRU WHDBOP OTHR P Crew change, PJSM, begin slabbing 0.0 0.0 23:12 00:00 coil, pull test crapple to 900 psi, good, remove reel chains, unlock reel, pull pipe through injector 3/8/2019 3/8/2019 0.80 MIRU WHDBOP OTHR P Complete stabbing pipe, break down 0.0 0.0 00:00 00:48 grapple, tugger line & snatch block, Gear floor, injector error (motor differential detected), confer w/ O'Brain, continue running pipe through injector, break off nozzle 3/8/2019 31812019 0.90 MIRU WHDBOP OTHR P Install UQC, re -head a -line & test, PT 0.0 0.0 00:48 01:42 UQC to 4500 psi 3/8/2019 3/8/2019 1.30 MIRU WHDBOP PRTS P MU nozzle, check pack -offs, slab -on, 0.0 0.0 01:42 03:00 test IRV & stripper Small hydraulic leak from stripper T - fitting (call out mechanic to repair) 3/8/2019 3/8/2019 1.00 MIRU WHDBOP PRTS P PT tiger -tank line & PDL's, adjust 0.0 0.0 0300 04:00 goose -neck 3/8/2019 3/8/2019 0.60 MIRU WHDBOP OTHR P Continue goose -neck adjustments 0.0 0.0 04:00 04:36 I 3/8/2019 3/8/2019 0.40 MIRU WHDBOP OTHR P Open up well, 1280 pdi, bleed off to 0.0 0.0 04:36 05:00 TT, slowly building pressure on MP line, blow down TT line 3/8/2019 3/8/2019 4.50 MIRU WHDBOP OTHR P Install checks, MU nozzle, RIM, 0.0 0.0 05:00 09:30 Pumping seawater returns to tiger tank. Recip while ARP making adjustments / taking readings. Do not run in deeper then 300' Page 11119 Report Printed: 4/1 512 01 9 Operations Summary (with Timelog Depths) 2G -O6 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SW Depth StartTime, End Time our (hr) Phage Op Code Activity Code Time P -T -X Operation (aK6) End Depth (ftKB) 3/812019 318/2019 0.50 MIRU WHDBOP OTHR P Unstab injector. remove nozzle. M/U 0.0 0.0 09:30 10:00 pull plate. Pull test injector to 45K in 10K steps. Hold 45K. Relax coil. End of surface testing 3/8/2019 3/8/2019 1.30 PROD1 WHPST PULD P M/U BHA#16 with Weatherford V 0.0 77.2 10:00 11:18 fixed bend motor, 2.80 Dimond window mill, and RR string reamer 3/8/2019 3/8/2019 1.80 PROD1 WHPST TRIP P RIH BHA#16, EDC open pumping 77.2 8,020.0 11:18 13:06 seawater @ .4 BPM. Monitoring injector 3/8/2019 3/8/2019 0.10 PROD1 WHPST DLOG P Log K1 for -2', PUW=30K 8,020.0 8,045.0 13:06 13:12 3/8/2019 3/8/2019 0.80 PROD1 WHPST CIRC P Displace coil /well to viscosifed 8,045.0 8,066.0 13:12 14:00 milling fluid 3/8/2019 3/8/2019 0.10 PROD1 WHPST TRIP P Continue in, tag top of cement Q 8,066.0 8,085.0 14:00 14:06 8085, PUH 3/8/2019 3/8/2019 1.10 PROD1 WHPST MILL P Bring on pumps 1.8 BPM @ 3725 PSI 8,085.0 8,097.9 14:06 15:12 FS, Call TOC rQ 8084. Tough to get going. Once going ROP - 20 FPH. Roll toolface to 10° ROHS to handle walking in mini pilot hole 3/8/2019 3/8/2019 2.30 PROD1 WHPST MILL P ROP stopped, Call this pinch point. 8,097.9 8,099.4 15:12 1730 Roll TF to HIS. 1.79 BPM @ 3757 PSI FS. Start time milling window per procedure / Northern soulotions rep (TOW = 8098.3'). Hold at least 11.8PPG in rathole (per engineer) 3/8/2019 3/8/2019 2.30 PROD1 WHPST MILL P Continue milling window, CWT= 8,099.4 8,100.0 17:30 19:48 11.71K, WOB = 2.1 K, annular = 3280 psi, pump = 4017 psi, 1 for 1 returns, milling slows down, PU from 8099.9', FS = 610 psi 3/8/2019 3/812019 1.40 PRODt WHPST MILL P Milling window, CWT= 10.61K, WOB = 8,100.0 8,100.4 19:48 21:12 3.21K, annular = 3281 psi, pump = 4101 psi, 1.8 bpm, bleed down IA, slow milling progress, NS rep requests WOB increase to 4K. '• Pre -load ODS PDL 31812019 319/2019 2.80 PROD1 WHPST MILL P Continued slow milling, PU per NS 8,100.4 8,101.5 21:12 00:00 rep, PUW = 27K, FS = 600 psi, begin seeing weight at 8,099.9' (made footage from last PU), call BOW 8101' (2.7' window) 3/9/2019 319/2019 0.60 PROD1 WHPST MILL P Continue milling window from 8101.5', 8,101.5 8,102.3 00:00 00:36 CWT= 12K, WOB=.9K, annular= 3283 psi TOW = 8098.3', BOW = 8101' 3/9/2019 3/9/2019 2.40 PROD1 WHPST MILL P String reamer exits window, milling rat- 8,102.3 8,124.0 00:36 03:00 hole, begin pushing on it, CWT = 10K WOB = 3.2K, increase ECD at window to 12.4 ppg, WHIP = 549 psi, dirt in samples 3/9/2019 3/9/2019 1.80 PROD1 WHPST REAM P PUW = 27K, pump 5x5 sweep, 6,124.0 8,124.0 03:00 04:48 perform reaming passes, 2 HIS, 30L, 30R, & LS, dry drift window up & down, clean, confirm rat -hole TD, pump 5x5 sweeps 3/9/2019 3/9/2019 1.60 PROD1 WHPST TRIP P POOH, PUW = 28, open EDC 8,124.0 77.0 04:48 06:24 3/9/2019 3/9/2019 1.20 PROD1 WHPST PULD P At surface, tag up and space out. PUD 77.0 0.0 06:24 07:36 BHA#16. Mill out 2.79 No go Page 12119 ReportPrinted: 4/15/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stas Depth Startn" End Tim Dur (hr) Phase op code Acbv'M Code Time P -TA Operation (MIB) End Depm(MKB) 3/9/2019 3/9/2019 0.90 PROD1 DRILL CTOP P Make up nozzle and jet stack 0.0 0.0 07:36 08:30 3/9/2019 3/9/2019 1.40 PROD1 DRILL PULD P PD BHA#17 with 2.5` AKO motor and 0.0 72.2 08:30 09:54 RB HCC bit with Dynamus cutters. TX25207. PDL was preloaded. Make up to coil and surface test. Check packoffs. 3/9/2019 3/9/2019 2.30 PROD1 DRILL TRIP P Trip in BHA# 17 to drill build / tum 72.2 8,005.0 09:54 12:12 1 1 section rolling CT to mud system #1 3/9/2019 3/9/2019 0.10 PROD1 DRILL DLOG P Log K1 for -5.5' 8,005.0 8,033.0 12:12 12:18 3/9/2019 3/9/2019 0.70 PROD1 DRILL TRIP P Continue trip in. Complete fluid swap 8,033.0 8,124.0 12:18 13:00 Clean pass through window, Tag up and drill ahead @ 8124 3/9/2019 3/9/2019 3.10 PROD1 DRILL DRLG P 8124', Drill, 1.8 BPM @ 4691 PSI FS, 8,124.0 8,259.0 13:00 16:06 BHP=3771, RIW=9.1K, DHWOB=I.5K 3/9/2019 3/9/2019 0.10 PROD1 DRILL WPRT P 8259, BHA Wiper, PUW=28K 8,259.0 8,259.0 16:06 16:12 3/9/2019 3&2019 1.80 PROD1 DRILL DRLG P 8259', Drill, 1.9 BPM @ 4874 PSI FS, 8,259.0 8,403.0 16:12 18:00 BHP=3940 3/9/2019 3/9/2019 1.00 PROD1 DRILL WPRT T PUW = 29K, allow DD to grab survey. 8,403.0 8,080.0 18:00 19:00 Discover bolt walked out on pillow - block, pull into cased hole to install, dragging 41K WOB through 8370' 3/9/2019 3/9/2019 0.50 PROD1 DRILL DLOG P Log K1 for+4.5' correction, log RA at 8,080.0 8,140.0 19:00 19:30 8102' 3/9/2019 3/92019 0.20 PROD1 DRILL WPRT P RIH to drill, 2.31K WOB spike at 8263', 8,140.0 8,403.0 19:30 19:42 1 1 RIW = 8.3K 3/9/2019 3/92019 0.30 PROD1 DRILL DRLG P Drilling, FS = 600 psi, CWT = 6.6K, 8,403.0 8,450.0 19:42 20:00 WOB = 2.2K, bhp = 3980 psi, pump = 5078 psi, WHIP = 522 psi (12.7 ppg @ window), pump 5x5 sweeps 3/92019 3/9/2019 1.70 PROW DRILL TRIP P POOH, PUW = 26K, clean through 8,450.0 72.0 20:00 21:42 build & window, open EDC, tag up, PJSM 3/92019 3/9/2019 1.30 PROD1 DRILL PULD P PUD BHA #17. once cart slid back, 72.0 0.0 21:42 23:00 lock -out storage reel, check and lighten hub & saddle clamp bolts, blow -down MM, bit came out 1-1, balledup, & 1 plugged nozzle 3/9/2019 3/10/2019 1.00 PROD? DRILL PULD P Begin PD BHA#18 "A" Lateral 0.0 78.0 23:00 00:00 Assembly (NOV Agitator, 0.5" AKO motor, RB HYC A3 bit), lock -out injector, roll chains, check/inspect gripper blocks Note: Welll-ink moved forward 1 hr for DLS time prior to RIH (@ -23:00 hrs) 3/10/2019 3/10/2019 0.40 PRODt DRILL PULD P Complete PD BHA#18, slid in cart, 78.0 78.0 00:00 00:24 check pack -offs, MU to coil, set counters 3/10/2019 3/10/2019 1.50 PROD1 DRILL TRIP P RIH w/ BHA#18 78.0 8,015.0 00:24 01:54 3/10/2019 3/102019 1.20 PRODt DRILL DLOG P Log Kt for -5' correction, close EDC, 8,015.0 8,047.0 01:54 03:06 PUW = 28K (Note: Added 1 hour in this cell to account for daylight saving time) 3/10/2019 3/102019 0.30 PROD1 DRILL TRIP P Continue RIH, RIW = 9.5K, captured 8,047.0 8,450.0 03:06 03:24 agitator transducer screens Page 13/19 Report Printed: 4/15/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Start Time End Time Dur (hd Phase Op Code Adtivtty Code TMs P -T -x Operation (aKB) End Depm (rtKB) 3/10/2019 3/10/2019 1.60 PRODt DRILL DRLG P Drilling, FS = 940 psi @ 1.85 bpm, 8,450.0 8,663.0 03:24 05:00 CWT = 7K, WOB = 1.7K, annular = 4006 psi, WHIP = 595 psi, pump = 5382 psi, dp = 1347 psi, 1 for 1 returns, by-pass MM & blow -down again, -1/2"shale pieces from MM blow down 3/10/2019 3/1012019 1.80 PROD1 DRILL DRLG P Drilling, CWT = 3.9K, WOB = 2K, 8,663.0 8,900.0 05:00 06:48 annular = 4069 psi, pump 5505 psi, WHP = 496 psi, PUW = 28K from 8686' 311012019 3/10/2019 0.60 PROD? DRILL WPRT P 8900', Wiper trip, PUW=29K 8,900.0 8,900.0 06:48 07:24 311012019 3/10/2019 2.60 PROD1 DRILL DRLG P 8900', Drill, 1.9 BPM @ 5254 PSI FS, 8,900.0 9,172.0 07:24 10:00 BHP=4014 3/10/2019 3/10/2019 0.10 PROD1 DRILL WPRT P 9172', BHA wiper, PUW=31K 9,172.0 9,172.0 10:00 10:06 3/10/2019 3/10/2019 0.60 PROD1 DRILL DRLG P 9172', Drill, 1.9 BPM @ 5229 PSI FS, 9,172.0 9,300.0 10:06 10:42 BHP=4061 3/10/2019 3/10/2019 1.00 PROD1 DRILL WPRT P 9300', Wiper to jet 7" and tie in, With 9,300.0 8,015.0 10:42 11:42 1 sweeps off bottom and another set in 7", PUW=30K 3/10/2019 3/102019 0.10 PRODt DRILL DLOG P Log Tie in for +.5' 8,015.0 8,042.0 11:42 11:48 3/10/2019 3/10/2019 0.60 PROD1 DRILL WPRT P Continue in well. Set down in build 8,042.0 9,300.0 11:48 12:24 -8124'. Work pipe, reduce rate momentarily to pass. Continue in 3/10/2019 3/10/2019 0.50 PROD1 DRILL DRLG P 9300', Drill, 1.9 BPM @ 5240 PSI FS, 9,300.0 9,380.0 12:24 12:54 BHP=4107, RIW=3.2K, DHWOB=.8K 3/10/2019 3/10/2019 4.80 PROD1 DRILL DRLG P 9380', Started encountering Ankorite 9,380.0 9,705.0 12:54 17:42 stringers. ROP 200 FPH to 15' FPH back and forth. Better after 9540', drilled to called TD of 9705' 3/10/2019 3/10/2019 3.90 PRODt DRILL WPRT P Pump sweeps, wiper to 7550' (500' 9,705.0 78.0 17:42 21:36 into 3-1/2"), RBIH to EOB, pump sweeps, pull into 7" & circulate bottoms up, complete wiper to swab 3/10/2019 3/10/2019 1.50 PROD1 DRILL WPRT P RBIH 78.0 8,015.0 21:36 23:06 3/102019 3/10/2019 0.10 PRODt DRILL DLOG P Log K1 for -3' correction 8,015.0 8,037.0 23:06 23:12 3/102019 3/10/2019 0.10 PROD1 DRILL TRIP P Continue RIH 8,037.0 8,085.0 23:12 23:18 3/10/2019 3/112019 0.70 PROD1 DRILL DLOG P SBHP: Depth_bit= 8085', 8,085.0 8,085.0 23:18 00:00 TVD sensor= 5893.3', annular= 4003, EMW = 13.075 ppg Attempt bleeding down 3 times, well climbs to -13.08 ppg each time Confer with town, drop to 12.7 ppg (3909 psi on annular), well climbs back to 13.13 ppg overtime 3/112019 3/11/2019 1.50 PROD? DRILL CIRC T Confer wl town, begin circulating, 8,085.0 8,085.0 00:00 01:30 working KWF plan forward, working to find avalability of Micronized Barite & ammounts required for current lateral (mix recipe) 3/11/2019 3/11/2019 5.20 PROD1 DRILL CIRC T Identify Micronized Barite available in 8,085.0 8,085.0 01:30 06:42 Alpine, begin hot-shotting from Alpine to MI plant, offload 12.8 ppg K - Formate from rig in clean truck to MI plant to be weighted up to 13.35 ppg, continue circulating at window Page 14/19 Report Printed: 4/15/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth StartTme End Time Our (hr) Phew Op Corte Activity Code Time P -T -X Operation (WS) End Depth (ftKB) 3/11/2019 3/11/2019 0.70 PROD1 DRILL CIRC T Shutdown pump. Monitir well, 13.1 8,085.0 8,085.0 06:42 07:24 PPG EMW 3/11/2019 3/11/2019 7.00 FROM DRILL CIRC T Continue to circulate waiting on KWF 8,085.0 8,015.0 07:24 14:24 3/11/2019 3/11/2019 0.40 FROM DRILL DLOG P Log K1 for no correction 8,015.0 8,040.0 14:24 14:48 3/11/2019 3/11/2019 1.10 PROD1 DRILL TRIP P Trip in hole to condition hole, Get to 8,040.0 9,400.0 14:48 15:54 9408. Circulate 13.1 PPG Beaded liner running pill down CT. No setdowns or stacking. Hole in very good codition 3/11/2019 3/112019 0.70 PRODI DRILL TRIP P 13.1 beaded liner pill at bit. PUH 9,400.0 7,867.0 15:54 16:36 pumping pill 3/112019 3/112019 1.00 PROD1 DRILL TRIP P RBIH to pump 13.3 WARP 7,867.0 8,450.0 16:36 17:36 3/112019 3/11/2019 1.70 FROM DRILL TRIP P Trip out pumping 13.3 K -Formate 8,450.0 65.0 17:36 19:18 W/micronized barite, Paint EOP flags 8304, & 6900 3/11/2019 3/11/2019 1.30 FROM DRILL PULD P At surfae, Flow check well - Static. 65.0 0.0 19:18 20:36 Unslab injector. Lay down Drilling BHA #18, bit came out 1-2 & balled up 3/11/2019 3/11/2019 0.90 COMPZI CASING RURD P Rig up floor to run liner, PJSM to run 0.0 0.0 20:36 21:30 liner 3/11/2019 3/11/2019 1.70 COMPZI CASING PUTB P M/U BHA#19 A lateral completion with 0.0 1,061.0 21:30 23:12 non ported bullnose, 36 As slotted liner, and shorty deployment sleeve 3/11/2019 3/12/2019 0.80 COMPZI CASING PULD P PJSM, P/U coiltrak and M/U to 1,061.0 1,061.0 23:12 00:00 completion 3/12/2019 3/12/2019 0.70 COMPZ1 CASING PULD P Complete PU liner running tools BHA 1,061.0 1,061.0 00:00 00:42 #19 3/12/2019 3/12/2019 2.20 COMPZI CASING RUNL P RIH w/BHA #19,-3.9'correction to 1,061.0 9,414.0 00:42 02:54 window flag, PUW = 30K, continue RIH to 9414', PUW = 35K, RBIH, PU slack, bring up pumps, release off liner, PUW = 29K 3/12/2019 3/12/2019 3.10 COMPZI CASING DISP P Displace well to drilling fluid, pumping 9,414.0 8,088.0 02:54 06:00 fluid to the bit at 0.25 bpm, 14.5 ppg at window 3/12/2019 3/122019 2.30 COMPZI CASING TRIP P With drilling fluid at bit, begin 8,808.0 45.0 06:00 08:18 1 1 1 increasing rate, POOH 3/12/2019 3/12/2019 1.00 COMM CASING PULD P PUD BHA #19, WHIP = 1400 psi 45.0 0.0 08:18 09:18 3/12/2019 3/122019 1.10 COMPZI CASING PULD P PD BHA #20 Liner Run #2 (Anchored 0.0 72.0 09:18 10:24 Billet), slide in cart, check pack -offs, MU to coil, tag up, set counters 3/12/2019 3/12/2019 1.90 COMM CASING RUNL P RIH w/ BHA #20 72.0 8,010.0 10:24 12:18 3/12/2019 3/12/2019 0.20 COMPZI CASING DLOG P Log K1 for -5.5' correction 8,010.0 8,046.0 12:18 12:30 3112/2019 3/12/2019 0.50 COMPZI CASING RUNL P PUW = 24K, Gose EDC, continue RIH 6,046.0 8,052.0 12:30 13:00 w/ BHA#20, setdown 2K at 8102 twice (possible setting down on slips in bottom of window), orient 90° ROHS, again set down, PU & orient to 180°, get through. Arrive at set depth, PU slack, bring on pumps, shear off at 4900 psi, set down 4K, TOB -8340' 3/12/2019 3/12/2019 1.70 COMPZI CASING TRIP P POOH, PJSM 8,052.0 78.0 13:00 14:42 Page 15119 ReportPrinted: 4/15/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Time End Tans Dur(hr) Phase Op Code Aclivity Code Time P -T -X Operation (MB) End Depth(WEI) 3/12/2019 3/12/2019 1.00 COMPZt CASING PULD P PUD BHA #20 72.0 0.0 14:42 15:42 3/12/2019 3/12/2019 1.10 PROD3 STK PULD P PD BHA#21 AL2 KO/ Turn Assembly 0.0 78.0 15:42 16:48 (2.3" AKO motor, RS Hughes bit) 3/12/2019 3/12/2019 1.30 PRODS STK TRIP P RIH w/ BHA#21 78.0 8,005.0 16:48 18:06 3/12/2019 3/12/2019 0.20 PRODS STK DLOG P Tie into the Kt for a -5.5' correction. 8,005.0 8,035.0 18:06 18:18 3/12/2019 3/12/2019 0.20 PRODS STK TRIP P Close EDC 8,035.0 8,339.6 18:18 18:30 PU wt 25 k lbs, pass through the window, dean. " Tag TOB -8339.6'-WOB 2.4k 3/12/2019 3/12/2019 1.00 PRODS STK KOST P PU Wt 28 k lbs, Set rate and RBIH 8,339.6 8,340.5 18:30 19:30 CT 4913 psi, @ 1.83 bpm in, 1.83 bpm out, diff 614 psi. WH 660 psi, IA 30 psi, OA 358 psi, BHP 4073 psi holding 13.0 ppg EMW @ the window CT RIH Wt 9 k lbs, see motor work @ 8338.9' engage auto drill, WOB fell off to neg, bummed it up to see a little motor work and WOB, re-engaged auto drill at Vft per hr. 3/122019 3/12/2019 0.50 PROD3 STK KOST P Increase to 2 R/hr. 8,340.5 8,341.5 19:30 20:00 CT Wt 8.3 k lbs, WOB 0.06 k lbs. 3/12/2019 3/12/2019 0.25 PRODS STK KOST P Increase to 3 Mr. 8,341.5 8,342.5 20:00 20:15 CT Wt 8.3 k Itis, WOB 0.06 k lbs. 3/12/2019 3/12/2019 1.35 PRODS DRILL DRLG P Drill ahead up to 230 ft/hr, 8,342.5 8,464.0 20:15 21:36 Gamma Spike to 91 API, @ 8410'. Drilling dropped from 200 ft/hr to 100 R/hr over area then jumped back up. Resistivity pinched in as well. 8460' sudden drop in ROP to 8 ft/hr, resistivity suggests ankerite 3/12/2019 3/12/2019 0.20 PRODS DRILL WPRT P PU Wt 28k lbs, 8,464.0 8,322.0 21:36 21:48 Saw neg WOB to -1.2 k lbs, pulling up past 8410' Billet clean 3/122019 3/12/2019 0.10 PRODS DRILL WPRT P RBIH, Billet dry drift clean 8,322.0 8,464.0 21:48 21:54 Saw WOB spike to 1.5 k Ib @ 8410' 3/12/2019 3/12/2019 0.50 PRODS DRILL DRLG P CT 4731 psi @ 1.83 bpm in and 1.83 8,464.0 8,502.0 21:54 22:24 bpm out, diff 546 psi. WH 672 psi, IA 229 OA400 psi, BHP 4116 psi holding 13 ppg EMW at the window. WOB 2.4 it CT 4.8 k lbs, ROP 13 ft/hr 8,468' break out ROP up to 200 + ft/hr 3/12/2019 3/12/2019 1.30 PRODS DRILL DRLG P 8502', WOB stacked out, motor work 8,502.0 8,737.0 22:24 23:42 went away, PU 33k Itis - 8 k lbs over. Losses of 0.3 bpm. RBIH, tried to restart, had to PU again, 33k Itis, Cl VA. RBIH, New mud at the bit @ 8,528', @ surface 8620'- 23:05 3/12/2019 3/13/2019 0.30 PRODS DRILL DRLG P PU, 35 k lbs, - 100' wipe, RBIH, 8,737.0 8,766.0 23:42 00:00 1 1 Drill ahead to midnight depth of 8766' 3/13/2019 3/13/2019 1.90 PRODS DRILL TRIP P PU, 28 k lbs, billet and window clean. 8,766.0 66.0 00:00 01:54 1 Open EDC, continue OOH. 3/13/2019 3/13/2019 1.30 PROD3 DRILL PULD P Bump up, space out, PUD BHA # 21 66.0 0.0 01:54 0312 3/13/2019 3/13/2019 0.40 PROD3 DRILL BOPE P Vac down stack, Perform BOP 0.0 0.0 03:12 03:36 1 function test - good Page 16119 ReportPrinted: 4/15/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time log Start Depth Start Time End Time Dur (hr) Phase op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) 3/13/2019 3/13/2019 1.30 PRODS DRILL PULD P PD BHA# 22, check pack offs - good. 0.0 66.0 03:36 04:54 Bump up, set counters 3/13/2019 3/13/2019 1.50 PRODS DRILL TRIP P RIH, close EDC, shallow test agitator. 66.0 8,010.0 04:54 06:24 3/13/2019 3/13/2019 0.10 PRODS DRILL DLOG P Log Ki for -5' correction, PUW = 25K 8,010.0 8,042.0 06:24 06:30 3/13/2019 3/13/2019 0.50 PROD3 DRILL TRIP P Coninue RIH, see weight at 8153', 8,042.0 8,766.0 0630 07:00 1 1 1 continue through, RIW = 1 O 3/13/2019 3/13/2019 0.50 PRODS DRILL DRLG P Drilling FS = 1200 psi @ 1.9 bpm, 8,766.0 8,783.0 07:00 07:30 CWT =7.5K, WOB =1K, annular= 4113 psi, pump = 5444 psi, WHIP = 691 psi, diff less than FS, PUW = 25K, grab new parameters 3/1312019 3/13/2019 2.00 PRODS DRILL DRLG P Drilling FS = 1048 psi @ 1.9 bpm, 8,783.0 9,166.0 07:30 09:30 CWT =5.5K, WOB =1K, annular= 4142 psi, WHIP = 718 psi, pump = 5300 psi, pump sweeps 3/13/2019 3/13/2019 0.30 PRODS DRILL WPRT P Wiper up -hole, PUW =28K 9,166.0 8,375.0 09:30 09:48 3/13/2019 3113/2019 0.30 PRODS DRILL WPRT P RBIH, RIW =8K 8,375.0 9,166.0 09:48 10:06 3/13/2019 3113/2019 2.30 PROD3 DRILL DRLG P Drilling, FS = 1060 psi @ 1.9 bpm, 9,166.0 9,566.0 10:06 12:24 CWT = 4.8K, WOB = 1.51K, annular = 4169 psi, WHP = 723 psi, pump = 5466 psi, drilling wl negative CWT shortly after wiper, pump sweeps Drop ECD at window to 12.9 ppg (rate in = 1.9 bpm, rate out = 1.96 bpm), unble to maintain 1 -tor -1 returns, pinch back into 13.0 ppg 3/13/2019 3/13/2019 1.00 PRODS DRILL WPRT P Wiper to 7" casing, PUW = 27K, pump 9,566.0 8,010.0 12:24 13:24 additional sweeps time for EOB, (faulty pressure readings from DPS at -8280), clean past fault, slight negative pull through window 3113/2019 3/13/2019 0.10 PRODS DRILL DLOG P log K1 for +1' correction 8,010.0 8,036.0 13:24 13:30 311312019 3/13/2019 0.50 PRODS DRILL WPRT P RBIH, clean through window, stacked 8,036.0 9,566.0 13:30 14:00 5.51K weight at 8223', PU, clean through, clean past billet, clean past Vault at 8764', RIW = 5.31K 3/13/2019 3/13/2019 2.50 PRODS DRILL DRLG P Drilling, FS = 1060 psi @ 1.88 bpm, 9,566.0 9,894.0 14:00 16:30 CWT = 5K, WOB = 1.51K, annular = 4183 psi, WHIP = 577 psi, pump = 5393 psi, losing -0.03 bpm, ran into low ROP beginning at 9611', break out by 9644' 3/13/2019 3113/2019 1.10 PRODS DRILL DRLG P Drilling, CWT= -6.4K, WOB =1.6K, 9,894.0 10,009.0 16:30 17:36 annular = 4213 psi, WHIP = 559 psi, pump = 5521 psi, PUW = 30K from 9914' Pump 1 O 10 sweeps in anticipation of TD 3/13/2019 3/13/2019 0.60 PRODS DRILL WPRT P Discussion of extending TD, PU Wt 30 10,009.0 9,012.0 17:36 18:12 1 I I k Itis, pull wiper trip while deciding path forward, to drill or TD. 3/13/2019 3/13/2019 0.80 PRODS DRILL WPRT P RBIH to drill 9,012.0 10,009.0 18:12 19:00 1 Page 17119 Report Printed: 4/15/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Siert Depth Start Time End Time our (hr) phase Op Code Activity Code Time P -T -X Operation (aKB) End Capri (fll(6) 3/13/2019 3/13/2019 4.10 PRODS DRILL DRLG P CT 5012 psi @ 1.83 bm in and 1.83 10,009.0 10,260.0 19:00 23:06 bpm out. Diff 911 psi. Drilling, CWT = 0 to 4 K, WOB = 1 K, annular= 4219 psi, WHIP = 586 psi Drill ahead with diminishing resistivity until Geo's called TD @10260. 3/13/2019 3/14/2019 0.90 PRODS DRILL WPRT P PU Wt 35 k lbs, PUH chasing 10 x 10 10,260.0 8,368.0 23:06 00:00 1 1 TD sweeps up hole. 3/14/2019 3/14/2019 0.30 PROD3 DRILL WPRT P PU Wt 35 k lbs, PUH chasing 10 x 10 8,368.0 7,554.0 00:00 00:18 TD sweeps up hole. 3/14/2019 3/14/2019 0.50 PRODS DRILL WPRT P RBIH to EOB staging 10 x 10 sweep 7,554.0 8,840.0 00:18 00:48 to the bit. 3/142019 3/14/2019 1.00 PRODS DRILL WPRT P PUH chasing sweeps, Pull though 8,840.0 8,085.0 00:48 01:48 billet and window clean. Once in casing pump a bottoms up. 3/14/2019 3/14/2019 0.30 PRODS DRILL WPRT P Park @ 8085.05, 5893.5 TVD, trap 8,085.0 8,085.0 01:48 02:06 4037 psi - pressure slowly falling, bleed to 3992 psi observe pressure slabalize @ 3987 psi, bleed to 3960 psi, pressure increased and stabilized 2 3983 psi - 13.00 ppg 3/1412019 3114/2019 1.40 PRODS DRILL WPRT P Continue out of hole on swab wiper. 8,085.0 67.0 02:06 03:30 3/1412019 3114/2019 1.50 PROD3 DRILL TRIP P Bump up, set counters, RBIH 67.0 8,005.0 03:30 05:00 3/14/2019 3114/2019 0.20 PRODS DRILL DLOG P Tie int the K1 for -5.5' correction, by 8,005.0 8,037.0 05:00 05:12 pass HP screens. 3/1412019 3114/2019 0.20 PRODS DRILL DLOG P RIH and park @ 8084.99' CTMD / 8,037.0 8,076.0 05:12 05:24 589345' TVD. Trap 4007 psi - bleed to 3989 psi and observed pressure stabilize at 3989 psi - 13.0 ppg PU Wt 25 k Itis 311412019 3114/2019 1.00 PRODS DRILL TRIP P RIH, confine TD @ 10,261', PUW = 8,076.0 10,261.0 05:24 06:24 28K 311412019 3/14/2019 2.90 PRODS DRILL DISP P Lay in15 bbl LRP (build from drilling 10,261.0 8,370.0 06:24 09:18 fluid, followed by 5 bbl of 13.1 ppg K- Fonnate spacer), followed by 13.35 ppg WARP to surface, flow check 3/14/2019 3/14/2019 1.20 PRODS DRILL DISP P LD BHA #22, PJSM, check pipe for flat 8,370.0 0.0 09:18 10:30 -spots (good) 3/14/2019 3/1412019 3.70 COMPZ3 CASING PUTB P PU Liner (NP bullnose, 67 jnts slotted, 0.0 2,245.0 10:30 14:12 8jnts blank, pup, & sealbore deployment sleeve), loss rate minimal 3/14/2019 3/14/2019 0.60 COMPZ3 CASING PULD P PU liner running tools BHA#23, slide 2,245.0 2,305.0 14:12 14:48 in cart, MU to coil, tag up, set counters 3/142019 3/14/2019 3.20 COMPZ3 CASING RUNL P RIH w/ BHA#23, slow down to reduce 2,305.0 9,370.0 14:48 18:00 losses (-.2 bpm @ 60 fpm), 4.9' correction to window flag, PUW = 30K, RIH, stack weight at 9618, PUW = 40K, work pipe at -9618', dragging negative WOB, stack at 9606', PUH heavy, losing hole, continue dragging heavy, sete down 9533', continue to work pipe, 3/14/2019 3/14/2019 1.00 COMPZ3 CASING RUNL T Continue to work completion to 9,370.0 9,528.0 18:00 19:00 bottom. Snubbing up to -12 k Ibs, PU Wts 48-50 k lbs, Neg WOB up to -23k Itis, was -10 k lbs in open hole. Picking up from 9513' PU Wt 60 k lbs, 20 k Itis over normal pick up. 3/14/2019 3/142019 1.00 COMPZ3 CASING WAIT T Discuss plan forward with engineering 9,528.0 9,503.0 19:00 20:00 support. Page 18119 Report Printed: 4/1512019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operaacn (ftKB) End Depth h KB) 3/14/2019 3/14/2019 2.00 COMPZ3 CASING PULL T POOH with AL2 liner and running 9,503.0 2,293.0 20:00 22:00 assembly, repaint white window flag @ 8003.54' Pumped 26 bbls KW to replace pipe voidage - 26 ON of WARP remaining in pits. 3/14/2019 3/14/2019 0.70 COMPZ3 CASING PULL T LD AL2 liner running assembly - BHA 9,503.0 2,293.0 22:00 22:42 #23 3/14/2019 3/15/2019 1.30 COMPZ3 CASING PULL T LD 8 solid joints and 8 slotted joints 2,293.0 1,767.0 22:42 00:00 1 1 1 fill hole - 1 bbl 3/15/2019 3/15/2019 1.00 COMPZ3 CASING RUNL T LD 20 slotted joints, Fill hole 1 bbl 1,767.0 1,150.0 00:00 01:00 3/15/2019 3/15/2019 0.40 COMPZ3 CASING PUTB T PU 8 solid joints 1,150.0 1,402.0 0100 01:24 3/15/2019 3/15/2019 0.80 COMPZ3 CASING PULD T BHA#23, AL@ liner running assembly 1,150.0 1,447.0 01:24 02:12 - second attempt. 3/15/2019 3/15/2019 1.50 COMPZ3 CASING RUNL T RIH with AL2 completion, 85 ft/min 1,447.0 7,159.0 02:12 0342 running speed with minimal losses, 0.07 bpm. Tie into the window flag for 6.78' correction. 3/15/2019 3/15/2019 1.20 COMPZ3 CASING RUNL T Continue to RIH, PU Wt 28 k lbs, 7,159.0 9,402.8 0342 04:54 WOB -9.5 k lbs, RIH, drive by yellow TD flag for +3' correction. PU Wt 32 k lbs, unable to RBIH, PU wt 40 k lbs, RBIH to 9402'. Pump 1.34 bpm, CT 5608 psi, diff 1034 psi, PU Wt 23 k Ibs, 3/15/2019 3/15/2019 2.40 COMPZ3 CASING DISP P Park, reset counters, displace well 9,402.8 2,500.0 04:54 07:18 bore to seawater 3/15/2019 3/15/2019 1.80 COMPZ3 CASING FRZP P PJSM, freeze protect from—2500' to 2,500.0 50.0 07:18 09:06 1 1 1 surface 3/15/2019 3/15/2019 1.00 COMPZ3 CASING PULD P PUD BHA #24 (SITP = 1481 psi) 50.0 0.0 09:06 10:06 3/15/2019 3/15/2019 0.90 DEMOB WHDBOP CIRC P M/U nozzle stab on injector and flush 0.0 0.0 10:06 11:00 BOPE and rig surface lines 3/15/2019 3/15/2019 1.00 DEMOB WHDBOP RURD P Break off injector, vac stack, freeze 0.0 0.0 11:00 12:00 protect tree, secure injector, begin RD checklist 3/15/2019 3/15/2019 3.00 DEMOB WHDBOP NUND P Continue RD check list, off-load fluids 0.0 0.0 12:00 15:00 from rig, swap out Tango valves, ND BOP NES trucks arrive at 1400 hrs (to move shop & 1/2 -way house ahead of rig) " Rig Release: 3/15 @ 1500 hrs Page 19/19 Report Printed: 4/15/2019 ji S-11- PRoAcTiVE DIAGNOSTIC SERVICES, INC. WELL LOS TRANSMITTAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Caliper Report 2) Signed Print Name: ProActive Diagnostic Services, Inc. Attn: Diane Williams 130 West International Airport Road Suite C Anchorage, AK 99518 Pdsa n ch orae e(&me m o rvlog.com 17 -Feb -19 2G-06 1 Report / CD 104062 3039 2 REB EIVED Z 2 2019 AOGCC 50-029-21121-00 Date: = PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEOMEMORYLOG COM WEBSITE: www.mrMORYLOG.COM D:\AcNvesVv staTemplatailes\Templates\Distribwion\Tmnsmitte Sheets\ConocoPhillips_Transmicdccx X04002 30392 Memory Multi -Finger Caliper Company: ConocoPhillips Alaska, Inc. Log Date: February 17, 2019 Log No.: 20050 Run No.: 6 Pipe Description: 3.5 inch 9.3 Ib. L-80 EUE BIRD ABMOD Pipe Use: Tubing Pipe Description: 7 inch 26 Ib, J-55 BTC Pipe Use: Production Casing Log Results Summary Well: Field: State: API No. Top Log Interval: Bottom Log Interval: Top Log Interval: Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS: This caliper data is tied into the top of GLM 5 at 7,898 feet (Driller's Depth). 2G-06 Kuparuk Alaska 50-029-21121-00 Surface 8,046 Ft. (MD) 8,046 Ft. (MD) 8,125 Ft. (MD) This log was run to assess the condition of the tubing and casing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 3.5 inch tubing appears to range from good to poor condition, with a maximum recorded wall penetration of 41 % in a line of corrosion in joint 131 (4,190 ft). Recorded damage appears as a line of pits and line corrosion. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded. The caliper recordings indicate the 7 inch casing logged appears to range from fair to poor condition, with a hole recorded in joint 3 (8,110 ft) and joint 2 (8,068 ft), where the caliper also recorded 17% and 20% cross- sectional wall loss respectively. Recorded damage appears as isolated pitting and a line of pits. No other significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the casing logged. A 3-0 log plot of the caliper recordings across the casing logged is included in this report. This is the sixth time a PDS caliper has been run in this well, the third time the 3.5 inch tubing has been logged, and the first time the 7 inch casing has been logged. A comparison of the current and previous tog (June 6, 2011) of the 3.5 inch tubing indicates an increase in corrosive damage during the time between logs. A graph illustrating the difference in maximum recorded wall penetrations on a joint -by -joint basis between logs is included in this report. 3.5 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS: Line Corrosion 41 131 4,190 Ft. (MD) Line of Pits 39 52 1,661 Ft. (MD) Line of Pits 35 209 6,650 Ft. (MD) Line of Pits 35 250 8,045 Ft. (MD) Line Corrosion 35 168 5,373 Ft. (MD) 3.5 INCH TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 7%) are recorded. 3.5 INCH TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalvsis(a)memorvlog com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907j 659-2314 7 INCH CASING - MAXIMUM RECORDED WALL PENETRATIONS: Hole 100 3 8,110 Ft. (MD) Hole 100 2 8,068 Ft. (MD) Line of Pits 59 1 8,052 Ft. (MD) Isolated Pitting 26 4 8,122 Ft. (MD) 7 INCH CASING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Hole 20 2 8,068 Ft. (MD) Hole 17 3 8,110 Ft. (MD) No other significant areas of cross-sectional wall loss (> 13%) are recorded throughout the casing logged. 7 INCH CASING - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the casing logged. M. Domec C. Waldrop E. Zemba VrOACtiVe Diagnostic Services, Inc. / P.O. Box 1369, Stafforr_i, TX %7497 Phone: (281.) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalvsisgmemorvlog com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-231 PDS Multifinger Caliper 3D Log Plot Company: ConocoPhillips Alaska, Inc. Field : Kuparuk Well: 2G-06 Date : February 17, 2019 Description : Detail of Caliper Recordings Across Holes Recorded in 7Inch Casing Logged. Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (25.1' - 8,051.3') Well: 2G-06 Pipet 7. in (8,051.3'-8,125.0') Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: February 17, 2019 GLM 1 GLM 2 GLM 3 GLM 4 GLM 5- ■ Bottom of Survey = 4 1 25 50 75 100 v E 125 Z c 150 175 200 225 25Q Bottom of Survey = 4 �Maximum Recorded Penetration LAS Comparison To Previous Well: 2G-06 Survey Date: February 17, 2019 Field: Kuparuk Previous Date: June 06, 2011 Company: ConocoPhillips Alaska, Inc. Tool Type: UW MFC 24 Ext. No. 214040 LCountry: USA Tubing: 3.5" 9.3 Ib L-80 EUE 8RD ABMOD Overlay Difference Maximum Recorded Penetration (mils) 50 100 150 200 250 5. 6. 71 8' GlM 1 92 10. u 11: E � 12: Z 13: 14: 15. GLM 2 15'. 165 175 185 GLMI 196.3 206 216 GLM4 226 233 243 cu s 248.4 0 February 17, 2019 N June 06, 2011 Difference in Maximum Penetration (mils) -100 -50 0 50 100 8 15.3 25'— 35= 3= 453`- 55'—_— 65 3 75_ 85 92.3 102 a 3_ y 112= L E 122?=� � 132 -_ 142''- 152 ; - 1593x= 3- 69 179 189 1963_1 206 216,- 226 233 r 243 — — 248.4 ,--- „ -13 -6 0 6 13 Approximate Corrosion Rate (mpy) Corrosion Rate (mpy) Top 10Jts, Overall Average 8 3 Median 7 3 (Ps" s PDS Report Overview Body Region Analysis Well: 2G-06 Survey Date: February 17, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf L-80 FUE 8RD ABMOD Analyst: Waldrop Nom.OD Weight Grade &Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD ABMOD 2.992 in. 25 ft. 8,04ft Damage Profile (% wall) Penetration body 0 GLM 1 (9:30) CLM 2 (10:00) GLM 3 (1:00) GLM 4 (10:00) GLM 5 (10:00) Metal loss body 50 100 3ottom of Survey = 250.1 Penetration I% wall) 00 200- 150 150 100 50 0 0 to 20 to 40 to 20% 40% 850% over 850/ Number of Joints analyzed total = 266 104 161 1 0 Damage Configuration (body) 200 150 100 50 0 I I Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole Number of joints da ed(Lo al = 224) 28 0 196 0 0 Damage Profile (% wall) Penetration body 0 GLM 1 (9:30) CLM 2 (10:00) GLM 3 (1:00) GLM 4 (10:00) GLM 5 (10:00) Metal loss body 50 100 3ottom of Survey = 250.1 V's Well: 2G-06 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Sheet Survey Date: February 17, 2019 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf L-80 EUE BIRD ABMOD Tubing Nom. ID Body Wall Top Depth 2.992 in. 0.254 in. 25 ft Bottom Depth 8 046 ft. Joint Jt. Depth No. (Ft.) Pen. Upset (in.) Pen, Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 0.1 25 0 0.04 16 5 2.99 Pup Shallow Line of Pits. 1 29 0 0.04 14 5 2.93 1.1 61 0 0.03 11 4 2.96 Pu 1.2 71 0 0.03 11 5 3.02 Pu 2 73 0.04 0.03 13 2 2.97 3 104 0 0.03 1 13 2 2.95 4 136 0 0.03 1 13 2 2.97 5 167 0 0.04 15 3 2.95 Shallow Line of Pits. 6 198 0 0.04 1 14 5 2.96 7 229 0 0.03 1 11 6 2.98 8 261 0 0.04 16 2 2.95 Shallow Line of Pits. 9 292 0 0.04 14 4 2.94 10 323 0 0.04 14 5 2.95 11 355 0 0.04 15 4 2.96 Shallow Line of Pits. 12 386 0 0.03 11 2 2.96 13 418 0 0.04 16 7 2.96 Shallow Line of Pits. 14 449 0-1-6.04 15 3 -4 2.97 Shallow Line of Pits. 15 480 0 1 0.04 15 2.97 Shallow Pitting. 15.1 511 0 1 0.03 10 2 2.94 Pu 15.2 520 0 0 0 0 2.87 CAMCO DS NIPPLE 15.3 521 0 0.02 8 2 2.95 Pu 16 529 0 0.03 12 2 2.97 17 561 00.03 13 2 2.96 18 592 0 0.03 13 3 2.96 19 623 0 0.04 14 6 2.95 20 655 0 0.03 11 5 2.96 21 687 0 0.04 15 7 2.98 Shallow -Pitting. 22 719 0 0.03 12 4 2.95 23 750 0 0.03 11 3 2.95 24 781 0 0.03 12 4 2.96 25 813 0 0.03 12 2 2.96 26 844 0 0.04 14 6 2.95 27 875 0 0.03 13 2 2.95 28 907 0 0.04 15 6 2.96 Shallow Line of Pits. 29 939 0 0.03 11 4 2.96 30 970 0 0.03 13 5 2.96 31 1002 0 0.04 15 5 2.96 Shallow Pitting. 32 1033 0 0.03 12 4 2.96 33 1065 0 -0.05-L-1 8 2 2.95 Pitting 34 1096 0 0.04 14 4 2.94 35 1128 0.05 0.04 17 2 2.94 Pitti36 1159 0 0.04 14 2 2.95 37 1191 0 0.04 16 2 2.96 Lin38 1222 0.04 0.04 17 6 2.95 Lin39 1254 00.05 21 3 2.96 Pits.40 i-f 1284 0 0.06 23 3 2.94 Pits.411316 0 0.04 14 3 2.9542 1347 0 0.05 21 5 2.94 Pits.43 1378 0 0.05 18 4 2.94 Lin 44 141 0 0 0.08 32 4 2.95 Pits. Penetration Body Metal Loss Body Page 1 J�j Well: Field: Company: 2G-06 Kuparuk ConocoPhilIT s Alaska, Inc. PDS Report joint Tabulation Sheet Survey Date: February 17, 2019 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf Nom. ID Body Wall Top Depth L-80 FUE 8RD ABMOD Tubing 2.992 in. 0.254 in. 25 ft Bottom Depth 8,046 ft. Joint No. Jt. Depth Pen. (Ft.) Upset (in.j Pen. Body (in.) Pen. °7° Metal Loss % Min. I.D. (in.) Comments Damage Profile (%wall) 0 50 100 45 1441 0 0.07 26 3 2.95 Line of Pits. 46 1472 0 0.07 28 3 2.94 Line of Pits. 47 1504 0 0.08 30 3 2.95 Line of Pits. 48 1535 0.04 0.07 26 4 2.92 Line of Pits. It Deposits.. 49 1566 0.05 0.05 18 4 2.96 _ Shallow Pittine. 50 1598 0 0.07 28 2 Line of Pits. 51 1629 0 0.05 21 5 _2.95 2.92 _ Line of Pits. Lt. Deposits. 52 1660 0.08 0.10 39 4 2.94 Line of Pits. 53 1692 0 0.08 32 3 2.96 Line of Pits. 54 1723 0 0.04 15 2 2.93 Shallow Line of Pits. It. De osits. 55 1754 0 0.07 26 4 7195 Isolated Pitting. 56 1785 0 0.04 14 4 2.95 57 1817 0 0.06 22 4 2.95 Line of Pits. 58 1849 0 0.05 20 2 2.95 Line of Piis. 59 1880 0 0.07 26 3 2.94 Line of Pits. 60 1911 0 _ 0.04 15 3 2.92 _ Shallow Line of Pits._Lt. Deposits 61 1942 0 0.08 31 4 2.93 _ Line of Pits. 62 1973 0 0.05 20 3 2.94 Line of Pits. 63 _ 2004 0 0.08 30 6 2.95 Line of Pits. 64 2037 0 0.03 13 2 2.94 65 2068 0 0.05 18 5 2.95 Shallow Pittin . 66 2099 0 0.05 18- 4 2.93 Shallow Line of Pits. 67 2130 0 0.05 19 4 2.92 Shallow Line of Pits. Lt Dep -osis_ 68 2162 0 0.05 18 2 - - Shallow Line of Pits. 69 2193 0 0.05 18 3 2.95 Shallow Line of Pits. 70 2224 0 0.05 20 3 2.95 Line of Pits. 71 2256 0.04 0.04 15 4 2.93 Shallow D;16-- ittin 72 72 2287 0 0.06 23 3 2.94 Line of Pits. 73 2318 0 0.04 15 4 2.93 Shallow Pittin . 74 2349 0 0.05 21 4 2.93 Line of Pits. 75 2380 0 0.06 24 3 2.92 Line of Pits. Lt. De osits. 76 2412 _ 0 _0.04 t6 3 2.92 Shallow Pittine. Lt. Deposits, 77 2444 0 0.04 16 3 2.94 Shallow Line of Pits. 78 2475 0.04 005 19 3 2.94 _ Shallow Line of Pits. 79 2506 _0.04 0.03 72 4 2.94 _ 80 2537 0_.04 0.05 20 4 2.94 _ Line of Pits. 81 2568 0 0.05 19 2 2.95 Shallow Pittine 82 2600 0 0.04 16 5 2.94 Shallow Line of Pits. 83 2631 0.04 0.05 21 4 2.95 Line of Pits. 84 2663 _0.04 0.05 20 3 2.95 _ Line of Pits. 85 2694 0 0.05 20 5 2.91 Isolated Pittin Lt. Deposits. 86 2725 0 0.05 20 3 2.93 Line of Pits. Lt. De osits. 87 2756 0 0.06 23 4 2.92 Line Corrosion. Lt. Deposit-,. 88 2788 0.04 0.05 18 3 2.93 Shallow Line of Pits. 89 2819 0 0.05 21 4 2.93 Isolated Pittin Lt. De osits. 90 2851 0.04 0.05 21 4 2.94 Line of Pits. 91 2882 0 0.07 26 3 2.95 Line of Pits. 92 2913 0 0.04 16 3 2.95 Shallow Pittin . 92.1 2945 0 006 24 3 2.93 Pup Line of Pits, 92.2 2955 0 0 0 0 2.89 _ GLM 1 LATCH @ 9:30 Penetration Body Metal Loss Body Page 2 fp's Well: Field: Company: 2G-06 Kuparuk ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Sheet Survey Date: February 17, 2019 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf Nom, ID Body Wall Top Depth L-80 EUE 8RD ABMOD Tubing 2.992 in. 0254 in. 25 ft Bottom Depth 8,046 ft. Joint No. Jt. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. % Metal Loss °% Min. 1. D. (in.) Comments Damage Profile (% wall) 0 50 100 92.3 2964 0 0.07 29 4 2.91 Puo Line of Pits. Lt. De osits. 93 2974 0.04 0,05 19 3 2.95 Shallow Line of Pits. 943005 0 0.04 17 3 2.92 Shallow Line of Pits. Lt. Deposits. 95 3036 0 0.05 19 4 2.93 Shallow Line of Pits. Lt. Deposits.. 96 3067 0 0.03 13 3 294- 97 3098 0.04 0.06 25 4 2.93 Line Corrosion. Lt. Deposits. 98 3130 0 0.05 19 3 2.94 _ Shallow Line of Pits. 99 3161 0 0.03 13 2 2.94 100 3192 0 0.07 26 4 2.93 Line Corrosion. 101 3223 0.05 0.07 27 3 2.95 Line Corrosion. 102 3255 0.05 0.06 24 5 2.94 Line Corrosion. 103 3286 0.07 0.06 25 4 2.91 Line Corrosion. Lt. Deposits. 104 3317 0 0.05 20 4 2.93 Line of Pits. Lt. Deposits. 105 3348 0 0.05 20 4 2.92 Line of Pits. Lt. Deposits. 106 _ 3380 0.05 0.05 20 4 2.95 Line of Pits. 107 3411 0.05 0.09 34 5 2.92 Line Corrosion. Lt. De osits. 108 3442 0_05 0.06 25 3 2.94 Line Corrosion. 109 3473 0.04 0.08 30 3 2.93 Line Corrosion. 110 3504 0.06 0.06 24 5 2.94 Line Corrosion. 111 3536 0 0.06 24 4 2.92 Line of Pits. Lt. Deposits 112 3567 0.04 0.08 30 4 2.95 Line Corrosion. 113 3598 0 0.07 28 4 2.95 Line Corrosion. 114 3630 0 0.07 29 4 2.93 Line Corrosion. 115 3661 0 0.08 30 4 2.94 Line Corrosion. 116 3692 0 1 0.07 26 6 2.94 Line of Pits. 117 3723 0.05 0.07 28 4 2.95 Line Corrosion. 118 3755 0.06 0.08 30 4 1 2.94 Line Corrosion. 119 3786 0.05 0.08 31 4 1 2.94 Line of Pits. 120 381 7 0.06 0.07 26 4 2.93 Line Corrosion. 121 3848 0.05 0.07 28 4 1 2.94 Line Corrosion. 122 3880 0.06 0.08 31 4 2.94 Line Corrosion. 123 3911 0 0.07 26 4 2.93 Line Corrosion. 124 3942 0 0.05 19 3 2.92 Shallow Line of Pits. Lt. Deposits. 125 3973 0.05 0.08 32 3 2.91 Line Corrosion. LL Deposits. 126 1 4005 0.05 0.08 31 4 2.93 Line Corrosion. Lt. Deposits. 127 4037 0.06 0.07 28 3 2.-93 Line Corrosion. Lt. Deposits. 128 4068 0.05 0.09 34 4 2.92 Line Corrosion. Lt. Deposits, 129 4099 0 0.08 30 3 2.94 Line Corrosion. 130 4130 0.07 0.07 29 3 -2,9_3 Line Corrosion. Lt. Deposits. 131 4162 0.05 0.17 1 41 4 2.90 Line Corrosion Lt Deposits, 132 4193 0.07 0.07 1 27 4 2.92 Line of Pits. Lt. Deposits. 133 4224 0.04 0.09 34 5 j 2.92 Line Corrosion. LL Deposits. 134 4255 0 0.07 26 5 2.92 Line of Pits. Lt. Deposits. 135 4287 0 0.09 33 3 2.93 Line Corrosion. 136 4318 i0.05 0.06 22 3 2.94 Line of Pits. 137 4349 0.07 0.06 24 3 2.91 Line of Pits. Lt. De osits. 138 4380 0.05 0.06 23 3 2.93 Line Corrosion. Lt. Deposits. 139 4412 0.07 0.06 23 6 2.94 Line of Pits. 140 44430.04 0.06 25 5 2.91 Line of Pits Lt Deposits. 141 4474 0 0.06 22 4 2.94 Line of Pits. Penetration Body Metal Loss Body Page 3 Ji3-'s Well: 2G-06 Field: Kuparuk Conoc Company: ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Sheet Survey Date: February 17, 2019 Analyst: Waldrop Pipe L Description 3.5 in. 9.3 ppf L-80 EUE 8RD ABMOD Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in 25 ft 8,04 6 ft Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. 1. D. (in.) Comments Damage Profile (% wall) 0 50 100 142 4505 0,05-Q 06 22 4 2.91 Line Corrosion. Lt. Deposits. 143 4537 0 0.05 21 4 2.91 Line of Pits. Lt. Deposits 144 4568 0.06 0.07 27 3 2.92 Line Corrosion. Lt. Deposits. 145 4599 0.06? 0.06 24 2 2.91 Line of Pits. Lt. De osits. 146 4630 0.05 0.06 23 4 2.92 Line of Pits. Lt. De osits. 147 4662 0.06 0.07 29 2 2.94 Line Corrosion. 148 4693 0.07 0.08 30 4 2.90 Line Corrosion. Lt. Deposits. - e osits.149 149 4724 0.06 0.06 24 5 2.92 Line of Pits. Lt. Deposits. 150 4755 0.07 0.05 21 4 2.94 Line of Pits. 151 4787 0.04 0.05 19 2 2.94 Shallow Line of Pits. 152 4818 0.05 0.07 27 4 2.90 Line of Pits. Lt. Deposits. 153 4849 0 0.05 20 4 2.91 Line of Pits. Lt. Deposits. 154 4881 0 0.06 23 3 2.91 Line of Pits. Lt. De osits. 155 4912 0 0.07 27 4 2.93 Line of Pits. Lt. Deposits. 155.1 4943 0 0.04 17 5 2.93 Pu Shallow Pitting 155.2 4951 0 0 0 0 2_89 GLM 2 LATCH @ 10:00 155.3 4960 0.06 0.08 30 5 2.93 Pu Line Corrosion. Lt. Deposits. 156 4968 0 0.05 20 3 2.94 Line of Pits. 157 4999 0 0.06 24 6 2.94 Line of Pits. 158 5031 0.05 0.07 28 5 2.94 Line of Pits. 159 5062 0 0.07 26 4 2.95 Line of Pits. 1605093 0.05 0.06 22 5 _ 2.93 Line of Pits.. Lt. De osits. 161 5125 0 0.05 20 4 2.95 Line of Pits. 162 5156 0.05 0.05 20 4 Y. Line of Pits. Lt. De osits. 163 5187 0 0.05 18 4 2.91 Shallow Pittin . Lt. Deposits. 164 5218 0.05 0.07 29 4 2.94 Line Contusion. 165 5250 0 0.07 26 4 2.95 Line of Pits. 166 52810.05 0.07 26 4 2.95 Line of Pits. 167 5312 0.06 0.04 17 3 2.94 Shallow Line of Pits. 168 5343 1 0.06 0.09 35 5 2.95 Line Corrosion. 169 5375 1 0.05 0.05 18 4 2.94 Shallow Line of Pits. 170 5406 0 0.06 24 4 2.94 Line of Pits. 171 5437 0.05 0.06 24 4 2.91 Line of Pits. Lt. Deposit 172 5469 0.06 0.08 30 4 2.94 Line of Pits. 173 5500 0.07 0.06 24 4 2.91 Line of Pits. Lt. Deposits. 174 5531 0.04 0.06 25 4 2.95 Line of Pits. 175 5562 0 0.07 26 4 2.92 Line of Pits. Lt. Deposits. 176 5593 0.05 0.06 24 4 2.95 Line of Pits. 177 5625 0.05 0.06 22 4 2.93 Line of Pits. Lt. Deposits, 178 5656 0.06 0.06 24 3 2.95 Line of Pit 179 5687 0.04 0.05 21 4 2.91 Line of Pits. Lt. Deposits.. 180 5718 0.08 0.07 29 4 2.93 Line of Pits. Lt. Deposits. 181 5750 7=2 2.93 Line of Pits. Lt. De osits. 182 5781 2.93 Line of Pits. 183 5812 2.93 Line of Pits. Lt. Deposits 184 5841 2.95 Shallow Line of Pits. 185 58732.95 Line of Pits. 186 5903 2.94 Isolated Pittin 187 5935 2.94 Line of Pits. 188 5966 2.92 Line of Pits. Lt. Deposits. tPenetration Body Metal Loss Body Page 4 ii�,Si PDS Report Joint Tabulation Sheet Well: 2G-06 Survey Date: February 17, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhidips Alaska, Inc. Pipe Description Nom. ID Body Wall Top Depth 3.5 in. 9.3 ppf L-80 EUE 8RD ABMOD Tubing 2.992 in. 0.254 in. 25 ft Bottom Depth 8,046 ft. Joint No. JL Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % FMin. 1. D. (in.) Comments Damage Profile (% wall) 0 50 100 189 5997 0.07 0.05 20 1 3 1 2.92 Isolated Pittin Lt. De osits. 190 191 6029 6060 0.05 0.05 0.06 0.06 22 23 1 3 4 2.93 2.93 Line of Pits. Line of Pits. 192 6092 0 0.06 23 5 2.92 Line of Pits. Lt. De osits. 193 6123 0 0.04 14 4 2.95 194 6154 0 0.06 22 4 2.91 Line of Pits. Lt. Deposits. 195 6186 0.04 0.05 21 3 2.94 Line of Pits. 196 6217 0.04 0.06 24 4 2.95 Line of Pits. 196.1 6248 0 0.03 11 3 2.93 Pu 196.2 6256 0 0 0 0 2.91 GLM 3 LATCH @ 1:00 196.3 6265 0 1 0.04 14 3 2.94 Pu 197 6273 0 0.06 25 3 2.94 Line of Pits. 198 6305 0 0.05 19 2 2.94 Shallow Line of Pits. 199 6336 0.04 0.05 21 2 2.92 Line of Pits. Lt. Deposits. 200 6367 0.05 0.06 22 3 2.93 Line of Pits. Lt. Deposits. 201 6399 0.07 0.05 20 5 2.94 Line of Pits. 202 6430 0 0.05 21 3 2.96 Line of Pits. 203 6461 0 0.04 15 5 2.94 Shallow Pitfin . 204 6492 0 0.07 27 4 2.94 Line of Pits. 205 6523 0.06 0.06 23 4 2.94 Line of Pits. 206 6555 0.05 0.04 14 3 2.95 207 6586 0 0.08 30 4 2.93 Line of Pits. 208 6617 0.07 0.07 1 27 1 3 2.93 Line of Pits. Lt. Deposits. 209 6648 0.05 1 0.09 1 35 5 2.93 Line of Pits. Lt. Der)osits. 210 6680 0 1 0.06 23 4 2.94 Line of Pits. 211 6711 0 0.05 19 4 2.94 Shallow Line of Pits. 212 6742 0 0.06 24 4 2.94 Line of Pits. 213 6773 0 0.03 13 3 2.94 214 6805 0 0.06 22 2 2.95 Line of Pits. 215 6836 0 0.06 23 2 2.95 Line of Pits. 216 6867 0A4 0.05 19 2 2.94 Shallow Line of Pits. 217 6898 0 0.05 21 4 2.92 Line of Pits. Lt. Deposits. 218 6930 0 0.09 33 2 2.93 Line of Pits. 219 6961 0 0.05 21 3 2.94 Line of Pits. 220 6992 0 0.05 21 2 2.91 Line of Pits. Lt. Deposits 221 7023 _ 0 0,06 22 3 2.95 Line of Pits. 222 7055 0 0.05 20 2 2.94 Line of Pits. 223 7086 0 0.04 16 4 2.92 Shallow Line of Pits. Lt. Deposits. 224 711 7 0 0.04 17 3 2.94 Shallow Line of Pits. 225 7147 0 0.04 16 3 2.93 Shallow Pitting. Lt. De osits. 226 7178 0 0.06 22 3 2.93 Line of Pits. 227 7210 0.05 0.06 24 4 2.93 Isolated Pitting, Lt. Deposits. 227.1 7241 1 0 0.05 20 4 1 2.92 Pula Line of Pits. Lt. De osits. 227.2 7249 0 0 0 0 2.90 GLM 4 LATCH @ 10:00 227.3 7258 0 0.05 18 2 2.90 Pu Shallow Pitting. Lt. Deposits. 228 7266 0 0.07 26 3 2.93 Line of Pits. Lt. Deposits. 229 7297 0 0.05 21 3 2.91 Line of Pits. Lt. Deposits. 230 7329 0 0.05 20 2 2.93 Isolated Pittin Lt. Deposits. 231 7360 0.05 0.06 22 2 2.93 Line of Pits. Lt. Deposits. 232 7391 0.04 0.06 25 3 2.93 Line of Pits. Penetration Body Metal Loss Body Page 5 cli�s- Well: 2G-06 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Sheet Survey Date: February 17, 2019 Analyst: Waldrop Pipe Description Nom. ID Body Wall Top Depth 3.5 in. 9.3 ppf L-80 EUE 8RD ABMOD Tubing 2.992 in. 0.254 in. 25 It Bottom Depth 8,046 ft. Joint Jt. Depth No. (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. 1. D. (in.) Comments Damage Profile I% wall) 0 50 100 233 7422 0.04 0.04 17 3 2.94 Shallow Pittin . 234 7454 0 0.06 22 2. 2.94 Line of Pits. 235 7485 0 0.05 19 3 2.94 Shallow Line of Pits. 236 7516 0 0.05 18 2 2.92 Shallow Line of Pits. Lt. Deposits. 237 -T54 7 0 0.04 17 2 2.92 Shallow Pitting. Lt. Deposits. 238 7579 0 1 0.05 19 3 2.95 Shallow Line of Pits. 239 7610 0.04 0.05 20 3 2.95 Line of Pits. 240 7642 0 0.07 26 2 2.93 Line of Pits. Lt. De osits. 241 7673 0 0.05 20 4 2.91 Line of Pits. Lt. De osits. 242 7702 0 0.07 26 4 2.91 Line of Pits. Lt. Deposits, 243 7734 0 0.04 17 3 2.93 Shallow Line of Pits. Lt. Deposits. 244 7766 0 0.04 15 3 2.92 Shallow Pitting. Lt. Deposits. 245 7797 0 0.04 16 3 2.94 Shallow Line of Pits. 246 7827 0 0.04 17 3 2.93 Shallow Line of Pits. Lt. Deposits. 247 7859 0 0.05 19 2 2.94 Shallow Pitting. 247.1 7890 0 0.03 10 2 2.92 Pun Lt. De osits. 247.2 7898 0 0. 0 0 2.90 GLM 5 LATCH O 10:00 248 7907 0 0.06 23 6 2.93 Line of Pits. Lt. Deposits. 248.1 7947 0 0.07 29 4 2.91 Pu Line Corrosion. Lt. De osits. 248.2 7957 0 0 0 0 2.96 PER SEAL ASSEMBLY 248.3 7969 0 0 0 0 2.90 FHL PACKER 248.4 7978 0 0.03 1 13 6 2.92 Pup Lt Deposits. 249 7982 0 0.05 18 5 2.95 Shallow Line of Pits . 249.1 12 80 0 0 0 0 2.79 DS NIPPLE 250 8014 0.06 0.09 35 5 2.94 Line of Pits. 250.1 8046 1 0 0 0 0 2.96 END OFTUBING Penetration Body Metal Loss Body Page 6 PDS Report Cross Sections Well: 2G-06 Survey Date: Field: Kuparuk Tool Type: Company: ConocoPhillips Alaska, Inc. Tool Size: Country: USA No. of Fingers: Tubing: 3.5 in, 9.3 ppff L-80 EUE 8RD ABMOD Analyst: Cross Section for Joint 131 at depth 4,190.430 ft. Tool speed = 53 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 97% Tool deviation = 53° February 17, 2019 UW MFC 24 Ext. No. 214040 1.69 24 Finger = 3 Penetration= 0.105 in. Line Corrosion 0.11 in. = 41% Wall Penetration HIGH SIDE= UP PDS Report Cross Sections Well: 2G-06 Survey Date: February 17, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE BIRD ABMOD Analyst: Waldrop Cross Section for Joint 52 at depth 1,661.430 ft. Tool speed = 50 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 96% Tool deviation = 20' Finger = 22 Penetration = 0.100 in. Line Corrosion 0.10 in. = 39% Wall Penetration HIGH SIDE = UP 10 8 6 4 2 0 Penetration I% wall) 0 to 20 to 40 to over 20% 40% 85% 85°/ Number of joints analdot 1=4 0 1 1 2 Damage Configuration (body) 10 8 6 4 2 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole Number of' ints dam total = 4 1 0 1 0 2 Damage Profile (% wall) Penetration body Metal loss body 0 50 100 2 3 4 �L— Bottom of Survey = 4 PDS Report Overview .5 Body Region Analysis Well: 2G-06 Survey Date: February 17, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 7 in. 26 ppf J-55 BTC -Analyst: Waldrop ' Pipe NOm.OD Weight Grade &Thread Nom.ID Top Depth Bottom Depth 7 in. 26 ppf J-55 BTC _ 6.276 in. 8,051 ft. 8,125 ft. 10 8 6 4 2 0 Penetration I% wall) 0 to 20 to 40 to over 20% 40% 85% 85°/ Number of joints analdot 1=4 0 1 1 2 Damage Configuration (body) 10 8 6 4 2 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole Number of' ints dam total = 4 1 0 1 0 2 Damage Profile (% wall) Penetration body Metal loss body 0 50 100 2 3 4 �L— Bottom of Survey = 4 .S PDS Report Joint Tabulation Sheet Well: 2G-06 Survey Date: February 17, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description 7 in. 26 ppf J-55 BTC Casing Nom. ID Body Wall Top Depth 6.276 in. 0.362 in. 8,051 ft. Bottom Depth 8,125 ft. Joint No. Jt. Depth Pen. (Ft.) Upset (in.) Pen. Pen. Body % (in.) Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 1 8051 0.06 0.21 59 13 6.24 Line of Pits. 2 3 8056 0.10 8086 0.08 0.57 100 0.62 100 20 17 6.05 6.22 Hole! Lt. De osits. Hole! 4 —8114 0 0.10 26 3 6.21 Isolated Pitting, Lt. Deposits. Penetration Body Metal Loss Body Page 1 .s-, Well; Field: Company: Country: 2G-06 Kuparuk ConocoPhillips Alaska, Inc. USA PDS Report Cross Sections Survey Date: February 17, 2019 Tool Type: UW MFC 24 Ext. No. 214040 Tool Size: 1.69 No. of Fingers: 24 Cross Section for Joint 3 at depth 8,110.360 ft. Tool speed = 42 Nominal ID = 6.276 Nominal OD = 7 Remaining wall area = 87% Tool deviation = 39° Finger = 10 Penetration = 0.616 in. Hole 0.62 in. = 100% Wall Penetration HIGH SIDE = UP ii—�'s.. Well: 2G-06 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing: 7 in. 26 ppf J-55 BTC PDS Report Cross Sections Survey Date: February 17, 2019 Tool Type: UW MFC 24 Ext. No. 214040 Tool Size: 1.69 No. of Fingers: 24 Cross Section for Joint 2 at depth 8,067.710 ft. Tool speed = 43 Nominal ID= 6.276 Nominal OD = 7 Remaining wall area = 80% Tool deviation = 34° Finger = 22 Penetration = v.joo it. Hole 0.57 in.= 100% Wall Penetration HIGH SIDE= UP ji\J Field: Company: Country: 2G-06 Kuparuk ConocoPhillips Alaska, Inc. USA 7 in. 26 ppf J-55 BTC PDS Report Cross Sections Survey Date: February 17, 2019 Tool Type: UW MFC 24 Ext, No. 214040 Tool Size: 1.69 No. of Fingers: 24 Cross Section for Joint 2 at depth 8,067.700 ft. Tool speed = 43 Nominal ID = 6276 Nominal OD = 7 Remaining wall area = 80% Tool deviation = 36° Finger= 22 Penetration = Hole 20% Cross -Sectional Wail Loss HIGH SIDE = UP ji.S 2G-06 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing: 7 in. 26ppf J-55 BTC PDS Report Cross Sections Survey Date: February 17, 2019 Tool Type: UW MFC 24 Ext. No. 214040 Tool Size: 1.69 No. of Fingers: 24 Cross Section for Joint 3 at depth 8,1 10.1 10 ft. Tool speed = 42 Nominal ID = 6.276 Nominal OD = 7 Remaining wall area = 83% Tool deviation = 36° Finger= 10 Penetration= 0.616 in. Hole 17% Cross -Sectional Wall Loss HIGH SIDE = UP THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Kai Starck CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2G-06 Permit to Drill Number: 184-082 Sundry Number: 319-065 Dear Mr. Starck: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for the 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, Daniel T. Seamount, Jr. Commissioner DATED thisl� February, 2019. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAc 95 91911 FEB 11 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑Z Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: 2. Operator Name: 4. Current Well Class: --Whipstock_❑✓ 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development Q Stratigraphic El Service El, 184-082 3. Address: 6. API Number: PO Box 100360, Anchorage AK 99510 50-029-21121-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2G-06 r Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25656 Kuparuk River Field / Kuparuk River Oil Pool it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8485' 6253' 8368' 6158' 4320 N/A 8136' Casing Length Size MD TVD Burst Collapse Structural Conductor 72' 16" 110' 110' Surface 3097' 9-5/8" 3134' 2774' Intermediate Production 8413' 7" 8449' 6224' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8188'- 8198', 8216'- 8246' 1 6013'- 6021', 6035'- 6060' 3-1/2" L-80 8044' Packers and SSSV Type: Baker FHL Retrievable Packer Packers and SSSV MD (ft) and TVD (ft): 7968' MD / 5841' TVD 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development E] Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 2/20/2019 ✓ Commencing Operations: OIL ❑ WIND ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Kai Starck Contact Name: Keith Herring Authorized Title: CTD !rector Contact Email: Keith. E. Herrin CO .Com Contact Phone: 263-4321 Authorized Signature: -" Date: _ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Er Mechanical Integrity Test ❑ Location Clearance ❑ Other: BUP ?f5 t to 9800�s r� 4-vtnj�lar P�ry«,fz. test zSoo VsrJ �/¢rrna-t--z P1v% plaervr�ra�f a�prov�d Post Initial Injection MIT Req'd? Yes ❑ No ✓ nf✓ ,2.0 /¢-/YC 2,S //Z ��� �Er -�/ Spacing Exception Required? Yes E] No [2 Subsequent Form Required: l C — 46 2 y APPROVED BY Z/1 /� p Approved b � COMMISSIONER THE COMMISSION Date: / {! Ey �p� f l 9 a� f,1 -n \ / ^ ^�. /'� I \' �p��nA� �lp� 000 Submit Form and U o 10-403 Revised 4/2017 Approved applic�`ti/Q1'`r rq`fq/r 2'v�n f i11i Wb�ppcOvag.Q/ i 4 Ltj1�4ttachmenls in Duplicate n�/oj/y ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 08, 2018 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner ConocoPhillips Alaska, Inc. hereby submits sundry application to set a mechanical whipstock and cement squeeze the A -sand perforations in the KRU well 2G-06 (PTD# 184-082). ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill four laterals out of the KRU 2G-06 (PTD #184-082) using the coiled tubing drilling rig, Nabors CDR3-AC. Pre -rig operations are scheduled to begin in late February with CTD operations following in early March 2019. The objective will be to drill four laterals, KRU 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 targeting the Kuparuk A -sand interval. ConocoPhillips requests a variance to the requirements of 20 AAC 25.112(c) for the alternate plugging method to isolate the 2G-06 A -sand perforations utilizing an A -sand cement squeeze via service coil. To account for geologic uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being , limited to 500' from the original point. Attached to the sundry application are the following documents: - 10-403 Sundry Application for KRU 2G-06 - Operations Summary in support of the 10-403 sundry application - Current Wellbore Schematic - Proposed CTD Schematic Attached to the permit to drill applications are the following documents: - Permit to Drill Application Forms (10-401) for 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 - Detailed Summary of Operations - Directional Plans for 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 - Current Wellbore Schematic - Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, Keith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska KRU 213-06 (PTD #184-082) CTD Summary for Sundry Summary of Operations: A high expansion wedge, whipstock, was set in KRU well 2G-06 (PTD #184-082) at 8134' MD and a window was cut in the 7" casing. KRU lateral well 2G -06L1 PB1 (PTD #218-112) was drilled to 8330' MD. Multiple attempts to drill the build section of the hole were attempted and multiple fill cleanouts conducted. Due to poor hole conditions the wellbore was deemed to be a plug back and the decision was made to utilize a backup kick off point. A backup high expansion wedge was set up hole at 8095' MD and a backup window was attempted to be cut in the 7" casing. When tripping in hole with the drilling BHA to make another attempt at drilling KRU 2G - 06L1 (PTD #218-112) the high expansion wedge was found to have slid downhole. CDR3-AC rigged down and moved off 2G-06 to allow ConocoPhillips time to develop a plan forward. ConocoPhillips plans to have E -line set a high expansion wedge in the 7" casing at the planned kick off point at 8095' MD. Service coil will cement the high expansion wedge in the 7" casing and squeeze cement the A - sand perforations. T Cp.'cv/. 0j/ too has V(,99°kl�Tv < 100 A01" CTD Drill and Complete 2G-06 Laterals:�F 4Piney d 94 or, h Pre -CTD Work T4t�5 (1 / /Ir, pe rA� recover 1. RU Slickline: Obtain caliper of 7" casing. 2. RU E -line: Set high expasion wedge in 7" casing. 3. RU Service Coil: Cement high expansion wedge and squeeze cement the A -sand perforations. 4. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2G -06A Sidetrack a. Mill 2.80" window at 8095' MD. b. Drill 3" bi-center lateral to TD of 9750' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 8400' MD. 3. 2G-06AL1 Lateral a. Kick off the aluminum billet at 8400' MD. b. Drill 3" bi-center lateral to TD of 9750' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 8300' MD. 4. 2G-06AL2 Lateral a. Kickoff the aluminum billet at 8300' MD. b. Drill 3" bi-center lateral to TD of 9900' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 8400' MD. 5. 2G-06AL2-01 Lateral a. Kickoff the aluminum billet at 8400' MD. b. Drill 3" bi-center lateral to TD of 9900' MD. c. Run 2-3/8" slotted/blank liner from TD up into the 3-1/2" tubing at 8006' MD. 6. Freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post -Rig Work 1. Return to production Page 1 of 1 2/8/2019 KUP PROD WELLNAME 2G-06 WELLBORE 213-06 CaioeoPFnllipS WellAttnbutesMaxAngle&MD TD Ala9ka.Ir1D. ficltl Name WNIb412N'a PROD Status II'1 MDUCKID pcI BIm Dome) KUPARUK RIVER UNIT 500282112100 PROD x4.60 4,00000 8.485.0 CPTmenl MialWml Dame Mnob4an EndpMe KM.(ry Ry Release Me SSSV: NIPPLE 110 1211&2017 i-segi 7/142010 36.00 6118/1984 2ca.2n hB2s:m AMLast Tag Vam=tlevemsixenteal Aami Deplxmgild End Diane w¢Blpre IaslMm By ag: RKB 8,031.0262019 2G-06 zembaej xnuceR xo I-5C-E Rev Reason Annotation End Dale welMne Up, ad By eason: Pulled Rpckscreen B Updated To, Depth 2Ifi12019 2G-0fi arn.j Casing Strings Des=nptn nn un) IDLAN Tmp`Ke) semeptnfixe) SH popm lrvpL.. widen P_G,eae Top rme.a UCTOR 16 15 Re 38.0 110.0 110.0 6250 H-40 Weldetl "eargeion ODIin) ID(nl harmo Bl Set DeplM1 plNBI Bel DeplM1 pV01._ WULen IL. GrYe iop TM1reY ACE 95/8 9.21 37.2 3,133.9 2.)J3J 30.00 J55 BTC Desmlptlan ODpn)ID(Inl TOPMKB) Sa Dia1hpl BI BM DegM1 (TVOL.. w4Len g... Grant Top Tn..a UCTION ] 6.28 35.9 8,449.1 6.223.8 26.00 J-55 BTC coxpucTOR:2e:o.poD ng Strings pea=ap(wn Sl pinKel s¢t poptn lrt..¢t Oeln(1Vp1(_.wpaml i¢ Top Connxxon G WO 31/2 299 30.15,841.4 9.30 L-00 EUESrdADMOD ImPLE:5t6] Completion Details Top(rv01 Tap Incl Nominal Top IMNB) (ryKB ('I Item pet Com Cam) 30.1 30,1 0.09 HANGER Vetw Gray Gen II TUBING HANGER 2.938 524.] 524.6 1.16 NIPPLE 3.5'Camw'DS' Nippletai profile 2875 GAs OFT; 2.w1.5 ],956.6 SIGHS renes PB `BH Seal Assembly(eheared) wl 2 spare Out STABBED INTO 2. PACKER ASSEMBLY Tu,DeKripman String aux. .It. (m) TUBING PACKER 3112 2.99 ASSY Top(M1KB1 7,968.3 BM Dope M.., 8.043.6 OepiM1(1VDI I... 5.899.1 VImllO.h1 aw Gram¢ L-80 Tap Co ion 8RD END Completion Details SURFACE: w.. tags- Top lrv0) Top lint Nominal Top gi (nKB) A nem Des Com 10 ;968.3 5,840] 39.50 PACKER FHL Packer 3�p3p eA11.2 58]3.8 39.03 NIPPLE 2SlS DS Nipple 2813 GAe OF¶ 4s4e.4 Other in Hole QAgreline retrievable plugs, valves, pumps, fish, etc.) Top(ND) Noln=I TopinKB ItIKB) 1' des Com Run Data 10 (int 5.9414 31.98 WindpwinI HEW Wb pled B fell d. hole, leaving window 1021201 2800 casing exposed in )' casing 8 GASOFT:62ses 8,1320 5,968.7 37.54 NS High Expansion NS High Expansion Wedge WS 1021/201 8 0.000 Wedge WS Note: WE slid dpwTNwle. likely lop at 8136' MD (1023/18) ,136.0 5,91.8 3].49 NS Hgh NS High Expansion Wedge WS 1011 fi 0.000 Eganvon g cAs UFT:).2wo Wei WS 8.158.0 5,989.3 31.21 FISH LOWER PACKER FROM OLD COMPLETION.PX 1/6/2008 0.000 PLUG, 6 REST OF TUBING DOWN TO WIRELINE RE- ENTRY GUIDE IS IN FILL. TAGGED HARD MUD @ 8158 SLM. GAa LlF ,791'2 Perf.WI.n5&Slots aen O3s ToplaKBl Blm (11KB) Top(NO) (ttNB) Blm fiVp) plKa) Link. pone Data IsM1OaM ) Type Com Pay', ),6Y.fi 81188.0 ,198.0 6,013.3 6,021.3 A5, 2G-06 9/26/1988 4.0 IPERF 90 deg. Phasing; 4' ScM1lumbergu Casi 8,216.0 0.296.0 6,p35.J 8.059.9".21 &24/1988 4,U111- F 90 deg. Pbesing;4- FACKER:Tesa'3 � Schlumberger0851 Mandrel Inserts sm MI NIPPLE:8011.2 an Rp(IVD) Valw IeW Pansl]¢ iRO Run N Top(RKB) 1F1KB1 Make M.N Op Yry Type Type Ilnl IpSB Run Oam Com 1m) 2,951.5 ,855.4 Camw MMG 112 G LIFT GLV RK 1 0.180 1, 24. 1812018 9:30 2 4,905.5 3,851,9 Camw MMG 112 GAS LIFT LV RK 0.18 1,220.0 282010 1 3 .3 4,646.2 amcp MM 112 GAS LIFT GLV RK 0.188 1,21].0 2182 1 1:00 4 ],24fi0 5,3W.fi Cameo MMG 112 GA LD -1 GLV RK 0.188 1, 2/82018 9:30 5 )8982 5]6fi.6 Camw MMG I T2 GASLIFT OV RK 0.2511 0.0 222010 10'.30 Notes: General & Safety N51Fpn Esperipmweagews: B,IAO End Date Mmt4un 112,2000 NOTE: VJORKOVER 13/10200] NOTE "MIT TESTING WILL HAVE TO USE D6 NIPPLEd8008"' xSNgn Emamweate w5: 12/1 02007 NOTE'. WORKOVER a lae.p )22009 NOTE:5005' =TIGHT SPOT, UNABLETOWORK26'GAUGE RING PASTN272009 722D9 NOTE: View Sdiemaliew/Alaska Scommamic9.0 FI6K', 9.1580 IPERF'. a.1wp8,1580� IPERF. Lynn Se,g- PRODUCTION. M.SaahRl 2G-06 Proposed CTD Schematic 16" 62# H40 shoe CC 110' MD 9-5/8" 36# J-55 shoe @ 3134' MD High Expansion Wedge @ 8095' MD, 38.01, 49.06 Partial Window @ 8107'- 8109' MD Failed High Expansion Wedge Last Tag @ 8136' MD High Expansion Wedge @ 8134' MD Lower Packer from Old Completion @ 8158' MD A5 -sand perfs squeezed 8188'- 8198' MD A4 -sand perfs squeezed 8216' - 8246' MD 7" 26# J-55 shoe @ 8449' MD 3-1/2" 9.3# L-80 ELIE 8rd Tubing to surface 3-1/2" DS landing nipple @ 525' MD (2.875" min ID) 3-1/2" Carrico MMG gas lift mandrel @ 2952', 4946', 6250', 7246', and 7898' MD Baker 3-1/2" PBR @ 7957' MD (2.98" ID) Baker FHL packer @ 7968' MD (3.03" ID) 3-1/2" DS landing nipple @ 8011' MD (2.813" min ID) 3-1/2" tubing tail @ 8043.6' MD (8048' PDC) 2G-O6L1P61 TD @ 8,330' MD Washout, Cavings, and Packoffs @ —8170' MD 2G-06AL2-01 wp03 TD @ 9,900' MD Liner top at 8006' MD 2G-06AL2 wp03 1 TD @ 9,900' MD Uner Billet @ 8,400' MD 2G-06AL1 wp05 TD @ 9,750' MD Liner Billet @ 8,300' MD 2G-06Awp06 TD @ 9,750' MD Liner Billet @ 8,400' MD vOF' 771 • • \ s THE STATE Alaska Oil and Gas �w�"!•'�'���.►'�9� Of® T ® K ® Conservation Commission 333 West Seventh Avenue 1GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 11 "ITh„ Main: 907.279.1433 ALAS*14- Fax: 907.276.7542 www.aogcc.alaska.gov James Ohlinger Staff CTD Engineer %MANED JAN 0 5 2013 ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2G-06 Permit to Drill Number: 184-082 Sundry Number: 317-529 Dear Mr. Ohlinger: 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, Hollis S. French Chair DATED this - day of December, 2017. RBDNIS N17 • 0 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 0 8 2017 APPLICATION FOR SUNDRY APPROVALS ors 11-141- 117 20 AAC 25.280 Q A l^) (/�, 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 21 ' s 0,utdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill [f Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: _Cement Squeeze_❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development 0, 184-082 ' 3.Address: 6.API Number: Stratigraphic El ❑ PO Box 100360,Anchorage AK 99510 50-029-21121 -Op—pct. 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A_/ KRU 2G-06 Will planned perforations require a spacing exception? Yes ❑ No TO 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025656 Kuparuk River Field/Kuparuk Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8485 6249 8449 6227 4409 N/A 8158 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 16 110 110 1640 630 Surface 3134 9-5/8 3134 2774 3520 2020 Intermediate Production 8449 7 8449 6227 4980 4330 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8188-8198; 8216-8246 • 6013-6021; 6036-6060 3-1/2 L-80 8043 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker FHL Retrievable Packer 7968'MD,5841'TVD ` 12.Attachments: Proposal Summary ❑I Wellbore schematic ❑� 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 11/10/2017 ❑ WINJ ❑ WDSPL ❑ Suspended ❑ Commencing Operations: OIL ,, 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: Mike Callahan Authorized Title: Staff CTD Engineer Contact Email: mike.callahanc1 conocophiIIips.com Contact Phone: 263-4180 Authorized Signature: n Date: ///g1 /7 COMMISSIO USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 n . 5)-q Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: Bop i-e-5t ft, 5000 P 51 i9 N v7 v6�r Irl ✓l vt l f e "to 75-6° p 5' xlrt.rr7atc ptcry' /0/4ce-nom-r,-t1" ° ol'✓ rot�e" Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No IZ Subsequent Form Required: RBDNIS t l__ E`C 13 5 21317 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 1 L 14 liq olx �� Pi'1 u f gf 0- ,„/_�7 I/7-1__ /1/zo/i7-- Y� OiR4tG1ntAeE.,approvai. Submit Form and Form 10-403 Revised 4/2017 Approved application is valid Attachments in Duplicate I ✓ • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 November 7, 2017 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications to abandon the KRU 2G-06 by cementing up the perforations in order to set up to for CTD operations to drill a quad-lateral out of the KRU 2G-06 using the coiled tubing drilling rig, Nabors CDR3-AC. A sundry application is attached to plug the 2G-06 (184-082) perfs to allow these laterals to be drilled. As detailed in the attachments, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A-sand perfs in 2G-06. A permit to drill for the four proposed CTD laterals will be submitted at a later date. Attached to this application are the following documents: — 10-403 Sundry Application to Abandon KRU 2G-06 (184-082) — Operations Summary in support of the 10-403 sundry application — Proposed CTD Schematic — Current Well Bore Schematic If you have any questions or require additional information, please contact me at 907-263-4180. Sincerely, id2�'Z Mike Callahan ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • KRU 2G-06 CTD Summary for Plugging Sundry (10-403) Summary of Operations: KRU well 2G-06 is a Kuparuk A Sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize four laterals to target the A4 sand to the north and south of 2G-06. Prior to CTD operations, E-Line will punch 2' of holes in the 3-1/2" tubing tail at 8000' MD. The existing perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place 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 perforations in this manner. Following the cement squeeze Nabors CDR3-AC will drill a pilot hole to 8155' MD and set a mechanical whip-stock in the 2.80" pilot hole to kick off at 8134' MD. All laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the 3- 1/2" tubing tail. Using the maximum formation pressure in the area of 5017 psi in 2B-05, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 4409 psi. CTD Drill and Complete 2G-06 Laterals: November 2017 Pre-CTD Work 1. RU Slickline: Obtain SBHP, dummy off gas lift mandrels, and pressure test. 2. RU E-line: Punch 2' of holes in the 3'/2" tubing tail at 8000' MD. 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Cement squeeze the A-sand perforations up to the holes in the tubing tail. 5. RU Slick-line: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR3-AC and set BPV. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2G-06A Sidetrack (A4 sand - North) a. Drill 2.80" high-side pilot hole through cement to 8155' MD b. Caliper pilot hole c. Set top of whip-stock at 8134' MD d. Mill 2.80" window at 8134' MD. e. Drill 3" bi-center lateral to TD of 9750' MD. f. Run 2%" slotted liner with an aluminum billet from TD up to 8400' MD. 3. 2G-06AL1 Lateral (A4 sand - North) a. Kick off of the aluminum billet at 8400' MD. b. Drill 3" bi-center lateral to TD of 9750' MD. c. Run 2%" slotted liner with aluminum billet from TD up to 8450' MD. 4. 2G-06AL2 Lateral (A4 sand - South) a. Kick off of the aluminum billet at 8450' MD. /lecessu Propose/ (wrerQls 14.,7/ Kick o+ M K("41 CQ•11 No re5Nve5 (ev ew iy Page 1 of 2 gni 001/1/ 'Nd vi'74 11°11"d l,hr/x hq4. r'nty C:10) 10)th�i ;6// C.no� r/240 CV/l�G1T/ rn 1/ /2017 w(( he cgbfe o� Pradv,,6 ,� be, t by. the €703h4— ti of f a r17w17 b. Drill 3"center lateral to TD of 9900' MD. 410 c. Run 2%" slotted liner with aluminum billet from TD up to 8770' MD. 5. 2G-06AL1 Lateral (A4 sand - South) a. Kick off of the aluminum billet at 8770' MD. b. Drill 3" bi-center lateral to TD of 9900' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 8125' MD. 6. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD3-AC. Post-Rig Work 1. Pull BPV 2. Obtain SBHP 3. Install gas lift design 4. Return to production Page 2 of 2 11/8/2017 • • 2G-06 Proposed CTD Schematic ncEntod 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 3-1/2"DS landing nipple @ 525'MD(2.875"min ID) 16"62#H-40 shoe @ 110'MD 3-1/2"Camco MMG gas lift mandrel @ 295Z,4946',6250', 7246',and 7898'MD 9-5/8"36#J-55 shoe @3134'MD --.001111 Baker 3-1/2"PBR @ 7957'MD(2.98"ID) Baker FHL packer @ 7968MD(3.03"ID) 3-1/2"DS landing nipple @ 8011'MD(2.813"min ID) 3-1/2"tubing tail @ 8043.6'MD (8048'PDC) J,== 2G-06AL2-01 wp03 TD @ 9,900'MD Liner top at 8043'MD 20-06AL2 wp03 A5-sand perfs [ot TO 9,900'MD 8188'-8198'MD IN\ "7- 78,11.t@ 8,770 MD A4-sand perfs 8216'-8246'MD ILat#3 2G-06AL1 705 7:4W Irri Liner e gxr g I Lat#1 2G-06A wp03 TD @ 9,750'MD Liner Billet 8,400'MD 7"26#J-55 shoe @ 8449'MD KUP PROD • 2G-06 • ConocoPhillips i Weil Attributes Max Angle&MD TO Alaska IncIi' . Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) u,t. lhpz - 500292112100 KUPARUK RIVER UNIT PROD 54.60 4,000.00 8,485.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date' 2G-06,52420149'29'17 AM SSSV:NIPPLE 80 12/30/2012 Last WO: 7/14/2010 36.00 6/18/1984 Vertical schemata(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,132.0 2/8/2014 Rev Reason:Mandrel Orientations lehallf 5/24/2014 HANGER;30.1 IVA Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len-II..Grade Top Thread ae116aunlasi CONDUCTOR 16 15.062 38.0 110.0 110.0 62.58 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 11 SURFACE 95/8 9210 37.2 3,133.9 2,773.7 36.00 J-55 BTC � Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 35.9 8,449.1 6,223.8 26.00 1-55 BTC Tubing Strings Tubing Description String Mn...ID lin) Top(ftKB) Set Depth Ift...Set Depth(ND)(..,Wt(Ib/ft) Grade Top Connection TUBING WO 31/2 2.992 30.1 7,969.3 5,841.4 9.30 L-80 EUE8rdABMOD I Completion Details Nominal ID ,AAI CONDUCTOR;38.0-110.0Top(ftKB) Top(ND)(ftKB) Top Incl(I) Item Des Com (in) 30.1 30.1 0.09 HANGER Vetco/Gray Gen II TUBING HANGER 2.938 524.7 524.6 1.18 NIPPLE 3.5"Camco"DS"Nipple w/2.875 profile 2.875 NIPPLE;524.7 MP 7,956.6 5,831.6 39.63 PBR PBR Seal Assembly(sheared)w/2'space out STABBED 2.980 a. lit INTO PACKER ASSEMBLY Tubing Description String Ma...ID(in) -Top(ftKB) -Set Depth(ft..,Set Depth(TOD)(...Wt(lb/ft) Grade Top Connection TUBING Packer Assy 31/2 2.992 7,968.3 8,043.6 5,899.1 9.30 L-80 8RD EUE Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(1) Item Des Com (in) GAS LIFT;2,951.5 7,968.3 5,840.7 39.50 PACKER FHL Packer 3.030 • 8,011.2 5,873.8 39.03 NIPPLE 2.813"DS Nipple 2.813 Other in Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) _ Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 8,158.0 5,989.3 3721 FISH LOWER PACKER FROM OLD COMPLETION,PXX 1/6/2008 0.000 PLUG,8 REST OF TUBING DOWN TO WIRELINE RE-ENTRY GUIDE IS IN FILL.TAGGED HARD • MUD @ 8158 SLM. SURFACE;372-3.1339- Perforations&Slots shot Den Top(ND) Btm(TVD) (shotstf GAS LIFT;4,945.4 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,188.0 8,198.0 6,013.3 6,021.3 A-5,2G-06 9/24/1988 4.0 IPERF 90 deg.Phasing;4" Schlumberger Casi 8,216.0 8,246.0 6,035.7 6,059.9 A-4,2G-06 9/240988 4.0 IPERF 90 deg.Phasing;4" Schlumberger Casi Mandrel Inserts GAS LIFT;6,250.3 'ti St ili n i N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ORB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1� 2,951.5 2,655.4 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/17/2013 9:00 2 4,945.5 3,851.9 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,265.0 7/19/2010 10:30 3 6,250.3 4,646.2 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,256.0 7/18/2010 1:00 GAS LIFT;7,246.0 ® 4 7,246.0 5,310.6 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,245.0 708/2010 9:30 • y 5 7,898.2 5,786.8 Camco MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 6/18/2012 10:30 -- Notes:General&Safety End Date Annotation 1/2/2000 NOTE WORKOVER -► GAS LIFT;7,898.2 I 12/10/2007 NOTE:WORKOVER _ 12/10/2007 NOTE:"MIT TESTING WILL HAVE TO USE DS NIPPLE @ 8008' 7/2/2009 NOTE:5005'=TIGHT SPOT,UNABLE TO WORK 2.6"GAUGE RING PAST 6/27/2009 7/2/2009 NOTE:View Schematic w/Alaska Schematic9.0 PBR;7.956.6 V a,=f PACKER;0968.3 l, l.f I N NIPPLE,8,011.2 Is i I FISH;8,1580 IPERF;8,188.0-8,198.0--r IPERF;8,216.0-8,246.0 PRODUCTION;35.9-8,449.1 1 i • • Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Monday, November 20,2017 10:55 AM To: Loepp,Victoria T(DOA) Subject: RE: [EXTERNAL]KRU 2G-06( PTD 184-082) Plug for Redrill: BOP test pressure Victoria,based on the MPSP of just over 4400 psi,we will test the BOPs to 5000 psi (2500 psi for the annular). Please let me know if you have any other questions or concerns. Thanks, Mike Callahan CTD Engineer ConocoPhillips Alaska ATO 660 Office: (907)263-4180 Cell: (907)231-2176 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, November 20, 2017 10:51 AM To:Callahan, Mike S<Mike.Callahan@conocophillips.com> Subject: [EXTERNAL]KRU 2G-06( PTD 184-082) Plug for Redrill: BOP test pressure Mike, What is the BOP test pressure? • Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 • Victoria.Loepp aC�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 • 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 Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon"or "Suspend"boxes are also checked, cross out that erroneous entry and " initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon"box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial then ?' it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill"box, they 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, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill"code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assigna 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, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in 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. MAY 17 23i) WELL LOG TRANSMITTAL#903269376 AOCACC To: Alaska Oil and Gas Conservation Comm. May 13, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA OED Anchorage, Alaska 99501 5���GG K.BENDER RE: Multi Finger Caliper&Jewelry Log: 2G-06 Run Date: 4/26/2016 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 2G-06 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21121-00 Multi Finger Caliper&Jewelry Log (Field Log) 1 color log 50-029-21121-00 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. SCANNED Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / Imag~ 'oject Well History File Cover e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ ~ /~- C) ~; ~Well History File Identifier Organizing RESCAN DIGITAL DATA OVERSIZED (Scannable) [] ~jtems: Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Diskettes, No. [] Other, No/Type [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY Project Proofing BY: "-'-~OBIN VINCENT SHERYL MARIA WINDY Scanning Preparation _.~ x 30 = -I- DATE: // = TOTALPAGES BY: BEVERL~CENT SHERYL MARIA WINDY Production Scanning Stager PAGE COUNT FROM SCANNED FILE: ' (0 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES BY: (~ ROBIN VINDEN' SHERYL MARIA WINDY Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BY: BEVERLY ROBIN VINCE~IA WINDY (SCANNING I$ COMPLETE &T THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY , GRAYSCALE OR COLOR IMAGES) NO NO DATE:I /.-~/ JSI ~ ReScanned (individual page [special a~e,ti~d ~ca;ming completed) RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: ISl General Notes or Comments about this file: Quality Checked (do.e) 12/10102Rev3NOTScanned.wpd • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 1, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Gas Lift Survey: 2G -06 _ 0 '62- c Run Date: 6/15/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2G-06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21121 -00 A.MVIMIX SEP 0 6 2011 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 9/2-A\ Signed: 4 • . WELL LOG TRANSMITTAL It . PROAcrivE DimNos is SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 [907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 .* co (0 C I 1) Caliper Report 06- Jun -11 2G-06 1 Report/ CD 50-029- 21121 -00 2) Signed : `' " Da : ` o! 1 si g � 1 Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 Fax: (907)245 -8952 E : PDSANCHORAGECQ)MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\Archives\ Distribution\ Transmit talSheets \ConocoPhillips Transmit.docx 1 i • Memory Multi- Finger Caliper 1 VS Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 2G -06 Log Date: June 6, 2011 Field: Kuparuk (CPF -2) Log No.: 10258778 ZX70 State: Alaska I Run No.: 5 API No.: 50-029-21121-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8RD ABMOD Top Log Intvll .: Surface Pipet Use: Tubing Bot. Log Intvll.: 8,030 Ft. (MD) 1 Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : 1 The caliper data is correlated to Tubing Tally and Well Schematic dated (6/5/2011) 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 logged appears to be in good to fair condition, with a I maximum recorded wall penetration of 28% recorded in a line of pits in joint 109 (3,502). Recorded damage appears as lines of pits and isolated pitting. No significant areas of cross - sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. I This is the fifth time a caliper has been run in this well and the second time this 3.5" tubing has been logged since the RWO in July 2010. A comparison between the current and the previous log (November 28, 2010) indicates an increase in corrosive damage during the time between logs. A comparison graph illustrating the difference in maximum recorded penetrations on a joint -by -joint basis is included in this report. 1 This summary report is interpretation of data provided by Halliburton Well Services. 4.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: 1 Line of Pits ( 28 %) Jt. 109 @ 3,502 Ft. (MD) Line of Pits ( 28 %) Jt. 242 @ 7,708 Ft. (MD) Line of Pits ( 27 %) Jt. 248 @ 7,937 Ft. (MD) Line of Pits ( 26%) Jt. 112 @ 3,584 Ft. (MD) Isolated Pitting ( 26%) Jt. 209 @ 6,670 Ft. (MD) 4.5" TUBING - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: 1 No significant areas of cross - sectional wall loss (> 6 %) are recorded throughout the tubing logged. 4.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: 1 No significant I.D. restrictions are recorded throughout the tubing logged. Mandrel Orientation I 2G -06 ConocoPhillips Alaska, Inc. Kuparuk 6- Jun -11 Joint No. Tool Deviation Mandrel No. Latch Orientation 92.2 49 1 10:00 155.2 52 2 10:30 196.2 51 3 1:00 I 227.2 44 4 10:00 247.2 39 5 10:00 I Field Engineer: Galligan & Regnier Analyst: C. Lucasan Witness: J. Condio Active Diagnostic Services, Inc. / P.O. Box Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @memorylog.com 1 Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 te ar• 1 Correlation 'Recorded Damage to Boreholetrofile 1 • Pipe 1 3.5 in (49.4' - 8028.61 Well: 2G -06 Field: Kuparuk (CPF -2) Company: ConocoPhillips Alaska, Inc. I Country: USA Survey Date: June 06, 2011 1 . Approx. Tool Deviation ■ Approx. Borehole Profile 1 1 53 25 '■ 833 li 1 50 ,a1 1616 1 75 2395 1 GLM 1 100 3204 _ 0 I 125 3983 = c Z — s fl a) I ° 150 4762 0 GLM2 1 175 5567 1 GLM 3 200 6368 ( 1 GLM 4 225 7145 y / 1 GLM 5 f 249.3 8029 I 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) 1 Bottom of Survey = 249.3 1 1 1 • • 1 Recorded Penetration �-� � • Comparison To Previous I Well: 2G -06 Survey Date: June 06, 2011 Field: Kuparuk (CPF -2) Prev. Date: November 28, 2010 Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 24 No. 1000429 (HAL' Country: USA Tubing: 3.5" 9.3 lb L -80 8RDABMOD I Overlay Difference 1 Max. Rec. Pen. (mils) Diff. in Max Pen. (mils) 0 50 100 150 200 250 -100 -50 0 50 100 1 0.1 0.1 8 = 8 15.3 - 15.3 1 25 — 25 35 -_ - 35 45 45 1 55 55 65 = 65 75 - 75 1 85 _ 85 92.3 92.3 102 102 U 112 --.1. 112 ` 122 -� _ - -� E 122 — Z 132 Z 132 1 •0 142 E 142 152 152 — 159 159 ' i_ I 169 - 169 - 179 179 189 -- 189 I 196.3 . _ill 196.3 206 206 216 1 = 216 - r I 226 226 233 233 243 243 I 248.2 - 248.2 -192 -96 0 96 192 • June 06, 2011 ■ November 28, 2010 Approx. Corrosion Rate (mpy) 1 1 1 1 • • 1 PDS Report Overview VS. Body Region Analysis I Well: 2G -06 Survey Date: June 06, 2011 Field: Kuparuk (CPF -2) Tool Type: UW MFC 24 No. 1000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf L -80 8RDABMOD Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 ins 9.3 ppf L -80 8RDABMOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins 1 Penetration(% wall) Damage Profile (% wall) I 250 ollw Penetration body Metal loss body 0 50 100 200 1 150 100 i 50 - - 46 0 I 0 to 20 to 40 to over 20% 40% 85% 85% i Number of joints analysed (total = 268) GLM 1 94 I 245 23 0 0 I Damage Configuration (body ) _,g 150 144 GLM 2 100 50 GLM 3 192 Ali 0 I Isolated General Line Other Hole / GLM 4 Pitting Corrosion Corrosion Damage Pos. Hole 238 °=k_ GLM 5 I Number of joints damaged (total = 103) 102 1 0 0 0 Bottom of Survey = 249.3 1 1 1 1 1 • SHEET PDS REPORT JOINT TABULATION I Pipe: 3.5 in 9.3 ppf L -80 8RDABMOD Well: 2G -06 Body Wall: 0.254 in Field: Kuparuk (CPF -2) Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: June 06, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( % wall) (Ins.) (Ins.) % (Ins.) 0 50 100 0.1 49 0 0.03 10 2 2.93 Pup Lt. Deposits. ■ I 1 53 0 0.03 10 2 2.92 Lt. Deposits. 1.1 85 0 0.01 6 2 2.92 Pup Lt. Deposits. 1.2 95 0 0.02 9 0 2.98 Pup ■ 2 97 0 0.03 11 1 2.96 I 3 128 0 0.02 8 2 2.96 4 159 0 0.03 11 2 2.96 • 5 191 0 0.03 11 2 2.93 Lt. Deposits. ■ 6 221 0 0.03 11 2 2.95 ■ I 7 253 0 0.03 11 2 2.96 ■ 8 284 0 0.03 12 2 2.93 • ■ 9 315 0 0.03 11 2 2.92 Lt. Deposits. • 10 346 0 0.03 11 2 2.95 • I 11 377 0 0.03 13 3 2.93 Shallow Pitting. 12 408 0 0.02 9 2 2.96 • 13 440 0 0.03 12 6 2.96 • 14 471 0 0.02 7 2 2.96 15 502 0 0.03 12 3 2.96 I 15.1 533 0 0.02 7 3 2.94 Pup 15.2 541 () 0 0 0 2.88 DS Nipple 15.3 543 0 0.02 7 2 2.93 Pup Lt. Deposits. 16 551 0 0.02 8 1 2.96 I 17 18 582 0 0.03 11 2 2.95 • 614 0 0.03 10 3 2.95 ■ 19 645 0 0.02 9 5 2.98 ■ 20 677 0 0.03 10 5 2.96 ■ I 21 708 0 0.03 12 2 2.96 ■ 22 740 0 0.03 10 2 2.94 • ■ 23 771 0 0.03 11 2 2.94 24 802 0 0.02 8 2 2.94 I 25 833 0 0.02 7 2 2.96 26 865 0 0.02 9 2 2.95 IN 27 896 0 0.03 11 2 2.96 IN 28 927 0 0.03 11 2 2.95 ■ 29 959 0 0.02 9 2 2.95 ■ I 30 991 0 0.03 12 2 2.94 • 31 1022 0 0.02 9 1 2.96 ■ 32 1054 0 0.02 9 2 2.95 • 33 1085 0 0.03 10 2 2.93 r I 34 1116 0 0.03 11 2 2.93 Lt. Deposits. • 35 1147 0 0.03 11 2 2.91 Lt. Deposits. ■ 36 1179 0 0.02 9 1 2.95 ■ 37 1210 0 0.03 12 2 2.94 ■ I 38 1241 0 0.03 12 3 2.94 • 39 1273 0 0.04 15 2 2.93 Shallow Pitting. Lt. Deposits. NI 1304 0 0.03 10 2 2.91 Lt. Deposits. • 41 1335 0 0.02 9 3 2.93 Lt. Deposits. I 42 1366 43 1397 0 0.02 8 2 2.93 Lt. Deposits. 0 0.03 12 2 2.93 Lt. Deposits. ■ 44 1428 0 0.03 11 3 2.94 Penetration Bo Metal Loss Body Page 1 1 1 1 • • PDS REPORT JOINT TABULATION SHEET 1 Pipe: 3.5 in 9.3 ppf L -80 8RDABMOD Well: 2G -06 Body Wall: 0.254 in Field: Kuparuk (CPF -2) Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: June 06, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 45 1460 0 0.02 9 1 2.94 • I 46 1491 0 0.02 9 2 2.93 Lt. Deposits. • 47 1522 0 0.03 10 2 2.95 ■ 48 1553 0 0.03 10 2 2.91 Lt. Deposits. 49 1585 0 0.02 9 2 2.95 I 50 1616 51 0 0.03 11 2 2.94 IN 1647 0.04 0.03 11 3 2.92 Lt. Deposits. ■ 52 1678 0 0.02 9 2 2.93 53 1709 0 0.02 9 2 2.95 I 54 1740 0 0.03 10 2 2.90 Lt. Deposits. • 55 1772 0 0.04 14 4 2.93 Shallow Pitting. 56 1803 0 0.02 7 3 2.94 57 1834 0.04 0.03 11 4 2.94 • 58 1865 0 0.03 11 2 2.94 I 59 1896 0.03 0.02 8 3 2.93 Lt. Deposits. 60 1928 0 0.02 8 3 2.91 Lt. Deposits. 61 1959 0 0.03 11 1 2.93 Lt. Deposits. I 62 1990 0 0.02 9 2 2.92 Lt Deposits. 63 2021 0 0.03 11 2 2.94 • 64 2052 0 0.02 9 1 2.94 • 65 2084 0 0.02 7 2 2.93 66 2115 0 0.03 11 2 2.93 Lt. Deposits. ■ 1 67 2146 0.04 0.03 12 2 2.89 Lt. Deposits. • 68 2177 0 0.03 11 2 2.94 ■ 69 2208 0 0.03 10 2 2.94 70 2239 0 0.02 9 2 2.94 1 71 2271 0.04 0.03 11 2 2.89 Lt. Deposits. • 72 2302 0 0.03 12 2 2.94 • 73 2333 0 0.02 8 2 2.94 74 2364 0 0.02 9 2 2.92 Lt. Deposits. • I 75 2395 0 0.03 10 2 2.91 Lt. Deposits. 76 2427 0 0.02 9 2 2.92 Lt. Deposits. 77 2458 0 0.02 9 1 2.93 Lt. Deposits. 78 2489 0 0.03 11 2 2.93 Lt. Deposits. ■ I 79 2520 0.04 0.02 9 2 2.93 Lt. Deposits. • 80 2551 0 0.03 10 2 2.93 ■ 81 2583 0 0.03 12 2 2.94 Shallow Pitting. • 82 2614 0.03 0.03 13 2 2.93 Shallow Pitting. Lt. Deposits. • 83 2645 0 0.03 12 2 2.94 Shallow Pitting. ■ I 84 2676 0 0.03 12 3 2.94 Shallow Pitting. • 85 2707 0.03 0.03 12 2 2.91 Shallow Pitting. Lt. Deposits. • 86 2738 0 0.04 15 2 2.94 Shallow Pitting. ■ 87 2770 0 0.03 10 2 2.94 ■ I 88 2801 0.27 0.03 11 2 2.92 Hole in Upset! Lt. Deposits. • 89 2832 0.03 0.04 14 3 2.93 Shallow Pitting. Lt. Deposits. • 90 2863 0.04 0.04 18 2 2.92 Shallow Pitting. Lt. Deposits. • 91 2895 0 0.03 10 2 2.94 • 1 92 2926 0 0.03 13 2 2.93 Shallow Pitting. Lt. Deposits. ■ 92.1 2957 0 0.03 13 2 2.94 Pup Shallow Pitting. 92.2 1 2967 0 0 0 0 2.90 GLM 1 (10:00) I Penetration Bo Metal Loss Body Page 2 1 1 1 PDS REPRT JOINT TABULATION SHE• I Pipe: 3.5 in 9.3 ppf L -80 8RDABMOD Well: 2G -06 Body Wall: 0.254 in Field: Kuparuk (CPF -2) Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: June 06, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 923 2976 0 0.04 17 2 2.91 Pup Shallow Line of Pits. Lt. Deposits. • I 93 2986 0 0.02 9 2 2.95 • 94 3017 0 0.03 12 1 2.90 Lt. Deposits. • ■ 95 3049 0 0.04 17 2 2.94 Shallow Line of Pits. • 96 3079 0 0.04 15 3 2.94 Shallow Line of Pits. ■ I 97 3111 0 0.04 14 2 2.92 Shallow Pitting. Lt. Deposits. • 98 3142 0 0.04 14 2 2.92 Shallow Pitting. Lt. Deposits. ■ 99 3173 0 0.03 12 2 2.94 Shallow Pitting. • 100 3204 0.04 0.05 21 2 2.93 Line of Pits. Lt. Deposits. ■w 101 3235 0 0.05 21 2 2.93 Isolated Pitting. Lt. Deposits. • I 102 3267 0 0.05 18 2 2.95 Shallow Line of Pits. ■ 103 3298 0.03 0.03 12 2 2.93 Lt. Deposits. ■ 104 3329 0 0.04 14 2 2.91 Shallow Pitting. Lt. Deposits. • 105 3360 0 0.05 20 3 2.92 Shallow Line of Pits. Lt. Deposits. ■io I 106 3391 0.05 0.05 20 4 2.95 Shallow Line of Pits. ■m 107 3422 0 0.06 24 3 2.92 Line of Pits. Lt. Deposits. ■ e 108 3454 0 0.05 20 2 2.95 Shallow Line of Pits. ■m 109 3485 0 0.07 28 2 2.92 Line of Pits. Lt. Deposits. E. I 110 3516 0 0.06 22 4 2.93 Line of Pits. Lt. Deposits. ■� 111 3547 0 0.05 20 4 2.94 Isolated Pitting. ■o 112 3578 0.03 0.07 26 2 2.93 Line of Pits. Lt. Deposits. •• 113 3609 0 0.04 17 2 2.93 Shallow Pitting. Lt. Deposits. ■i I 114 3640 0 0.04 14 2 2.93 Shallow Pitting. Lt. Deposits. • 115 3671 0 0.05 21 2 2.93 Isolated Pitting. Lt. Deposits. woo 116 3703 0.04 0.06 24 2 2.93 Line of Pits. Lt. Deposits. ■EI 117 3734 0 0.06 22 2 2.94 Line of Pits. • 118 3764 0 0.04 17 2 2.92 Shallow Pitting. Lt. Deposits. ■ I 119 3795 0 0.05 19 2 2.94 Shallow Line of Pits. 120 3826 0 0.02 8 2 2.91 Lt. Deposits. 121 3858 0 0.03 12 2 2.94 • 122 3889 0 0.04 16 3 2.93 Shallow Pitting. Lt. Deposits. • I 123 3920 0 0.03 10 4 2.92 Lt. Deposits. • 124 3951 0 0.04 14 4 2.92 Shallow Pitting. Lt. Deposits. • 125 3983 0 0.05 19 3 2.92 Shallow Line of Pits. Lt. Deposits. • 126 4014 0 0.04 16 1 2.95 Shallow Pitting. ■ I 127 4045 0 0.04 17 2 2.93 Shallow Line of Pits. Lt. Deposits. • 128 4077 0 0.05 19 2 2.94 Shallow Pitting. • 129 4107 0 0.03 11 2 2.95 • 130 4138 0 0.02 9 3 2.93 Lt. Deposits. r I 131 4170 0 0.03 13 2 2.92 Shallow Pitting. Lt. Deposits. • 132 4201 0 0.04 14 4 2.93 Shallow Pitting. ■ 133 4233 0 0.04 17 2 2.92 Shallow Pitting. Lt Deposits. • 134 4264 0 0.02 7 2 2.91 Lt. Deposits. 135 4295 0 0.04 14 2 2.92 Shallow Pitting. Lt. Deposits. ■ I 136 4326 0 0.05 20 2 2.94 Shallow Pitting. • 137 4357 0 0.03 13 2 2.91 Shallow Pitting. Lt. Deposits. ■ 138 4388 0 0.02 9 3 2.92 Lt. Deposits. ■ 139 4420 0.03 0.05 18 2 2.93 Shallow Line of Pits. Lt. Deposits. • I 140 4450 0 0.04 14 2 2.93 Shallow Pitting. Lt. Deposits. ■ 141 4482 0 0.04 15 1 2.94 Shallow Pitting. ti I Penetration oss Bo dy I Page 3 1 1 PDS REIIRRT 1 OINT TABULATION SHE I Pipe: 3.5 in 9.3 ppf L -80 8RDABMOD Well: 2G -06 Body Wall: 0.254 in Field: Kuparuk (CPF -2) Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: June 06, 2011 I joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 142 4513 0 0.03 11 3 2.90 Lt. Deposits. I 143 4545 144 4575 0 0.03 10 2 2.93 Lt. Deposits. 0 0.03 11 1 2.95 • 145 4606 0 0.02 9 2 2.92 Lt. Deposits. 146 4637 0 0.03 11 3 2.93 Lt. Deposits. I 147 4669 0 0.04 15 2 2.94 Shallow Pitting. 148 4700 0.03 0.04 17 6 2.91 Shallow Pitting. Lt. Deposits. 149 4732 0 0.03 13 2 2.93 Shallow Pitting. 150 4762 0 0.04 15 3 2.94 Shallow Pitting. I 151 4793 0 0.03 12 2 2.93 Lt. Deposits. _ 152 4824 0 0.02 9 2 2.92 Lt. Deposits. 153 4856 0 0.04 15 2 2.93 Shallow Pitting. Lt. Deposits. 154 4887 0 0.04 14 3 2.93 Shallow Pitting. Lt. Deposits. 155 4918 0 0.04 15 2 2.94 Shallow Pitting. I 155.1 4949 0 0.02 9 4 2.95 Pup 155.2 4957 0 0 0 0 2.88 GLM 2 (Latch @ 10:30) 155.3 4967 0.04 0.02 7 2 2.92 Pup Lt. Deposits. V 156 4974 0 0.02 9 2 2.94 I 157 5005 0 0.03 13 5 2.93 Shallow Pitting. Lt. Deposits. ■ 158 5037 0.04 0.04 18 3 2.93 Shallow Line of Pits. Lt. Deposits. 159 5067 0 0.03 11 3 2.95 160 5098 0.03 0.03 13 2 2.90 Shallow Pitting. Lt. Deposits. I 161 5130 0 0.02 8 2 2.94 162 5162 0 0.03 13 3 2.94 Shallow Pitting. • 163 5193 0 0.02 7 2 2.93 Lt. Deposits. 164 5224 0 0.04 17 2 2.94 Shallow Pitting. I 165 5255 0 0.04 17 2 2.94 Shallow Pitting. 166 5286 0 0.04 17 2 2.93 Shallow Pitting. Lt. Deposits. 167 5318 0 0.02 7 1 2.92 Lt. Deposits. 11 168 5349 0 0.05 19 2 2.94 Shallow Pitting. I 169 5379 0 0.04 15 5 2.91 Shallow Line of Pits. Lt. Deposits. ■ 170 5411 0 0.03 11 2 2.92 Lt. Deposits. 171 5443 0 0.03 12 4 2.91 Lt. Deposits. ■ 172 5474 0 0.03 11 2 2.93 Lt. Deposits. 173 5504 0.03 0.03 12 2 2.94 I 174 5536 0 0.02 7 2 2.93 Lt. Deposits. 175 5567 0 0.03 12 2 2.93 Lt. Deposits. II 176 5597 0 0.02 7 2 2.93 Lt. Deposits. 177 5629 0 0.02 9 2 2.90 Lt. Deposits. I 178 5659 0 0.02 9 2 2.95 179 5691 0 0.02 7 2 2.94 III 180 5721 0 0.03 12 2 2.93 Lt. Deposits. II 181 5754 0 0.04 16 2 2.93 Shallow Pitting. Lt. Deposits. • I 182 5784 0 0.03 13 2 2.91 Shallow Pitting. Lt. Deposits. 183 5816 0.03 0.07 26 2 2.92 Line of Pits. Lt. Deposits. 184 5844 0 0.02 9 2 2.93 Lt. Deposits. 185 5876 0 0.03 10 2 2.92 Lt. Deposits. I 186 5907 187 5938 0 0.04 15 2 2.94 Shallow Pitting. 0 0.02 8 2 2.94 188 5969 0 0.03 10 1 2.93 Lt. Deposits. • Penen I Metal Los tratio s Bo dy Page 4 1 1 1 PDS REPORT 1 OINT TABULATION SHE I Pipe: 3.5 in 9.3 ppf L -80 8RDABMOD Well: 2G -06 Body Wall: 0.254 in Field: Kuparuk (CPF -2) Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: June 06, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 189 6000 0 0.03 12 3 2.94 I 190 6032 0 0.02 8 2 2.94 191 6063 0 0.03 13 2 2.91 Shallow Pitting. Lt. Deposits. • 192 6094 0 0.03 12 2 2.91 Shallow Pitting. Lt. Deposits. 193 6125 0 0.02 8 2 2.92 Lt. Deposits. I 194 6157 0 0.02 9 2 2.92 Lt. Deposits. • 195 6188 0 0.04 14 2 2.93 Shallow Pitting. Lt. Deposits. • ■ 196 6219 0 0.05 20 2 2.89 Shallow Line of Pits. Lt. Deposits. ■ 196.1 6250 0.07 0.04 15 1 2.91 Pup Shallow Corrosion. Lt. Deposits. I 196.2 6258 0 0 0 0 2.89 GLM 3 (Latch 1:00) 196.3 6267 0 0.02 9 1 2.96 Pup • 197 6275 0 0.06 24 4 2.92 Isolated Pitting. Lt. Deposits. 198 6307 0 0.02 9 2 2.93 Lt. Deposits. 199 6338 0 0.02 8 2 2.93 Lt. Deposits. I 200 6368 0 0.02 9 2 2.90 Lt. Deposits. 201 6401 0 0.02 7 2 2.95 202 6431 0 0.05 20 2 2.93 Shallow Pitting. in 203 6462 0 0.05 18 2 2.93 Shallow Pitting. Lt. Deposits. • 204 6494 0.04 0.04 15 2 2.91 Shallow Pitting. Lt. Deposits. ■ 205 6524 0 0.05 21 2 2.93 Isolated Pitting. Lt. Deposits. • 206 6556 0 0.04 17 1 2.94 Shallow Pitting. ■ 207 6587 0 0.04 15 2 2.95 Shallow Pitting. ■ I 208 6618 209 6650 0 0.03 10 2 2.93 Lt Deposits. ■I 0 0.07 26 2 2.93 Isolated Pitting. 210 6680 0 0.02 9 2 2.92 Lt. Deposits. 211 6711 0 0.03 11 2 2.93 Lt. Deposits. ' 212 6742 0 0.02 7 2 2.92 Lt. Deposits. 213 6773 0 0.03 11 3 2.88 Lt. Deposits. • 214 6806 0 0.04 14 1 2.93 Shallow Pitting. Lt. Deposits. ■ 215 6837 0 0.02 9 2 2.94 I 216 6868 0 0.02 8 2 2.93 Lt. Deposits. 217 6899 0 0.03 11 2 2.94 • 218 6930 0 0.03 10 2 2.92 Lt. Deposits. • 219 6961 0 0.02 8 2 2.94 220 6991 0 0.04 15 1 2.94 Shallow Pitting. I 221 7023 0 0.02 8 2 2.92 Lt. Deposits. 222 7055 0 0.02 8 2 2.92 Lt. Deposits. 223 7086 0 0.02 8 1 2.93 Lt. Deposits. 224 7116 0 0.03 10 2 2.93 Lt. Deposits. ■r I 225 7145 0.03 0.03 11 2 2.91 Lt. Deposits. 226 7177 0 0.02 8 2 2.91 Lt. Deposits. 227 7208 0.05 0.05 18 4 2.93 Shallow Pitting. Lt. Deposits. 227.1 7240 0 0.01 6 2 2.94 Pup I 227.2 7247 0 0 0 0 2.89 GLM 4 (Latch 10:00) 227.3 7256 0 0.02 9 4 2.92 Pup Lt. Deposits. 228 7265 0 0.02 7 2 2.94 11 229 7296 0.03 0.03 10 2 2.89 Lt. Deposits. • I 230 7328 0 0.04 15 1 2.94 Shallow Pitting. • 231 7359 0 0.03 12 2 2.94 232 7389 0.04 0.02 8 2 2.93 Lt. Deposits. Penetration Bo I Metal Loss Body Page 5 1 1 1 PDS REPO RT J OINT TABULATION SHE! I Pipe: 3.5 in 9.3 ppf L -80 8RDABMOD Well: 2G -06 Body Wall: 0.254 in Field: Kuparuk (CPF -2) Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: June 06, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/0 wall) (Ins.) (Ins.) % (Ins.) 0 50 100 233 7421 0 0.02 7 2 2.94 I 234 7452 0 0.02 8 2 2.93 Lt. Deposits. 235 7482 0 0.02 7 2 2.93 Lt. Deposits. 236 7515 0 0.03 13 2 2.94 Shallow Pitting. 237 7545 0 0.02 9 2 2.93 Lt. Deposits. I 238 7577 239 7607 0 0.02 8 2 2.93 Lt. Deposits. O 0.02 7 1 2.91 Lt. Deposits. 240 7639 0 0.04 16 2 2.94 Shallow Pitting. 241 7670 0.03 0.06 23 3 2.93 Isolated Pitting. Lt. Deposits. I 242 7701 243 7731 0 0.07 28 4 2.92 Line of Pits. Lt. Deposits. O 0.03 13 2 2.93 Shallow Pitting. Lt. Deposits. 244 7764 0 0.04 17 2 2.92 Shallow Pitting. Lt. Deposits. 245 7794 0 0.04 16 2 2.93 Shallow Line of Pits. Lt. Deposits. 246 7825 0 0.05 18 2 2.95 Shallow Pitting. I 247 7856 0.04 0.04 16 2 2.93 Shallow Pitting. Lt. Deposits. 247.1 7887 0 0.03 10 2 2.95 Pup 247.2 7895 0 0 0 0 2.90 GEM 5 (Latch @ 10:00) 247.3 7904 0 0.03 12 2 2.93 Pup Lt. Deposits. 1 248 7912 0.03 0.07 27 2 2.94 Line of Pits. 248.1 7943 0 0.05 19 3 2.92 Pup Shallow Line of Pits. Lt. Deposits. 248.2 7953 0 0.02 8 2 2.92 Pup Lt. Deposits. 248.3 7966 0 0 0 0 3.03 FHL Packer I 248.4 7973 249 7979 0 0.03 11 4 2.91 Pup Lt. Deposits. O 0.03 13 3 2.90 Shallow Pitting. Lt. Deposits. 249.1 8009 0 0 0 0 2.81 DS Nipple 249.2 8011 0 0.04 17 2 2.94 Pup Shallow Pitting. I 249.3 8029 0 0 0 0 2.98 Mule Shoe I Peti Bo Metal tra Loss Body 1 1 1 1 1 . 1 Page 6 1 1 1 • • 1 PDS Report Cross Sections I Well: 2G -06 Survey Date: June 06, 2011 Field: Kuparuk (CPF -2) Tool Type: UW MFC 24 No. 1000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf L -80 8RDABMOD Analyst: C. Lucasan 1 Cross Section for Joint 109 at depth 3502.570 ft 1 Tool speed = 51 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 98% Tool deviation = 52° I 1 7 1 i 1 1 1 N N 1 1 Finger = 22 Penetration = 0.071 ins Line of Pits 0.07 ins. = 28% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 1 • • 1 VS, PDS Report Cross Sections I Well: 2G -06 Survey Date: June 06, 2011 Field: Kuparuk (CPF 2) Tool Type: UW MFC 24 No. 1000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 8RDABMOD Analyst: C. Lucasan 1 I Cross Section for Joint 242 at depth 7708.470 ft Tool speed = 50 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 98% / Tool deviation = 41° 1 1 1 \ / 1 1 1 Finger = 22 Penetration = 0.070 ins Line of Pits 0.07 ins. = 28% Wall Penetration HIGH SIDE = UP 1 1 1 1 .0, KUP 2G-06 COIIOCOPhillip5 0 at tributes P agle & ND 7D Alaska, Inc_ i APIa1W1 Fldd Name Well Status In9_ MD (rtKB net etm MKS) CanocoR�fi� 500292112100 _ KUPARUK RIVER UNIT PROD 54.60 4,000.00 8,449.0 Comment N2S (ppn ) Date Annotation End Date 1034rd (1q Rig Release Date SSSV: NIPPLE 150 1/11/2009 Last WO: 7/14/2010 36.00 6/18/1984 We8CnMlg. -2G -06. 721/2010 1248 01 PM Schemffib -Actual Annotation Depth NIK8) End Date Annotation Lot Mod ... End Date Las[ Tag: SLM 8,038.0 11/25/2009 Rev Reason: GLV GO, Pull Plug & Catcher Imosbor 7/2112010 Casing Strings s HANGER. 30 Casing Description String 0... String ID ... Top OMB) Set Depth (L. Set Depth (1VD) ... String Wt.. String... String Top Thd CONDUCTOR 16 15.062 38.0 110.0 110.0 62.58 H - 40 Welded 1 Casing Desaipgon String 0_. Shim D ... Top (N(� Set Depth (8. Set Depth (1VD) ... String Wt. String String Top Thai SURFACE 95/8 8.765 37.2 3,133.9 2,773.9 36.00 J - 55 BTC Casing Description String 0_. Stlllm D _. Top (111(8) Set Depth (L Set Depth (1VD) ._ String Wt. S11Mg String Top Tlyd PRODUCTION 7 6.151 35.9 8,449.1 6,223.8 26.00 J -55 BTC Tubing Strings Tubing Description String 0... String ID -. Top (OKB) Set Depth (8... 5d Depth (TVD) _ String Wt..- Stung... String Top TIN ' TUBING2010 3 1/2 2.992 30.1 7,969.3 5,841.5 9.30 L -80 EUE8rdABMOD Completion Details Top Depth CONDUCTOR, (TVD) Top Inc! Noma 38 -110 . Tap Mite) (111(8) ( "1 Item Description Comment ID (in) a 30.1 30.1 0.09 HANGER Vetco /Gray Gen 11 TUBING HANGER 2.938 524.7 524.6 1.18 NIPPLE 3.5" Camco "DS" Nipple w/ 2.875 profile 2.875 NIPPLE, 525 T bi 7 . 956 - 6 5,831.7 39.63 PBR PBR Seal Assembly (sheared) w/ 2' space out STABBED INTO PACKER 2.980 Tubing Description String 0... String ID String _. Top OMB) Set Depth (T_ Set Depth (TVD) _ Sng Wt... String... String Top T1rd T UBING Packer Assy 3 1/2 2.992 7,965.9 8,043.6 5,899.3 9.30 L -80 8RD EUE IN Completion Details Top Depth I GAS LIFT. . P Top loci Nord._ 2.951 T op (AB) ( & (°) Item DescdplIon Comment ID On) 7,965.9 5,838.8 39.53 PACKER FHL Packer 3.030 8,008.7 5,872.5 39.12 NIPPLE 2-813" DS Nipple 2.813 8,041.1 5,897.4 38.70 SHOE 2 ft Shorkle MULE SHOE 3 -1/7' EUE 2.980 I Tubing Description String 0... String D... Tap (11146) Set Depth (8... Set Depth (TVD) - Wing Wt.. String._ Skiing Top lied TUBING 1999 3 12 2.992 8,042.0 8,081.3 5,928.7 9.30 L -80 EUE8rdMOD SURFACE. J Completion Detail$ 373 134 Top Depth r . -. (1VW Topmci Nonni... Top O8B) (1008) ("1 Item Description ID (In) ' , 8,042.0 5,898.1 38.69 PACKER FHL RETRIEVABLE PACKER 2.850 GAS LIFT. T, 4.948 8.0693 5,919.2 38.34 NIPPLE HES NIPPLE w /SELECTIVE PROFILE 2.750 8,080.6 5,928.1 38.20 W CommeK LEG WIRELINE ENTRY GUIDE 2.992 Other In Hole ( Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth ( Tap Intl GAS LIFT. a, Top (RKB) ( B) (°) Description Comment Run Dale D N4 6,250 8,0 38.34 PLUG 2.75° PXX PLUG IN HES'X' NIPPLE 12/10/2007 0.000 Perforation & Slots shot .."4 Top ( Blnn(TVD) DeM GAS LFT. Tap 1111(8) Btrn MKS) 0 tIM Zane Dih ( - Type Comment 7.246 8,188 8,198 6,013.3 6,021.3 AS, 2G-06 9/24/1988 4.0 IPERF 90 deg. Phasing; 4" Schiumberger Casi 8,216 8,246 6,035.7 6,059.9 A -4, 2G-06 9/24/1988 4.0 IPERF 90 deg. Phasing; 4" Schlumberger Casi i GAS LFT. Notes: General & Safety 7,898 • End Date 1/2/2000 NOTE: WORKOVER 12/10/2007 NOTE: WORKOVER Annotation 12/102007 NOTE: "MIT TESTING WILL HAVE TO USE DS NIPPLE 1 1 8008' """ i PBR, 7,987 1/5/2008 NOTE: CUT TBG TAIL POST WO DROPPED 97', COVERED WITH FILL I@ 8159' SLM 7/2/2009 NOTE: 5005' = TIGHT SPOT, UNABLE TO WORK 2.6" GAUGE RING PAST 6/27/2009 �� 7/2/2009 NOTE: VIEWW /ALASKA SCHEMATIC 9.0 N. PACKER. 7.966 1 NIPPLE. 8,009 1 SHOE, 8,041 I PACKER, 6,042 W_ PLUG. 8069 I all NIPPLE. GOO III WLEG.8.081 / t Mandrel Details I Se T op Depth Top Port MD) Ind OD Valve Lath bTZe IRO Rw Sm Top (RIB) 11KB) CI Make Model Prf Type Type 1 ) Ns4 Run Date Com... 1 2,951.5 2,655.5 49.03 Camco MMG 1 12 GAS UFT DMY R -20 0.188 1,271.0 7/192010 2 4,945.5 3,852.0 53.27 Camco MMG 1 12 GASUFT GLV R -20 0.188 1,265.0 7/19/2010 alalaaR = = = 3 6,250.3 4,646.5 52.51 Cameo MMG 112 GAS LIFT GLV R -20 0.188 1,256.0 7/182010 4 7,246.0 5,310.9 45.76 Camco MMG 1 12 GAS LIFT GLV R -20 0.188 1,245.0 7/18/2010 IPERE, - 5 7,898.2 5,786.8 40.24 Camco MMG 1 12 GAS LIFT OV rdo20 0.250 0.0 7/1812010 8,216 -8,246 1 TD. 8,449 _- PRODUCTION, • • 38 -8.449 • WELL LOG _ S TRANSMITTAL PROAcTivE DiAgnos1ic SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C F 1 2011 Anchorage, AK 99518 F Fax: (907) 245 -8952 1) Caliper Report 27- Nov-10 1L-03A 1 Report / EDE 50-029- 21182 -01 2) Caliper Report 28 -Nov10 2G-06 1 Report / EDE 50 -029 -21 121 -00 "59 -v3 2 0 zi..‘ Signed : _ 7 . Date Print Name: 5 a '. 3 a. 15 =<{ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -88952 E -MAIL : odsanehorac e(a.niernorvlcq.corrl WEBSITE : www.rrlemoryloq.com C:\Documents and Settings \Diane Williams \Des[dop \Transmit_Conoco.docx i • • 1 111111 Multi- Finger Caliper Log Results Summary 1 Company: ..� ConocoPhillips Alaska, Inc. Well: 2G -06 Log Date: November 28, 2010 Field: Kuparuk Log No.: SO# 10258778 2X16 State: Alaska I Run No.: 4 API No.: 50- 029 21121 -00 Pipet Desc.: 3.5" 9.3 Ib. L -80 EUE 8RD ABMOD Top Log Intvl: Surface Pipet Use: Tubing Bot. Log Intvl: 8,043 Ft. (MD) 1 Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : 1 This caliper data is correlated to the Wellbore Schematic dated July 21, 2010. This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. I The caliper recordings indicate the 3.5" tubing logged appears to be in good to fair condition, with a maximum recorded wall penetration of 24% recorded in a line of pits in joint 248 (7,936'). Other recorded damage appears as a line of pits and isolated pitting. No significant areas of cross - sectional wall loss or I.D. I restrictions are recorded throughout the tubing logged. This is the fourth time a caliper has been run in this well and the first time this 3.5" tubing has been logged since the RWO in July 2010. 1 This summary report is interpretation of data provided by Halliburton Well Services. 1 MAXIMUM RECORDED WALL PENETRATIONS : Line of Pits ( 24 %) Jt. 248 @ 7,936 Ft. (MD) Line of Pits ( 22 %) Jt. 248.1 @ 7,951 Ft. (MD) I Isolated Pitting ( 21 %) Jt. 227 @ 7,237 Ft. (MD) Line of Pits (21 %) Jt. 242 @ 7,716 Ft. (MD) Isolated Pitting ( 20 %) Jt. 240 @ 7,641 Ft. (MD) 1 MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : No significant areas of cross - sectional wall loss (> 6 %) are recorded throughout the tubing logged. 1 MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. 1 1 1 I I Field Engineer: J. Conrad Analyst: C. Waldrop Witness: 8. Boehme ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Boone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail PDS�4memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 1 i'V 0e6a- 04)6-615- i • Correlation of Recorded Damage to Borehole Profile I Pipe 1 3.5 in (50.5' - 8043.3') Well: 2G-06 Field: Kuparuk I Company: Country: ConocoPhillips Alaska, Inc. USA Survey Date: November 28, 2010 I I ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 54 25 _ 835 I 50 a 1618 75 2397 I GLM 1 100 3206 _ a I iii 125 i 3985 L c 111 — Z t I c v ° 150 4764 0 GLM 2 I 175 1 5567 I GLM 3 200 �- 6370 ii M I GLM 4 225 __ 7147 I GLM 5 8012 2 5011 8043 1 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) t Bottom of Survey = 250.1 I I I • • PDS Report Overview VS. Body Region Analysis I Well: 2G -06 Survey Date: November 28, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 10000429 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 EUE 8RD ABMOD Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 ins 9.3 ppf L -80 EUE 8RD ABMOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins I Penetration(% wall) Damage Profile (% wall) I 300 NM Penetration body =IN Metal loss body 0 50 100 250 0 I 200 150 100 i S0 46 A 0 I 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 267) GLM 1 94 I 262 5 0 0 n I Damage Configuration ( body ) 20 144_ GLM 2 "A I 15 10 I 5 192 GLM 3 a 0 ° ■ I Isolated General Line Other Hole/ GLM 4 Pitting Corrosion Corrosion Damage Pos. Hole 238 GLM 5 I Number of joints damaged (total = 19) 19 0 0 0 0 Bottom of Survey = 250.1 I I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8RD ABMODWeII: 2G -06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: November 28, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 51 0 0.03 10 2 3.00 Pup in 54 0 0.03 11 2 2.96 1.1 86 0 0.01 6 2 2.96 Pup 1.2 96 0 0.02 8 6 2.99 Pup 2 98 0.03 0.03 11 2 2.97 ■ I 3 129 0 0.03 10 2 2.96 • 4 160 0.03 0.03 10 1 2.97 ■ 5 191 0 0.03 11 2 2.95 • 6 223 0 0.03 10 2 2.96 ■ I 7 254 0 0.03 10 2 2.97 • 8 285 0 0.03 10 2 2.95 • ■ 9 316 0 0.03 11 2 2.93 Lt. Deposits. • 10 347 0.03 0.03 10 2 2.96 • 11 378 0 0.03 10 3 2.96 • 12 410 0 0.03 11 1 2.97 ■ 13 441 0 0.03. 10 2 2.96 • 14 472 0 0.02 9 1 2.97 , • 15 504 0.03 0.02 9 2 2.97 I 15.1 535 0 0.02 9 3 2.95 Pup 15.2 543 0 0 0 0 2.88 DS Nipple 15.3 544 0 0.02 9 2 2.94 Pup 16 552 0 0.02 9 1 2.97 I 17 584 0 0.02 9 2 2.96 18 615 0 0.03 10 2 2.96 19 646 0 0.02 7 1 2.98 20 678 0 0.02 8 2 2.97 I 21 710 0.04 0.02 9 2 2.98 22 741 0 0.02 9 2 2.98 23 772 0 0.03 11 2 2.95 • 24 803 0 0.03 10 2 2.96 • I 25 835 0 0.03 10 2 2.96 26 866 0.03 0.02 9 2 2.96 27 897 0 0.03 12 2 2.96 • 28 929 0.03 0.02 9 2 2.96 29 960 0 0.02 8 2 2.98 I 30 31 992 0 0.03 10 2 2.97 ■ 1024 0 0.03 10 2 2.97 7 32 1055 0 0.02 9 2 2.97 33 1087 0 0.03 11 1 2.95 ■ I 34 1118 0.04 0.03 11 2 2.94 35 1149 0.04 0.02 9 2 2.94 36 1180 0 0.03 11 1 2.96 ■l 37 1212 0 0.02 9 2 2.95 J I 38 1243 0 0.02 9 3 2.95 • 39 1274 0 0.03 11 2 2.94 • ■ 40 1305 0 0.03 11 2 2.93 Lt. Deposits. • 41 1337 0.03 0.02 9 3 2.95 • 42 1368 0 0.03 10 2 , 2.94 • I 43 1399 0.03 0.02 9 2 2.94 • 44 1430 0 0.03 10 4 2.96 rat Body I Metal Loss ion Body Page 1 Penet I 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8RD ABMODWeII: 2G -06 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 28, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 45 1462 46 1493 0 0.02 9 2 2.95 0 0.02 9 2 2.94 47 1524 0 0.02 8 2 2.95 48 1555 0 0.02 8 2 2.95 49 1586 0 0.03 10 2 2.96 I 50 1618 3 0.02 8 2 2.95 51 1649 0.04 0.03 11 2 2.94 • 52 1680 0 0.03 11 3 2.95 53 1711 0 0.02 8 2 , 2.96 I 54 1743 0.03 0.03 11 2 2.95 • 55 1774 0.03 0.02 9 2 2.95 56 1805 0 0.02 9 3 2.96 57 1836 0 0.03 10 2 2.96 • I 58 1867 0 0.03 10 3 2.95 • 59 1898 0 0.02 9 2 2.94 • 60 1929 0 0.03 11 3 2.93 • 61 1961 0 0.03 11 3 2.94 • I 62 1992 0 0.02 9 2 2.93 63 2023 0 0.02 9 2 2.95 64 2054 0 0.03 11 3 2.96 65 2085 0 0.02 7 2 2.94 66 2116 0.03 0.03 11 3 2.94 I 67 2148 0.04 0.02 8 2 2.93 68 2179 0 0.02 9 2 2.95 ■ 69 2210 0 0.03 11 2 2.96 ■ 70 2241 0 0.03 10 3 2.95 I 71 2273 0.05 0.02 7 2 2.93 72 2304 0 0.03 10 2 2.95 73 2335 0 0.02 9 4 2.94 74 2366 0.04 0.03 11 3 2.94 ■ I 75 2397 0 0.02 9 2 2.93 Lt. Deposits. ■ 76 2429 0 0.03 10 2 2.94 77 2460 0 0.02 8 2 2.95 78 2491 0 0.02 8 4 2.94 79 2522 0 0.02 7 2 2.94 I 80 2553 0.03 0.03 11 3 2.94 • 81 2585 0 0.03 10 3 2.96 ■ 82 2616 0.04 0.03 11 3 2.94 • 83 2647 0 0.03 12 2 2.95 • I 84 2678 0 0.03 11 2 2.93 • 85 2710 0.03 0.03 10 2 2.93 Lt. Deposits. 86 2740 0 0.02 8 2 2.96 87 2772 0 0.03 10 2 2.96 I 88 2803 0 0.02 9 2 2.93 Lt. Deposits. 89 2834 0 0.03 10 2 2.93 • 90 2865 0.04 0.03 11 2 2.93 Lt. Deposits. • 91 2897 0 0.02 8 3 2.96 92 2928 0 0.02 8 3 2.93 I 92.1 2959 0 0.03 10 2 2.96 Pup 92.2 2969 0 0 0 0 2.91 GLM 1 (Latch @ 9:30) rat I Metal Loss ion 03 1 I 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8RD ABMODWeII: 2G -06 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 28, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 92.3 2978 0 0.02 8 4 2.96 Pup 93 2988 0 0.02 9 2 2.95 94 3019 () 0.02 8 1 2.96 95 3050 0.01 0.02 8 2 2.94 I 96 3081 0 0.02 7 2 2.95 97 3112 0 0.02 9 4 2.94 ■ 98 3144 0.03 0.03 11 4 2.96 99 3175 0 0.02 8 2 2.95 100 3206 0 0.02 9 2 2.95 I 101 3237 0 0.03 10 3 2.96 II 3268 0 0.03 10 3 2.94 ■ 103 3299 0 0.03 11 5 2.91 ■ 104 3331 0 0.03 11 2 2.94 IN I 105 3362 0.04 0.03 10 4 2.94 ■ 106 3393 0 0.03 10 2 2.97 IN 3424 0 0.03 11 3 2.94 N 108 3456 0 0.02 8 2 2.95 I 109 3486 0 0.03 11 1 2.95 ■ 110 3517 0.04 0.03 11 2 2.95 IN 111 3548 0 0.03 11 2 2.93 Lt. Deposits. ■ 112 3579 0 0.03 11 2 2.95 113 3610 0 0.02 8 2 2.95 I 114 3642 0 0.03 11 2 2.94 ■ 115 3673 0 0.03 12 I 2.95 ■ 116 3704 0.04 0.03 13 2 2.95 Shallow Pitting. ■ 117 3735 0 0.03 12 2 2.95 Shallow Pitting. ■ I 118 3767 0 0.04 14 2 2.93 Shallow Pitting. NI 3798 0 0.02 9 2 2.92 Lt. Deposits. 120 3829 0 0.02 9 2 2.96 121 3859 0 0.02 9 2 2.93 Lt. Deposits. I 122 3891 0 0.02 9 2 2.95 123 3922 0.04 0.03 11 4 2.95 IN 3953 0 0.02 9 4 2.94 ■ 125 3985 0.03 0.03 10 3 2.93 Lt. Deposits. • 126 4016 0 0.03 12 1 2.96 IN I 127 4047 0 0.03 12 2 2.95 ■ 128 4078 0 0.03 11 2 2.95 129 4109 0 0.02 8 2 2.96 130 4140 0 0.02 7 2 2.95 I 131 4172 0 0.02 9 2 2.94 132 4203 0 0.02 8 2 2.96 133 4234 0 0.02 9 2 2.94 • 134 4266 0 0.03 11 2 2.95 I 135 4296 0 0.02 7 2 2.93 Lt. Deposits. 136 4328 0.03 0.02 9 3 2.95 • 137 4359 0 0.03 10 2 2.93 Lt. Deposits. ■ 138 4390 0 0.02 9 2 2.95 139 4421 0 0.02 7 2 2.95 I 140 4452 0 0.03 10 3 2.90 Lt. Deposits. ■ 141 4483 0 0.03 10 1 2.95 rat I Metal Loss ion Body I Page 3 Penet I 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8RD ABMODWeII: 2G -06 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: November 28, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 142 4514 0 0.02 8 3 2.94 143 4545 0 0.02 9 2 2.95 144 4576 0 0.02 9 3 2.95 • 145 4607 0 0.03 11 2 2.93 • I 146 4639 0 0.03 10 4 2.91 147 4671 0 0.02 8 2 2.96 148 4701 0 0.03 10 2 2.95 149 4732 0 0.02 7 2 2.95 150 4764 0 0.02 7 2 2.96 151 4795 0.03 0.03 11 2 , 2.95 152 4826 0 0.02 8 2 2.94 153 4857 0 0.02 9 3 2.95 • 154 4889 0 0.03 12 2 2.95 155 4920 0 0.02 7 2 2.95 155.1 4950 0 0.03 10 4 2.97 Pup 155.2 4958 0 0 0 0 2.92 GLM 2 (Latch @ 10:00) I 155.3 4968 0.04 0.03 10 4 2.97 Pup 156 4975 0 0.02 9 2 2.94 I 157 5007 0 0.02 7 2 2.93 158 5038 0.04 0.03 11 2 2.95 159 5069 0 0.02 8 2 2.96 160 5101 0 0.02 9 2 2.94 I 161 5131 0 0.02 7 2 2.95 162 5163 0 0.03 12 3 2.96 163 5194 0 0.02 6 2 2.95 164 5225 0 0.02 8 2 2.96 1 165 5256 0 0.02 8 2 2.94 166 5287 0 0.03 10 2 2.95 167 5319 0 0.02 9 1 2.94 168 5350 0 0.02 7 2 2.96 I 169 5380 0 0.02 9 4 2.92 170 5412 0 0.02 9 2 2.94 171 5443 0.03 0.02 8 4 2.93 172 5474 0 0.02 9 4 2.95 173 5506 0.04 0.02 7 2 2.94 I 174 5536 0 0.02 9 3 2.95 175 5567 0 0.02 8 2 2.92 176 5599 0 0.02 8 2 2.96 177 5629 0 0.02 9 2 2.92 Lt. Deposits. I 178 5661 0 0.02 7 2 2.96 179 5692 0 0.02 8 2 2.95 180 5723 0 0.02 8 2 2.95 181 5754 0 0.03 10 2 2.93 Lt. Deposits. • I 182 5786 0.04 0.02 9 2 2.95 • 183 5816 0 0.03 11 4 2.93 184 5845 0 0.02 7 2 2.95 185 5877 0 0.02 8 2 2.94 186 5908 0.03 0.03 11 3 2.95 I 187 5938 0 0.02 7 4 2.94 188 5970 0 0.02 7 1 2.95 rat I Metal Loss ion Body I Page 4 Penet I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8RD ABMODWell: 2G -06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: November 28, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 189 6001 0 0.03 10 3 2.94 190 6032 0 0.03 11 2 2.95 191 6064 0.04 0.03 11 2 2.95 192 6095 0 0.03 11 4 2.90 Lt. Deposits. 193 6126 0 0.02 9 2 2.94 I 194 6157 0 0.02 7 1 2.95 195 6188 0 0.03 10 2 2.94 196 6219 0 0.02 8 2 2.95 196.1 6250 0 0.02 8 2 2.91 Pup Lt. Deposits. I 196.2 6259 0 0 0 0 2.91 GLM 3 (Latch @ 12:30) 196.3 6267 0 0.02 9 3 2.97 Pup 197 6276 0.03 0.04 18 3 2.94 Shallow Pitting. 198 6307 0 0.02 7 2 2.95 I 199 6338 0 0.02 9 2 2.94 200 6370 0 0.03 10 2 2.95 201 6401 0 0.02 7 2 2.95 202 6432 0 0.03 13 1 2.96 Shallow Pitting. 203 6463 0 0.03 11 5 2.94 I 204 6494 0.03 0.02 9 4 2.93 Lt. Deposits. 205 6526 0 0.02 9 2 2.96 206 6556 O 0.04 17 2 2.93 Shallow Pitting. Lt. Deposits. 207 6588 0 0.02 9 2 2.93 I 208 6619 0 , 0.02 8 2 2.95 209 6649 0 0.02 9 2 2.94 210 6680 0 0.02 9 4 2.93 211 6711 0 0.03 11 4 2.94 I 212 6743 0 0.02 7 2 2.94 213 6774 0 0.02 8 3 2.93 Lt. Deposits. 214 6806 0 0.02 8 2 2.92 215 6837 0 0.02 7 2 2.94 I 216 6868 0 0.03 11 2 2.93 217 6899 0.03 0.02 9 2 2.94 218 6930 0 0.02 9 4 2.94 219 6961 0 0.04 15 2 2.94 Shallow Pitting. 220 6991 0 0.04 17 2 2.93 Shallow Pitting. Lt. Deposits. I 221 7023 0 0.03 11 2 2.96 222 7054 0 0.03 10 2 2.93 223 7086 0 0.03 11 2 2.95 224 7116 0 0.03 11 4 2.94 I 225 7147 0.03 0.03 10 3 2.94 226 7177 0 0.02 8 2 2.93 227 7209 0.00 0.05 21 4 2.93 Isolated Pitting. Lt. Deposits. 227.1 7240 0 0.01 6 1 2.96 Pup I 227.2 7248 0 0 0 0 2.89 GLM 4 (Latch @ 9:30) 227.3 7257 0 0.03 11 2 2.95 Pup 228 7264 0 0.03 12 3 2.94 229 7296 0.03 0.03 11 2 2.93 Lt. Deposits. 230 7327 0 0.03 11 3 2.94 I 231 7359 0.03 0.03 12 2 2.95 Shallow Pitting. 232 7389 0.04 0.04 15 3 2.94 Shallow Pitting. I Metal Loss Body I Page 5 Penetration I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8RD ABMODWeII: 2G -06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: November 28, 2010 I Joint Jt. Depth Peen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body To Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 233 7421 0 0.02 9 1 2.96 234 7451 0 0.03 12 3 2.94 • 235 7484 0 0.03 10 2 2.96 ■ 236 7514 0 0.03 10 2 2.94 ■ 237 7545 0 0.02 9 2 2.95 • I 238 7576 0 0.03 12 2 2.95 Shallow Pitting. ■ 239 7608 0 0.03 10 2 2.93 Lt. Deposits. • 240 7638 0 0.05 20 2 2.94 Isolated Pitting. 241 7669 0 0.03 11 2 2.94 ■ ■11 I 242 7701 0 0.05 21 4 2.93 Line of Pits. 243 7732 0 0.02 9 1 2.96 244 7763 0 0.03 10 2 2.94 • 245 7794 0 0.02 9 2 2.94 ■ 2I 246 7825 0 0.02 9 2 2.96 ■ 247 7857 0 0.03 11 2 2.95 ■ 47.1 7888 0 0.03 10 2 2.97 Pup 247.2 7896 0 0 0 0 2.96 GLM 5 (Latch @ 10:30) 247.3 7904 0 0.03 13 3 2.96 Pup Shallow Line of Pits. ■ I 248 7913 0.04 0.06 24 3 2.91 Line of Pits. LL Deposits. ■■ 248.1 7944 0.03 0.06 22 3 2.93 Pup Line of Pits. Lt. Deposits. 248.2 7954 0 0 0 0 2.98 PBR Seal Assembly 248.3 7967 0 0 0 0 3.03 FHL Packer I 248.4 7974 0.03 0.03 10 6 2.93 Pup Lt. Deposits. • 249 7980 0 0.04 18 3 2.95 Shallow Line of Pits. • 249.1 8010 0 0 0 0 2.81 DS Nipple 250 8012 0.03 0.04 16 4 2.95 Shallow Pitting. I 250.1 8043 0 0 0 0 N/A End of Log Penetration Body Metal Loss Body I I I I I I Page 6 I I • • I PDS Report Cross Sections VS,,. I Well: 2G -06 Survey Date: November 28, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 10000429 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf L -80 EUE 8RD ABMOD Analyst: C. Waldrop I I Cross Section for Joint 248 at depth 7936.340 ft Tool speed = 49 Nominal ID = 2.992 I Nominal OD = 3.5 wall area = 98% /-- Tool deviation = 37° . I I i 1 / 1 I / I Finger = 24 Penetration = 0.061 ins Line of Pits 0.06 ins = 24% Wall Penetration HIGH SIDE = UP I 1 1 I I • 1 PDS Report Cross Sections ' Well: 2G -06 Kuparuk Survey Date: November 28, 2010 Field: Tool Type: UW MFC 24 No. 10000429 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 ' Tubing: 3.5 ins 9.3 ppf L -80 EUE 8RD ABMOD Analyst: C. Waldrop Cross Section for Joint 248.1 at depth 7951.150 ft Tool speed = 49 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 98% -- Tool deviation = 38° I r i ' Finger = 21 Penetration = 0.055 ins Line of Pits 0.06 ins = 22% Wall Penetration HIGH SIDE = UP 1 I,- KUP 2G -06 ConocoPhillips 3 = 11 Attribute Alaska. Inc n WM W1M lbore AP Weld Name Weft Status Ina ( °) hD Angle (RKB& ) MD TD Act Bun (NB) x / 500292112100 KUPARUK RIVER UNIT PROD 54.60 4,000.00 8,449.0 '" Comment H2S (ppm) Date Annotation End Date KBQd (11) Rig Release Date Well con69: - 2G - 0s 7/21rz010 12 48 PM SSW: NIPPLE 150 1/11/2009 Last WO: 7/14/2010 36.00 6/18/1984 smematic - Actual Annnotatlnn Depth (1603) Era bate Annotation aE MMod ... End Date Last Tag: SLM 8,038.0 11/25/2009 Rev Reason: GLV C /O, Pull Plug & Catcher Imosbor 7/21/2010 HANGER, 30 4 Casing Strings Casing Description String 0... String ID ... Top (RKB) Set Depth (L.. Set Depth (ND) ... String Wt_. String ... Sting Top Thra CONDUCTOR 16 15.062 38.0 110.0 110.0 62.58 HI440 Welded I , . Casing De r 9 ... Suing ... Top 37.2 Set Depth L. Set Depth (WV) ... Str6g M . St ring ... string Thrd 7 SURFACE scription St 95/8 0 8.765 ID 37.2 3,133.9 (I 2,773.9 36.00 J-55 B Top TC Casing Description String 0... Stang ID ... Top (NCB) Set Depth (r_. Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 35.9 8,449.1 6,223.8 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (11(B) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd I TUBING 2010 3 1/2 2.992 30.1 7,969.3 5,841.5 9.30 L-80 EUEBrdABMOD Completion Details CONWCTOR, Top Depth 3&110 (ND) Top Ind NOM... Top (111(8) ( 8 ) E) Rem Description Comment ID (m) -- 30.1 30.1 0.09 HANGER Vetco/Gray Gen II TUBING HANGER 2.938 I NIPPLE, 525 524.7 524.6 1.18 NIPPLE 3.5" Camco "DS" Nipple w/ 2.875 mile 2.875 7,956.6 5,831.7 39.63 PBR PBR Seal Assembly (sheared) w/ 2' space out STABBED INTO PACKER 2.980 Tubing Description String 0... String ID - Top (NCB) Set Depth (f... Set Depth (ND) ... String Wt... String _. String Top Thrd TUBING Packer Assy 31/2 2.992 7,965.9 8,043.6 5,899.3 9.30 L-80 8RD EUE Completion Details Top Depth I ! I GAS 951 k (TM Top Ind Nom... Top (NCB) ( B) PI keen Description Comment ID PM 7,965.9 5,838.8 39.53 PACKER FHL Packer 3.030 ;r. 8,008.7 5,872.5 39.12 NIPPLE 2.813" DS Nipple 2.813 I 8,041.1 5,897.4 38.70 SHOE 2 81 Snorlle MULE SHOE 3 - 1/2" EUE 2.980 I Tubing Description String 0... String ID ... Top (NCB) Set Depth (L.. Set Depth (1110) ... String ink... String ... String Top Thin TUBING 1999 31/2 2.992 8,042.0 8,081.3 5,928.7 9.30 L -80 EUEMOD Com Details Brd SURFACE Top Depth sore (T Top Ind Nont... EL Top (NB) MB) ( °) Item Description Comment ID (In) I 8,042.0 5,898.1 38.69 PACKER FHL RETRIEVABLE PACKER 2850 III GAS LIFT, 4,945 8,069.3 5,919.2 38.34 NIPPLE HES NIPPLE w /SELECTIVE PROFILE 2.750 8,080.6 5,928.1 38.20 WLEG WIRELINE ENTRY GUIDE 2.992 Other In Hole 'reline retrievable plugs, valves, pumps, fish, etc.) Top Depth i (ND) Top Intl GAS LIFT, Top (Itl(B) del ( °) Description Comment Date ID (In) 5.919.3 38.34 PLUG 2.75" PXX PLUG IN HES'X' NIPPLE 12/10/2007 0.000 [7:1 Perforations Sr Slots Shot I _ Top (PM) Btm (TVD) Dens LIFr, Top (NCB) Bhn (NB) ( B) ( T) zone Date Ism... Type Comment 7,2ae 8,188 8,198 6,013.3 6,021.3 A3, 2G-06 9/24/1988 4.0 IPERF 90 deg. Phasing; 4" Sc lumberger Casi 8,216 8,246 6,035.7 6,059.9 A -4, 20 -06 9/24/1988 4.0 IPERF 90 deg. Phasing; 4" Sch(umberger Casi I S AS I IFr Notes: General & Safety re9a End Date Annotation _ - 1/2/2000 NOTE: WORKOVER 12/10/2007 NOTE: WORKOVER 12/10/2007 NOTE: MIT TESTING WILL HAVE TO USE DS NIPPLE @ 8008' `" NI 1/5/2008 NOTE: CUTTBG TAIL POST WO DROPPED 97, COVERED WITH FILL @ 8159' SLM PBR, 7,957 =_ 7/2/2009 NOTE: 5005' = TIGHT SPOT, UNABLE TO WORK 2.6" GAUGE RING PAST 6/27/2009 a= 7/2/2009 NOTE: VIEW W /ALASKA SCHEMATIC 9.0 PACKER, 7,966 NIPPLE, 8,009 1 III I SHOE. 8.041 I I'''. P ACKER, 8,042 PLUG, 8,069 I1 III I NIPPLE. 8.069 • 111! ACES, 8.081 Mandrel Details Top Depth Top Port I (ND) and OD Valve Latch Size TRORon Stn Top (NCB) 0 ) (9 Male Mood (in) Sery 1Ype Type (In) (psi) Run Date Can_ 1 2,951.5 2,655.5 49.03 Camco MMG 1 12 GAS LIFT DMY R -20 0.188 1,271.0 7/19/2010 2 4,945.5 3,852.0 53.27 Camco MMG ' 1 12 GAS LIFT GLV R -20 0.188 1,265.0 7/19/2010 8,188-81 8 i 3 6,250.3 4,646.5 52.51 Cameo MMG 1 12 GAS LIFT GLV R -20 0.188 1,256.0 7/18/2010 I 4 7,246.0 5,310.9 45.76 Cameo MMG 1 12 GAS LIFT GLV R -20 0.188 1,245.0 7/18/2010 IPERF. 8.2185.246 , 5 7,898.2 5,786.8 40.24 Cameo MMG 1 12 GAS LIFT OV rdo20 0.250 0.0 7/18/2010 ITO. 8,449 PRODUCTION. A 38 -8,449 ■ I WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cutting Torch Record /Tubing Punch Record: 2G-06 Run Date: 7/10/2010 August 11, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2G06 ~ .. ~C`}?~ r , ~.. ~~ Digital Data in LAS format, Digital Log Image file~~''Y~~ ' "&~ ' ~~ ~` 1 CD Rom 50-029-21121-00 ~~/-or~~ ~ce~`f PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@ Date: ~~iG a ~~2~~~ tin . Signed: STATE OF ALASKA ALASK~ AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Repair w ell ~`' Rug F~rforations ~'°"" Stimulate ~' Other ~"'` Alter Casing Pull Tubing ~ Perforate New Fbol ~ Waiver Time Extension ~"° Change Approved Program ~"°' Operat. Shutdown ('°" Perforate Re-enter Suspended Well ~" 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~° Exploratory ~"""` 184-082 3. Address: Stratigraphic Service 6. API Number: ' P. O. Box 100360, Anchora e, Alaska 99510 ~ 50-029-21121-00 7. Property Designatign: 8. Well Name and Nunyber: ~~ ADL 25656 2G-06 9. Field/Pool(s): ~ Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8485 feet Plugs (measured) 8009', 8069' true vertical 6253 feet Junk (measured) none Effective Depth measured 8368 feet Packer (measured) 7966, 8042 true vertical 6158 feet (true vertucal) 5839, 5898 Casing Length Size MD ND Burst Collapse CONDUCTOR 72 16 110 110 SURFACE 3097 9.625 3134 2774 PRODUCTION 8413 7 8449 6224 ~A ~-` ~+~ Perforation depth: Measured depth: 8188'-8198', 8216'-8246' ~~ ' ' `~ `~ ` True Vertical Depth: 6013'-6021', 6036 -6060 ~1~ttS~tB ~ ~,'1~4i~ . ~.' , ~ ~ °~t ~'0~'~~f'"~f" Tubing (size, grade, MD, and TVD) 3.5, L-80, 8081 MD, 5928 TVD Packers & SSSV (type, MD, and TVD) PACKER -FHL RETRIEVABLE PACKER @ 7966 MD and 5839 TVD NIPPLE - 3.5" CAMCO DS NIPPLE W/2.813" @ 8009 MD and 5872 TVD PACKER -FHL RETRIEVABLE PACKER @ 8042 MD and 5898 TVD NIPPLE - 3.5" HALLIBURTON "X" NIPPLE W/2.75" SELECTIVE @ 8069 MD and 5919 TVD NIPPLE - 3.5" Camco "DS" Nipple w/ 2.875 profile @ 525 MD and 525 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable _~ ,~~~j ~~ j• r~~ ~ I ~ `-' ~ ~j ~(, Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation si Subsequent to operation 78 600 1073 - 127 13. Attachments 14. Well Class after proposed work: \~ Copies of Logs and Surveys run E~loratory Development ~` Service ~'"` 15. Well Status after work: it ;~ Gas WDSPL Daily Report of Well Operations XXXX GSTOR ~ WAG ~ GASINJ ~"" WINJ ~ SPLUG "` 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Nh4 if C.O. exempt: none Contact Erik Nelson... 263-4 Printed Name Erik N '`~n Title Wells Engineer Phone: 263-4693 Date // ~~/1 Signature ~ ~ Form 10-404 Revised 7/2009 ~ ~BC'I~AS AUG 1'2 ZO'~ Submit Origin Only~~ tZ -/a ~/ _~,, - KUP - 2G-06 ., ! ~Qr]('~[{)Ph~~ll~~ { - '; Well Attnbutes _ __ (Max Angle & MD TD _ Fa ' ' ~ I Wellbore APUUWI IF;eltl Name (Well Status lncl (') MD (ftK6) Act Bbn (ftK8) ~ // ~ 500292112100 .. ~.. KUPARUK RIVER UNIT __ (PROD 54.60 4,000.00 8,449.0 C ment ~SSSV NIPPLE ~ H2S(ppm) (Date 150 1/11/2009 Annotalion IEnd Date KB-Grd (ft) Last WO: 7/14/2010 36 00 IRigR lease Data 1 6!18/1984 „V9au pAnfig,.,-,2G fis n ~~ ~ - ~ ~ - _ ~~2tiiu ~A i . . t M L 1 d E d D t __ $chema[K Act _ notahon (Dep al Last Tag: SLM 8 ~ th (ftK8) IEnd Date (Annotat on .038.0 11/25/2009 Rev Reason: ( as WORKOVER Imos .. I n O a e bor //18/2010 HANGER so -- -_ _ . -' Casing Stnn s , - "' Casing Descnption String 0... String ID ... Top (kK8) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 110.0 1100 - 62.58 ~, H-00 Welded Casing Description String 0... String ID ... Top (ftK6) Set Depth (f... Set Depth (ND) .'String Wt...String ._ _ String Top Thrd SURFACE 95/8 8.765 37.2 3,133.9 2,773.9 36.00 ~ J-65 '~ BTC ;! Casing Description (String 0... String ID ... Top (ftK6) Set Depth (f... Set Depth (ND) (String Wt... St ing ._ String Top Thrd PRODUCTION 7 6.151 35.9 8,449.1 J-55 6,223.8 26.00 BTC j Tubing Strings . _ _ " Tubing Descnption String 0... String lD ... TOp (ftK8) String Wt...Strmg ... ( Set Depth (i... Set Depth(ND). String TOp Thrd TUBING 2070 ( l 31/2 1 2.992 30.1 ( ( 7,969.3 5841.5 9.30 L-80 35 Com letion Det ails _ __ coNDUCroR, __ rop Deptn 38-1 t0 (ND) Top Inc! Nomi.. Top (ftK6) (ftK6) (°) ~ Item D scription Cwnment ID (in) 30.1 30.1 0.09i HANGER Vetco/Gray Gen II TUBING HANGER 2.93£ NIPPLE 525---- ~ 624J 524.6 1181 NIPPLE 3.6"Cameo "DS"Nloole w/2875 orofle 2.87r- GAS LIFT. 2,951 SURFACE, 3]-3.13a GAS LIFT, 6,965 GAS LIFT,_ __.. 6,250 GAS LIFT. __. _. ],246 GAS LIFT, PBR, 7,95]- PACKER, ],566 - CATCHER,- B,00] NIPPLE, 8,009-- PLUG.8.U09- SHOE, 8,061 - PACKER.8.062- PLUG, 8,Ofi9 NIPPLE. 8,069 - WLEG, 8.081-- - IPERF. _- 8,188-8.198 3.61 5,831.71 39.63PBR PBR Seal Assembly (sheared) w/ 2' space out 51 ABBED IN I O PACKLH 2. Description (String 0... (String ID ... Top (ftK8) Set DepM (f... Set Depth (ND) ... String Wt.. String ... String Top Thr G Packer Assv 3 1/2 i 2.992 7.965.9 8.043.6 5.899.3 930 L-80 ~ 8RD EUE 8,008.71, 5,872.5 39.12 NIPPLE 12.813" DS Nipple 2.813 8,041.1,1. 5,897.4 38.70 SHOE 2 ft Snorkle MULE SHOE 3-112" EUE _ 2 980 ubing Descnption (String 0... String ID ... Top (ftK8) Set D pth (f Set Depth (ND) .. -String Wt... Str ng ._ Stri g Top Thrd TUBING 1999 'I 31/2 2.992 I 8,0420 I 8081 3 -(__...._5,928.7 ;_ 9.30. L-8~ EUE8rdMOD Completion Det Top Depth._ ails _ ____ __ __ ...___..__. _.. _ _ _._ (ND) lop Inc! Nomi... fop (ftKBJ' (kK8) (°) Item Description Comment ID (in) 8,0420 5,898.1 38.69 PACKER i FHL RETRIEVABLE PACKER 2.850 8,069.3 5,919.21' 38.34 NIPPLE HES NIPPLE w/SELECTIVE PROFILE 2.750 ( 8,ORO.fi 5,928.1 38.20WLEG WIRELINE ENTRY GUIDE - _ 2.992 . Dther In Hole~ - __ Wireline retrievablylugs, valves,pumps, fish, etc. __ __.. - Top Depth (TVD) Top Inc! fop (kK8) (ftK6) (°) Description Comment Run Date ID (in) 8,007 5 871.2 39.14ICATCHER AVA CATCHER SET ON PLUG 6/9/2010 0.000 8,009 5,872.5 39.12~PLUG 2.81"CSA-2 PLUG 6/9/2010 0.000 8,069 5,919.3 38.341PLUG 2.75" PXX PLUG IN HES'X' NIPPLE 12/10/2007 0.000 Perforations & Slots snot Top (TVD) Btm (TVD) Dens rop (ftK6)', Btm (ftK8) (ftK6) (ftK6) Zone Date (sh--~ Type Comment 8,188 8,198 ' 6,013.3 6,0213 A-5, 2G-O6 9/2411988 ~ 4.O IPERF 90 deg. Phasing; 4" Schlumberger ( i Casi $2161 8,246 6 035.7 6,059.9 A-0, 2G-06 9/24/1988 ~, 4.01PERF 90 deg. Phasing; 4" Schlumberger Casl 12/10/2007 iNOTEt WORKOVER - - 12/10/2007 NOTE "` MIT TESTING WILL HAVE TO USE DS NIPPLE @ 8008""' 1/5/2008 NOTE CUT TBG TAIL POS T WO DROPPED 9T, COVERED WITH FILL @ 8159' SLM 7/2/2009 (NOTE 5005' =TIGHT SPOT, UNABLE TO WORK 2.6" GAUGE RING PAST 6/27!2009 7/2/2009 (NOTE VIEW W/ALASKA SCHEMATIC 9.0 landrel D etails - _ Top Depth Top _ - Port _-- - (TVD) Inc! OD Valve Latch Size TRO Run '.n Top (ftK8) (ftK6) (°) Make Model _ (n) Serv Type Type (in) (psi) Run Dahl Com 1 2,951.5 2,6555 49.03 Cameo MMG 1 1/2 GAS LIFT DMY RK-5 0.000 0.0 7/13/2010 2 4,945.5 3,852.0 53.27 Cameo MMG 1 12 GAS LIFT DMY RK-5 0.000 0.0 7/13/2010 3 6 250.3 4,646.5 52.51 Cameo MMG 1 1/2 GAS LIFT DMY RK-5 0.000 0.0 7/13/2010 4 7,246.0 5,310.9 45.76 Cameo MMG 1 1/2 GAS LIFT DMY RK-5 0.000 0.0 7/13/2010 5 7,898.2 5,186.8 40.24 Cameo MMG 1 1/2 GAS LIFT SOV RKP 0 000 0.0 7/13/2010 TD, s.a69 PRODUCTION, 36-8,6J9 ' 2G-06 Pre and Post Workover Events DATE SUMMARY 5/24/10 (PRE RWO) T-POT (PASSED), T~POT (PASSED), IC-POT (PASSED), IC-P OT (PASSED), FUNCTION TEST LDS'S 6/8/10 PULL 2.81" CSA-2 PLUG @ 8009' RKB. TAGGED @ 8046' SLM. MEASURED SBHP @ 8000' RKB. SET 2.81" CSA-2 PLUG @ 8009' RKB. ATTEMPT DRAWDOWN TEST, NO SUCCESS. PULL EQ. PRONG @ 8009' RKB. IN PROGRESS. 6/9/10 SET 2.81" CSA-2 PLUG @;8009' RKB. SET CATCHER @ 8009' RKB. PULL DV @ 7929' RKB. 7/10/10 CUT 3.5" TUBING @ 7938.5' TUBING PUNCH BELOW CUT@7949' ~'~ e~ ~~y 7/17/10 PULLED SOV @ 7898' RKB. IN PROGRESS. 7/18/10 CIRC IA TO DSL. PULLED DVs @ 4945', 6250, AND 7245' RKB. SET OV @ 7898', AND GLVs @ 7245' & 6250' RKB. IN PROGRESS. 7/19/10 PULLED DV @ 2951' RKB. SET GLVs @ 2951' AND 4945' RKB. BAILED FILL FROM 7985' TO ~° 8000' RKB. PULLED AVA CATCHER @ 8007' RKB. IN PROGRESS. t`~ 7/20/10 BAILED FILL AND PUL_LED_2.81 CA-2 PLU_G_ ~ 8009' RKB TAGGED FISH la 8042' SLM_ COMPLETE. • " Time Log & Summary ConocoPhillilas vv~„.„~~., v„z~ R~pom~g Report Well Name: 2G-06 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 7/9/2010 12:30:00 PM Rig Release: 7/14/2010 4:00:00 AM Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 7/07/2010 24 hr summary Road Nordic Rig 3 from 1J Pad to 08:00 12:00 4.00 COMPZ MOVE MOB P Road Nordic Rig 3 from 1J-Pad to s ine road 12:00 14:30 2.50 COMPZ MOVE MOB P Move from 1J Pad access road to KOC -circus tent 14:30 17:00 2.50. COMPZ MOVE OTHR P Standby with crews while KDTH suffles ri mats ahead of ri 17:00 19:00 2.00 COMPZ MOVE OTHR X Standby with crews while KDTH suffles rig mats ahead of rig and for Ku aruk feild crew chan e 19:00 00:00 5.00 COMPZ MOVE MOB P Continue with Rig Move. Just passing the 2 Z-Pad access road at midni ht 7/08/2010 Continue with Rig move to 2 G Pad 00:00 03:30 3.50 COMPZ MOVE MOB P Continue moving Rig towards 2 G-Pad. Rig at CPF-2. Move rig Mats 03:30 05:30 2.00 COMPZ MOVE MOB P Continue moving Rig to 2G-Pad Access Road turn-off. 05:30 00:00 18.50 COMPZ MOVE MOB P Moved 1.0 miles. Rig mat two step to 2G -Pad 7/09/2010 Shuffle mats and continue to move towards 2G Pad. MIRU. Circulate Well w/9.6 ppg Brine. Set BPV. ND Tree. 00:00 06:00 6.00 COMPZ MOVE MOB P Continue towards 2G Pad. Continue to shuffle ri mats. 06:00 12:30 6.50 COMPZ MOVE MOB P Up-date at 06:00 hrs, need to move Rig Mats 1.5 more times. Rig close to entering Pad. Accept Nordic Rig 3 @ 12:30hrs on 7-9-10 12:30 13:00 0.50 COMPZ MOVE OTHR P Load Tree in Cellar 13:00 15:00 2.00 COMPZ MOVE RURD P MIRU Nordic Rig 3 on 2G-06. Set down and Berm up. Spot auxilary e ui ment. 15:00 16:00 1..00 COMPZ WELCTL MPSP P Lubricate out BPV. Open up well .and Obtain pressures. 0 psi TBG, 75 si IA, 280 si OA ressure. 16:00 19:00 3.00 COMPZ WELCTL OTHR P Rig up lines. Start to load Pipe Shed with 3 1/2" Completion Tubing. Load Pits with 9.5 heavy Ib/gal Brine. Test Lines at 250/3,900 si. Good test. Page l of 5 l~ • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 19:00 22:30 3.50 COMPZ WELCTL CIRC P Begin to circulate Well with 9.5 Ib/gal , Brine down the Tubing at 4.0 h eavy _ _ bpm 1,090 psi taking returris through the choke to the Tiger Tank holding 100 psi back pressure. After 30 bbls away Tubing pressure suddenly fell to 70 psi (?). Continue to circulate at 4.0 bpm. Returns =diesel. After most of the diesel from the Annulus was recovered the Tubing pressure gradually started to build as the havier Brine was being lifted in the Annulus. Finial circulating pressure was TP = 460 psi, IA = 90 psi. Pumped a total, of 312 bbls (calculated volume from the GLM with an open pocket was 278 bbls). Returns weighed 9.2 ppg heavy. Monitor Well and let any remaining lite fluids rise to the top. Off load final Vac Truck into Pits. Bring Pump back on line at 4.0 bpm at 470 psi and pumped 40 more bbls to clean up remaining lite fluids. Final weight = 9.5 Ib/gal heavy. Monitor Well Static. Blow down lines. 22:30 00:00 1.50 COMPZ WELCTL NUND P et BPV. Nipple down Tree. S _ Inspect top Hanger threads. Install Blankin Plu . 7/10/2010 Nipple up BOPE. Test BOPE. Attempt to pull Seal Assembly free. Rig up E-Line to Cut Tubing. 00:00 03:30 3.50 COMPZ WELCTL NUND P Rig up test e ui ment. 03:30 09:00 5.50 COMPZ WELCTL PRTS P Perform initial BOPE test at 250/4,500 psi. The State's right to witness test was waived by C. Scheve. 09:00 10:00 1.00 COMPZ WELCTL MPSP P Pull Test plug and BPV., 10:00 10:30 0.50 COMPZ RPEOPI OTHR P MU landing pups and BOLDS. 10:30 11:30 1.00 COMPZ RPEOPI PULL P ,mod TBG han er 90k and Pull 50k OSW (4'), Work TBG and attempt to work seals from PBR - No luck. Pull to 140k and Circulate @ 9 bpm @ 1,120 psi -not able to h drualic seals from PBR. 11:30 12:30 1.00 COMPZ RPEOPI OTHR P Land hanger and RILDS. Back out landing pups, add 4' pup for space out. MU landing pups and BOLDS. Pull to 120k - 30k osw. Land in slips and RU for Eline. Page 2 of 5 ~~ l • Time Lo s Date From To Dur S. De th E. De th Phase Cnde 5ubcode T Comment 12:30 22:30 10.00 COMPZ RPEQPI ELOG P Call out E-Line Unit. Spot Unit. PJSM. Configure Tool String to anchor above GLM at 7,928-ft and make a tubing cut in the Pup Joint below the GLM at 7,938-ft. Test mechanical anchor on surfade and had trouble opening the arms. The spare anchor did the same thing. Discuss problem with Anch Eng and Halliburton Eng. Decided to use a Pressure Balance Anchor. Order a tubing punch to punch a hole below the cut de th. 22:30 00:00 1.50 COMPZ RPEQPI ELOG P RIH with a Tubing Punch. Log tie-in pass and corelate to the GLM Assembly at 7,246-ft. Make a (-) 3-ft correction. Drop down to 7,980-ft . Log up and position the Tubing Punch to "punch" at 7,949-ft in the middle of the lower Pup Joint. Fire Tubin Punch. Good. Start POOH. 7/11 /2010 Cut Tubing at 7,938.5-ft using the Halliburton Rotary Torch Cutter on E-Line.. Lay down 3 1!2" Completion. Load PI a Shed with 3 1/2" Drill Pi e. 00:00 00:30 0.50 COMPZ RPEQPI ELOG P Finish POOH with Tubing Punch. Tubin Punch fired. 00:30 03:00 2.50 COMPZ RPEQPI ELOG P Re-configure Tool String and pick up Rotary Torch Cutter. RIH. Tie into ssembly aaaiagain at 7.246-ft. _. Make a (+) 4-ft correction. Drop down hole and log RTC into place to cut in the bottom Pup Joint of the bottom GLM. Fire RTC and cut at _7 938 5-ft. Good.. Jarred Pressure Balance anchor free after 4 Jar c cles: POOH. RTC fired normal. 03:00 04:00 1.00 COMPZ RPEQPI ELOG P Rig E-line off of Well. Pick up on Completion String. Tubing free. Pull Tubing Hanger to floor with normal expected string weight of 95K. complete E-Line rig down and prep to sin le down 3 1/2" Com letion. 04:00 13:00 9.00 7,939 0 COMPZ RPEQPI PULD P Single down 3 1/2" Completion in Pipe Shed. Lay down 248 jts, 5 - GLM, 1- 2.875" DS Nipple. Recovered 1.92' of 3 1/2 TBG stub. 13:00 14:00 1.00 0 0 COMPZ RPEQPI OTHR P Clean and clear rig floor and pipe shed of decompletion. Change over to DP a ui ment. 14:00 19:00 5.00 0 0 COMPZ RPEQPI OTHR P Load, rack and Tally 245 jts 3 1/2 DP and 6 - 4 3/4" OD DC's 19:00 21:00 2.00 0 217 COMPZ RPEQPI FISH P Make up BHA #1 as follows: 5 3/4" Drag Tooth Shoe, Extension, Extension, Double Pin Bushing, Overshot Bowl (w3 1/2" Spiral. Grapple nominal. Catch range 3 7/16" - 3 9/16"), Top Sub, Bumper Sub, Oil Jar, 6 ea 4 3/4" Drill Collars. P=:tle 3 .:` ~~ a Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 21:00 00:00 3.00 217 2,300 COMPZ RPEQPI FISH P RIH with BHA #1 with single 3 1/2" Drill Pi a from Pi a Shed. 7/12/2010 Jar Seal Assembly free. TOOH. RIH with 3 1/2" Mule Shoe and clean out PBR/Pkr Bore. POOH and lay down 3 1/2" Drill Pi e. 00:00 05:30 5.50 2,300 7,938 COMPZ RPEQPI FISH P Continue to RIH with BHA #1 and single in 3 1/2" Drill Pipe from Pipe Shed.. Up Weight = 137K. Down Wei ht = 87K. 05:30 06:00 0.50 7,938 7,948 COMPZ RPEQPI FISH P Wash over the 3 1/2" Stump (Jt # 240) at 8,4 bpm/1,870 psi. Wash through soft fill down to 7,948-ft. Swap around to reverse circulate two lus Drill Pi a volumes at 06:00 06:30 0.50 7,948 7,952 COMPZ RPEQPI WASH P Continue to wash over @ 5 bpm @ 710 psi to 7,952'. Set 20k down and Engage grapple ~ 7,940'. PU and - bleed jars and Pull 40k osw of 137k and seals ulled free. 06:30 07:30 1.00 7,952 7,932 COMPZ RPEQPI CIRC P Reverse Circulate 30 bbl hi visc sweep and chase out @ 8 bpm @ 1,950 si. Blow down To drive. 07:30 10:30 3.00 7,932 218 COMPZ RPEQPI TRIP P Trip out w/ 240 jts 3 1/2 DP from 7,932' to 218'. 10:30 11:30 1.00 218 0 COMPZ RPEQPI PULL P Stand back DC's, Release Overshot from seal assy and lay down tools and fish. 11:30 12:30 1.00 0 0 COMPZ RPEQPI OTHR P Clean and clear rig floor. pre load next BHA into i e shed. 12:30 13:30 1.00 0 213 COMPZ RPEQPI TRIP P PU and MU 3 1/2 IF Mule shoe and RIH w/ 6 - 4 3/4" OD dc's to 213-ft. 13:30 16:30 3.00 213 7,969 COMPZ RPEQPI TRIP P Continue to RIH from 213-ft to 7,969-ft. PU 2-ft. 16:30 18:00 1.50 7,967 7,967 COMPZ RPEQPI CIRC P Pump 30 bbl high visc sweep and Reverse out @ 8 bpm @ 1,950 psi. Blow down lines and To Drive. 18:00 00:00 6.00 7,967 1,430 COMPZ RPEQPI PULD P PJSM. POOH and single down 3 1/2" Drill Pipe in Pipe Shed from 7,967-ft to 1,430-ft. 7/13/2010 Finish laying down 3 1/2" Drill Pipe. Located PBR, PU & Circulated Corrosion Inhibited Seawater. Landed Completion. PT Tubing & IA. ND BOP's. NU & Tested Tree and Packoffs to 250/5000 psi. Pulled Two-Way Checks. 00:00 02:00 2.00 1,400 0 COMPZ RPEQPI PULD P Complete laying down 3 1/2" Drill Pipe, Drill Collars, and Mule Shoe Joint. 02:00 03:00 1.00 0 0 COMPZ RPCOM RURD P Clear and clean Floor. Rig up to handle 3 1/2" Tubing. Perform final 'ewel ins ection. 03:00 09:30 6.50 0 7,970 COMPZ RPCOM PULD P Pick up Seal Assembly, 1 Joint of 3 1/2" 9.3 Ib/ft L-80 EUE 8rd Tubing, Camco 3 1/2" X 1 1/2" MMG GLM Assembly w/SOV. Continue picking , u~ 3 1/2" Gas Lift Completion ac desi ned.. No 0 7,970-ft. 09:30 10:30 1.00 7,970 7,945 COMPZ RPCOM HOSO P PU and Space out for 2' off of No go. MU TBG han er. ~- -- ~ - --- - uge 4 ~.. '-- Time Lo s ,..Date From To Dur S. De th E. De th Phase Code Subcode T Comment 10:30 14:00 3.50 7,945 7,945 COMPZ RPCOM CRIH T Wait for Vac trucks to deliver 270 bbls CI Sea water and 100 bbls of Sea water. Displace 9.6 ppg Brine with 70 bbls of Sea water and Follow with 270 bbls of CI Sea water, followed by 10 bbls of Sea water. Circulating @ 5 bpm @ 340 psi ICP and 560 si FCP. 14:00 15:00 1.00 7,945 7,968 COMPZ RPCOM THGR P Land TBG hanaer and RILpS Close pipe rams and PT TBG hanger void @ 250 for 10 min. and 5,000 psi for 10 min. as 7 1/16" 5M x 11" 3M TBG s ool has no test ort. 15:00 17:00 2.00 7,968 7,968 COMPZ RPEQPI PRTS P RU and Test TBG @ 2,500 psi for 15 minutes and Bleed back to 2,000 psi. Press IA up to 2,500 psi for 30 min. Bleed IA, then TBG and Pressure. up to 2,000 psi and shear out SOV. RD test equipment and ulllandin 't. 17:00 18:00 1.00 7,968 COMPZ WELCTL MPSP P Set Two way check. 18:00 19:30 1.50 COMPZ WELCTL NUND P Drain stack, ND BOP 19:30 21:30 2.00 COMPZ WELCTL NUND P NU "New" 3 1/8" 5M x 7 1/16" Production tree. 21:30 22:30 1.00 COMPZ WELCTL PRTS P PT tree @ 250 / 5,000 and chart. 22:30 23:00 0.50 COMPZ WELCTL MPSP P Pull BPV 23:00 23:15 0.25 COMPZ WELLPF SFTY P Held PJSM with LRS and Rig crew on Freeze rotectin . 23:15 00:00 0.75 COMPZ WELLPF FRZP P RU LRS and start pumping 70 bbls of diesel down the IA. 7/14/2010 Freeze Protected Tubing x IA w/ Diesel. Set BPV. RDMO. 00:00 01:30 1.50 COMPZ WELLPF FRZP P Completed pumping operation.RD LRS. Allow well to utube. 01:30 02:00 0.50 COMPZ MOVE DMOB P R/D Hoses. Set BPV 02:00 03:00 1.00 COMPZ MOVE DMOB P Dres Tree. Prep rig F/Move 03:00 03:30 0.50 COMPZ MOVE DMOB P Move Rig Off Well. Load T-Mats. 03:30 04:00 0.50 COMPZ MOVE DMOB P Clean Up Around Rig Locations. Release Nordic Rig #3 @ 04:00 hrs on 7-14-2010 r:,~:," 5 of 5 • UIlELL LQG S Tf~4NSlI~ft7TAL PnoAcrive DiAgNOSric SeevicEC, INC. Ta: 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/ MTT) 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 ~ ~d~ 130 West International Airport (j~,.~" ~~ ~ ~a Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1) Caliper Report 09-Dec-09 26-06 2j ~~i~ Signed Print Name: 1 Report/ EDE 50-029-21121-00 Date ~, ~' ~ ~'' PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~_ _ ,_, _ ____, _~ WEBSITE ° ._~~~ _ C~.~Decuments and Settings\IJiane Williams\Desktop\Transmit_Conoco.docx ~~ • • Memory Multi-Finger Caliper Log Results summary Company: ConocoPhillips Alaska, Inc. Well: 2G-06 Log Date: December 9, 2009 Field: Kuparuk Log No.: 6780 State: Alaska Run No.: 3 API No.: 50-029-21121-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8RD ABMOD Top Log Intvl1.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 8,002 Ft. (MD) ', ~ Inspection Type : Corrosive & Mechanical Damage Mspection COMMENTS III ` This caliper data is tied into the top of GLM 5 @ 7,928. T (Tubing Detail dated: December 7, 2007). 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 logged is in good to poor condition, with probable holes recorded in joints 113 (3,607') and 107 (3,395'). Wall penetrations ranging from 40% to 83% wall thickness are recorded in 43 of the 265 joints logged. Recorded damage appears as a line of pits and line corrosion from _1,950' to -4,600`, with intermittent areas of shallow corrosion and scattered pitting recorded throughout the tubing. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. The caliper recordings indicate slight buckling from 4,600' to 7,950'. ' A 3-D log plot of the caliper recordings across the probable holes is included in this report. This is the third time a PDS caliper has been run in this well and the first time this 3.5" tubing has been logged. ' MAXIMUM RECORDED WALL PENETRATIONS: Probable Hole (98%) Jt. 113 @ 3,607 Ft. (MD) Probable Hoie (95%) Jt. 107 @ 3,395 Ft. (MD) Line corrosion (83%) Jt. 100 @ 3,194 Ft. (MD) Line corrosion (82%) Jt. 131 @ 4,170 Ft. (MD) Line corrosion (78%) Jt. 120 @ 3,798 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 13%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. ' ~~t~ ~ ~ Z~~d i~ Field Engineer: N. Kesseru Analyst: C. Waldrop Witness: C. Fitzpatrick ~' ProActive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (28I) 565-1359 E-mai!: PDS~memory!og.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~ .~~ - o~ a , ~ ~~a • PDS Multifinger Caliper 3D Log Plot ~, _ , Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2G-06 Date : December 9, 2009 Description : Detail of Caliper Recordings Across Probable Holes (3,395' & 3,607 Comments Depth Max. Pen. (%) Max. I.D. (ins.) 3-D L 1 ft:240ft ' ~ - ,~ 0 100 2.5 3.5 34° Min. I.D. (ins.) 2.5 3.5 Nominal I.D. (ins.) 2.5 3.5 Joint 105 ~ i 3360 ~ .~~ ~ .~ -_ ~~' Joint 106 - -- - Line Corrosion 3370 I ,..:_ ~'! _ ~.,,_ .._ - - - 74% Wall - y Penetration 3380 i ~~; - __ - - 3390 - __.. . _,..~ Joint 107 .,. ~" ~" 3400 Probable Hole .~+-.-~- (3,395') ~ _. ~_,.. ,,~ s5% wall 3410 _ -- Penetration ' -~~_ -=~= 3420 . __ ~ _ - v., - _ Joint 108 3430 ~`~ ~ 4 Line Corrosion ._ ,~_. ,.. 54% Wall ~ - 3440 Penetration ~ I ~ ,_ .~ 3450 .... - _. - Joint 109 3460 -e... Line Corrosion . °°- ~ ` 39% wall 3470 ..:..~... Penetration i -~ '^~ p ~ ~' 3480 ~ Joint 110 I = __ ~., 3490 ! Line of pits R .tl _~ :. -., ~ 3500 ~- . 0° 90° 180° 270° 0° I • 28% Wall T +~ - " _" Penetration II_,__ _ 3510 s ~_ - -I a 3520 Joint 111 ., Line Corrosion I 3530 - 57% Wall ~ ~ ~ ~ Penetration z ' _ I " _ ~ ~ 3540 . - ~ - ~: .: _ . T_ 3550 3 Joint 112 ' ~ :. _ Line Corrosion 3560 :. , 54 /° Wall ~ ~ -_ _ Penetration m~" ~ - ~ 3570 ~ ~ :~ ~' _. ~` 3580 Joint 113 ~. ' Probable Hole 3590 ~ ~ I (3,60T) ._~ 98% Wall _.~~ - ° - Penetration 3600 ~ --- 3610 " . ~.._T ~ _ Joint 114 I ~; 3620 Line Corrosion 67% Wall -~ °~`, . ~ Penetration 3630 ~~ .: ~, ~ _ r ~: _ _ --- ~.~. ~ =~ ~ -T»~ 3640 ,. _. Joint 115 I ( 'I _- ~ ~. Nominal t.D. (ins.) 2.5 3.5 Min. I.D. (ins.) 2.5 3.5 Comments Depth Max. Pen. (%) Max. I.D. (ins.) 3-D Log Image Map 1ft:240R .O__._ 100 2.5 3.5 34° 0° 90° 180° 270° 0° • Correlation of Recorded Damag Pipe 1 3.5 in (2.8' - 7978.8') Well: Field: Company: Country: Survey Date: • ;e to Borehole Profile 2G-06 Kuparuk ConocoPhillips Alaska, Inc. USA December 9, 2009 A pprox. Tool De viation ^ A pprox. Borehol e Profil e 1 7 25 ~ 788 50 1571 75 2355 GLM 1 100 3169 -9 E 125 ii 3952 ~ ~ •- Z t c Q- v GLM 2 0 150 ~ 4763 175 5545 GLM 3 200 6357 22 ' ~ 7142 _ GLM 4 - GLM 5 249 7979 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 249 • • PDS Report Overview ~~,. ~,, Body Region Analysis Well: 2G-06 Survey Date: December 9, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st; C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 EUE 8RD ABMOD '2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~j metal loss body 300 250 200 150 100 50 0 D to 1 to 10 to 20 to ~ 40 to over 1% 10%° 20% 40% 85% 85% Number of ~oints anal sed total = 265 gene. 0 51 130 39 43 2 loss 5 259 1 0 0 0 Damage Configuration (body ) 100 80 bi) 40 20 0 isolated general line nng hole/poss pitting corrosion corrosion corrosion ible hole Number of'oints lama ed total = 180 87 33 58 0 2 Damage Profile (% wall) ~ penetration body , , ,metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 Bottom of Survey = 249 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD ABMODWeII: 2G-06 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: December 9, 2009 Joint No. Jt. Depth (Ft) I'E,n. l lhsF°t (ln~.) Pen. Body (Ins.) Pen. °~<, 'vtetal I oss °<~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 3 U 0.04 15 2.93 PUP Shallow corrosion. 1 7 U 0.03 12 2.96 1.1 38 t~ 0.04 14 ; 2.92 PUP Shallow corrosion. 1.2 49 U 0.04 L5 2.93 PUP Shallow ittin . 1.3 57 t~ 0.03 10 1 2.93 PUP 2 67 t~ 0.03 1.s 4 2.96 Shallow ittin . 3 98 (~ 0.03 1 I a 2.95 4 129 ii 0.03 1tr ! 2.96 5 161 U 0.03 1 U -t 2.95 6 192 it 0.04 14 ~ 2.93 Shallow ittin . 7 223 tr 0.04 14 5 2.94 Shallow corrosion. 8 255 l~ 0.03 12 3 2.94 9 286 l) 0.04 15 ? 2.94 Shallow ittin 10 317 c ~ 0.03 1 'I 4 2.94 11 349 t~ 0.03 13 2.95 Shallow ittin . 12 380 i) 0.04 1 ~, 2.95 Shallow ittin . 13 411 ti 0.01 ~ _' 2.95 14 443 t? 0.04 1 ~ 2.96 Shallow ittin . 15 474 (~ 0.03 1 1 2.96 15.1 506 i) 0 (1 t~ 2.88 3.5" DS-Ni le 16 508 t r 0.01 3 ~' 2.96 17 538 tt 0.01 ? U 2.95 18 569 t ~ 0.02 9 2.97 19 600 (1 0.03 11 4 2.96 20 631 t) 0.02 ~i 4 2.96 21 662 t ~ 0.02 9 _' 2.93 22 693 (1 0.01 3 _' 2.93 23 725 i> 0.03 I i 2.93 24 756 i! 0.03 I ; -? 2.93 Shallow corrosion. 25 788 U 0.04 I' -1 2.93 Shallow ittin . 26 819 ~~ 0.03 13 2.96 Shallow ittin . 27 850 t~ 0.03 I2 4 2.92 28 882 t~ 0.03 i 1 t~ 2.93 29 913 U 0.03 11 -1 2.94 30 944 0 0.03 1 3 2.92 Shallow ittin . 31 976 t~ 0.02 ~i ~ 2.96 32 1007 t~ 0.02 t; 2.96 33 1038 1) 0.01 I 2.95 34 1070 t. 0.01 I 2.96 35 1 101 + ~ 0.01 ' ! 2.94 36 1132 !~ 0.01 ~~ 2.95 37 1163 t~ 0.03 II s 2.96 38 1194 t) 0.03 I(1 -4 2.94 39 1226 a 0.02 e _' 2.95 40 1257 a 0.03 li7 2.96 41 1288 !~ 0.03 I3 2.96 Shallow corrosion. 42 1320 to 0.03 Il? 2.94 43 1351 t ~ 0.02 f3 ; 2.94 44 1383 U 0.02 ~~ ; 2.95 45 1414 a 0.03 I tl ~~ 2.96 Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD ABMODWeII: 2G-06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal LD.: 2992 in Country: USA Survey Date: December 9, 2009 Joint No. Jt. Depth (Ft.) NE~n. ill~sc~t (In,.l Pen. Body (Ins.) Pen. °ii, ~Mc~tal Ic~ss "4, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 46 1446 t> 0.04 14 ~ 2.93 Shallow ittin . 47 1477 t) 0.05 2ti 2.91 Shallow corrosion. 48 1509 U 0.04 17 (, 2.95 Shallow ittin . 49 1540 i? 0.04 15 2.96 Shallow ittin . 50 1571 U 0.04 15 a 2.95 Shallow ittin . 51 1602 t! 0.04 1 i 2.93 Shallow corrosion. 52 1633 U 0.03 13 ~-t 2.93 Shallow ittin . 53 1664 t) 0.03 10 2.94 54 1696 U 0.03 13 2.95 Shallow ittin . 55 1727 l) 0.03 12 2.95 56 1758 0 0.04 15 3 2.96 Shallow ittin . 57 1790 t) 0.03 1 "S ~ 2.93 Shallow ittin . 58 1821 11 0.04 15 _' 2.96 Shallow ittin . 59 1853 t1 0.04 17 4 2.96 Shallow ittin Lt. De sits. 60 1884 t) 0.04 lfi 3 2.95 Shallow ~ittin . 61 1915 C! 0.04 16 S 2.95 Shallow ittin . 62 1947 U 0.05 20 1 2.96 Line of its. 63 1978 t) 0.06 Z3 4 2.93 Line of its. 64 2010 U 0.06 < ~ _' 2.93 Line corrosion. 65 2041 U 0.07 27 t~ 2.93 Line of its. 66 2072 U 0.07 29 2.91 Line corrosion. 67 2104 tt 0.08 3U ~1 294 Line corrosion. 68 2135 tt 0.08 ~O .91 Line of its. 69 2167 t~ 0.06 Z5 5 2.95 Line corrosion. 70 2198 t~ 0.07 Z7 _' 294 Line of its. 71 2229 U 0.06 'Z •a 2.94 Line of its. 72 2261 t) 0.05 ?0 ~ 2.94 Line of its. 73 2292 t) 0.06 24 ~' 2.94 Line of its. 74 2324 tt 0.10 38 5 2.89 Line of its. 75 2355 U 0.10 41 ~ 2.93 Line corrosion. 76 2387 t) 0.08 i3 ~ 2.92 Line corrosion. 77 2418 t) 0.14 54 t, 2.94 Line corrosion. 78 2449 O 0.10 39 2.93 Line corrosion. 79 2481 t) 0.13 51 5 2.95 Line of its. 80 2512 t) 0.08 32 4 2.95 Line corrosion. 81 2544 U 0.08 32 ~ 2.95 Line corrosion. 82 2576 O Q08 ~2 3 2.93 Line corrosion. 83 2607 U 0.10 39 ? 2.94 Line corrosion. 84 2638 U 0.09 i4 2.94 Line corrosion. 85 2670 t) 0.10 38 -+ 294 Line corrosion. 86 2702 U 0.08 ~1 a 2.94 Line of its. 87 2732 U 0.08 3 -1 2.95 Line corrosion. 88 2764 t~ 0.12 ~4i - 2.93 Line corrosion. 89 2795 t) 0.13 5(~ i~ 2.94 Line corrosion. 89.1 2826 tt 0.03 lU 2.91 PUP 89.2 2836 tt 0 0 U N A GLM 1 Latc @ 6:30 89.3 2844 U 0.04 18 i 2.93 PUP Shallow ittin . 90 2854 a 0.13 it1 -1 2.92 Corrosion. 91 2885 t) 0.15 5i 2.93 Line corrosion. 92 2917 l) 0.09 i i 2.95 Line corrosion. Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD ABMODWeII: 2G-06 Body Wall: 0.254 in Eield: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc Nominal I.D.: 2.992 in Country: USA Survey Date: December 9, 2009 Joint No. Jt. Depth (Ft) Pwr. t 117,e~t (InS.j Pen. Body (Ins.) Pen. °/, Mc~r.rl I o5s "'~~ Min. LD. (Ins.) Comments Damage Profile (% wall) 0 50 100 93 2949 i) 0.08 i:3 ? 2.94 Line corrosion. 94 2980 U 0.17 67 2.92 Line corrosion. Lt De osits. 95 3012 U 0.15 hO i3 2.93 Line corrosion. Lt. De sits. 96 3042 O 0.13 5' ~ 2.95 Line corrosion. 97 3074 (~ 0.19 3 2.96 Line corrosion. 98 3106 U 0.18 ~ !~ 2.93 Line corrosion. 99 3137 t! 0.17 6E> (~ 2.94 Line corrosion. Lt. De osits. 100 3169 t).1O Q_21 83 ti 2.94 Line corrosion. 101 3200 O 0.17 66 2.93 Line corrosion. 102 3232 a 0.15 5£3 (, 2.93 Line corrosion. Lt De osits. - 103 3263 U 0.15 Gil -t 2.93 Line corrosion. - 104 3295 !) 0.19 73 ~~ 2.92 Line corrosion. Lt De osits. 105 3326 U 0.16 (~l E> 2.92 Line corrosion. Lt De osits. 106 3358 t ~ 0.19 ~ 4 ~ 2.93 Line corrosion. - 107 3389 !~ 0.24 ~)5 ~) 2.93 Probable Holc! 108 3421 t) 0.14 54 > 2.92 Line corrosion. 109 3451 U.U~ 0.10 39 7 2.94 Line corrosion. ~~ 110 3483 U 0.07 2t3 -t 2.92 Line of its. 111 3514 O 0.15 57 4 2.93 Line corrosion. Lt De osits. ~; 112 3546 U 0.14 54 5 2.92 Line corrosion. 113 3577 U 0.25 98 I ~~ 2.93 Probable Hole! 114 3609 U 0.17 67 6 2.93 Line corrosion. 115 3640 t) 0.12 4~ •1 2.92 Line of its. 116 3671 (1 0.13 49 `i 2.91 Line corrosion. Lt. De osits. 117 3702 U 0.09 35 2.93 Line corrosion. Lt. De osits. 118 3734 t) 0.15 (,1 ~ 2.93 Line corrosion. 119 3764 U 0.13 51 5 2.94 Line corrosion. 120 3795 t) 0.20 -t~ 9 2.91 Line corrosion. 121 3827 O 0.08 31 3 2.94 Line of its. 122 3859 0 0.07 ?~> 7 2.93 Line of its. 123 3890 0 0.07 1(~ 8 2.93 Line corrosion. 124 3920 U 0.14 54 b 2.94 Line corrosion. 125 3952 i) Q14 5.5 ~ 2.91 Line corrosion. 126 3983 t) 0.05 ZU Z 2.92 Line of its. 127 4015 U 0.10 38 b 2.93 Line corrosion. 128 4045 l) 0.09 3i 4 2.94 Line of its. 129 4077 U 0.17 65 G 2.93 Line corrosion. 130 4108 U 0.15 5~ i 2.90 Line corrosion. 131 4140 t) 0.21 t32 ~ 2.92 Line corrosion. 132 4171 ~) 0.12 46 5 2.89 Line corrosion. 133 4202 U 0.06 _'_i 2.90 Line of its. 134 4234 U 0.05 _' I 2.92 Line of its. 135 4265 O 0.14 54 d 2.93 Line corrosion. 136 4297 U 0.18 72 7 2.90 Line corrosion. 137 4328 O 0.07 2t3 i 2.93 Line corrosion. 138 4360 U 0.10 40 5 2.91 Line corrosion. 139 4390 ! ~ 0.1 1 44 -k 2.94 Line of its. 140 4421 a 0.11 44 (~ 2.92 Line corrosion. 141 4453 (~ 0.12 46 4 2.90 Line corrosion. 142 4483 O 0.11 45 ~ 2.92 Line of its. Page 3 _ Penetration Body Metal Loss Body • • PDS REPORT JOINT TABULATION SHEET '~ ~ Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD ABMODWeII: 2G-06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 2.992 in Country: USA Survey Date: December 9, 2009 Joint No. Jt. Depth (Ft.) I'~~n. UIx~~1 Iln~.) Pen. Body (Ins.) Pen. % Metal loss `%, Min. LD• (Ins.) Damage Profile Comments (%wall) 0 50 100 143 4515 t~ 0.10 3ti 3 2.90 Line of its. 144 4547 U 0.04 17 'i 2.92 Shallow ittin . 145 4578 l! 0.11 42 5 2.92 Line of its. Sli ht Bucklin 146 4610 (! 0.04 17 ~ 2.91 Shallow ittin - 147 4641 l! 0.03 11 > 2.93 - 148 4673 ~! 0.05 19 2.94 Shallow ittin - 149 4704 i) 0.03 13 t 2.92 Shallow ittin Sli ht Bucklin . 149.1 4735 ~~ 0.03 1? 2.89 PUP Shallow ittin . 149.2 4746 ;! 0 U U N A GLM 2 Latch @ 9:00 149.3 4752 t) 0.03 1 Z -1 2.91 PUP - 150 4763 U 0.03 1 3 5 2.93 Shallow ittin 151 4795 U 0.06 Z2 5 2.90 Corrosion. - 152 4825 U 0.07 2£s 4 2.93 Isolated ittin 51i ht Bucklin - 153 4857 (! 0.03 1l) 4 2.93 154 4888 t! 0.11 4`; -1 2.93 Isolated ittin - 155 4919 U 0.08 >> ~ 2.88 Corrosion. Lt. De osits. - 156 4951 U 0.03 I2 ~~ 2.95 - 157 4982 ~! 0.04 15 ~ 2.94 Shallow corrosion. Lt. De osits. 158 5013 ~? D.03 13 (> 2.92 Shallow ittin . 159 5045 t) 0.03 1 1 (, 2.92 160 5075 t) 0.04 14 S 2.92 Shallow ittin Sli ht Bucklin 161 5106 t! 0.03 I Z - 2.91 - 162 5138 ~! 0.04 I ~ > 2.91 Shallow ittin - 163 5170 t) 0.04 14 s 2.93 Shallow ittin - 164 5201 a 0.03 11 4 2.94 165 5233 ~! 0.04 1 b 2.93 Shallow corrosion. 166 5264 I! 0.03 I1 2.93 167 5296 (? 0.03 I ~ t, 2.95 Shallow corrosion. Sli ht Bucklin - 168 532 7 r! 0.03 I ;! ~ 2.95 169 5358 !! 0.04 74 tS 2.93 Shallow corrosion. 170 5389 t! 0.04 16 4 2.94 Sh Ilow ittin . 171 5421 !! 0.04 1'i 4 2.90 Shallow ittin . 172 5452 !! 0.04 1' S 2.93 Shallow corrosion. 173 5484 U 0.04 14 7 2.93 Shallow corrosion. 174 5515 (1 0.04 I6 £i 2.93 Shallow corrosion. 175 5545 ~) 0.04 ! 7 V 2.93 Shallow corrosion. 176 5577 (! 0.03 13 4 2.93 Shallow ittin Sli ht Bucklin . 177 5609 ~! 0.04 I (~ 1 2.92 Shallow corrosion. 178 5641 (! 0.04 I , -i 2.93 Shallow corrosion. 179 5672 i1 0.04 1 5 2.92 Shallow corrosion. 180 5703 ! ! 0.03 I I /i 2.92 181 5734 !! 0.03 1 2.91 Shallow corrosion. Lt. De osits. 182 5764 0 0.03 l3 2.92 Shallow ittin . 183 5796 U 0.02 7 ,' 2.94 184 582 8 t l 0.02 ~) 4 2.94 - 185 5859 U 0.04 14 6 2.92 Shallow ittin Sli ht Bucklin - 186 5890 ~~ 0.03 10 s 2.92 - 187 5921 t! 0.02 ~? a 2.90 188 5953 t! 0.02 ~> 2.92 - 189 5984 U 0.03 11 ~ 2.91 Page 4 Penetration Body ;Metal Loss Body i ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD ABMODWeII: 2G-06 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: December 9, 2009 Joint No. Jt. Depth (Ft.) 1'e~n. Upset (In..l Pen. Body (Ins.) Pc~n. %, ulefal loss % Min. LD- (Ins.) Comments Damage Profile (%wall) 0 50 100 190 6016 a 0.03 11 _' 2.92 191 6047 i) 0.03 I 1 3 2.93 192 6078 O 0.03 1 t) ~ 2.93 193 6109 (i 0.03 1t) (~ 2.92 193.1 6141 U 0.03 I0 ? 2.90 PUP Sli ht Bucklin . 193.2 6151 U 0 0 li N A GLM 3 Latch @ 12:00 193.3 6158 t? 0.03 13 y 2.89 PUP Shallow ittin . 194 6168 ii 0.03 13 2.93 Shallow ittin . 195 6199 a 0.03 12 t~ 2.92 196 6231 t) 0.04 15 4 2.94 Shallow ittin Lt De osits. 197 6262 (? 0.03 10 4 2.94 198 6294 U 0.03 1:3 2.93 Shallow ittin . 199 6325 (~ 0.03 13 4 2.93 Shallow ittin . 200 6357 ti 0.03 13 i, 2.90 Shallow ittin . 201 6389 U 0.03 13 2.89 Shallow ittin Sli ht Bucklin . 202 6420 t? 0.03 10 2.89 203 6452 U 0.02 9 2.91 Lt De osits. 04 6483 i? 0.01 ~ t 2.91 205 6515 c) 0.04 14 6 2.91 Shallow corrosion. ~ - 206 6546 t? 0.04 I ~ 6 2.92 Shallow corrosion. 207 6578 i? 0.03 13 ~ 2.92 Shallow ittin . 208 6609 i) 0.03 12 `? 2.92 209 6641 t) 0.03 10 4 2.93 210 6671 ii 0.03 12 -1 2.93 Shallow ittin . 211 6703 (i 0.04 1 ~ i. 2.93 Shallow corrosion. Sli ht Bucklin . 212 6734 i? 0.02 ~) -1 2.93 213 6766 U 0.03 11 ~ 2.91 214 6797 a 0.02 9 5 2.90 215 6828 t) 0.03 11 2.94 216 6860 0 0.02 ~) 3 2.93 217 6891 U 0.03 1 Z 2.91 218 6923 t) 0.03 1_' 2.93 219 6954 (? 0.03 I ~ 7 2.92 220 6985 (i 0.03 13 `~ 2.91 Shallow ittin Sli ht Bucklin . 221 7017 (? 0.03 13 - 2.90 Shallow ittin . 222 7049 U 0.02 4 ~ 2.92 223 7080 t1 0.03 1 ~ 2.92 Shallow ittin . 224 71 12 ~) 0.04 1-l 2.91 Shallow corrosion. 225 7142 U 0.02 9 -! 2.93 226 7173 i? 0.03 10 _' 2.93 227 7204 !) 0.03 7 1 (~ 2.92 227.1 7236 ti 0.02 i _' 2.91 PUP Sli ht Bucklin . 227.2 7245 U 0 t) U N A GLM 4 Latch @ 4:00 227.3 7252 U 0.05 i £~ 4 2.91 PUP Shallow ittin . 228 7263 ~? 0.04 1.3 4 2.91 Shallow ittin . 229 7295 a 0.03 1 ~' •1 2.92 230 7325 t? 0.03 1 "i 1 2.91 Shallow corrosion. 231 7355 c) 0.03 1 ~1 2.92 Shallow ittin . 232 7387 ~? 0.04 14 - 2.91 Shallow ittin . 233 7418 U 0.04 14 2.89 Shallow ittin . Penetration Body Metal Loss Body Page 5 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE SRD ABMODWeII: 2G-06 Body Wall: 0.254 in field: Kuparuk ' Upset Wall: Nominal I.D.: 0.254 in Company: ConocoPhillips Alaska, Inc. 2.992 in Country: USA Survey Date: December 9, 2009 Joint No. Jt. Depth (Et.) I'c~n. Upset (Ins.) Pen. Body (Ins.) I'e~n. % Mct,il I oss `~~~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 234 7448 U 0.04 17 -i 2.91 Shallow corrosion. 235 7480 0 0.03 13 ~ 2.93 Shallow ittin . 236 7511 0 0.04 16 -t 2.93 Shallow corrosion. Sli ht Bucklin . 237 7543 t? 0.04 14 2.89 Shallow ittin . 238 7574 t) 0.04 15 t~ 2.91 Shallow corrosion. Lt. De osits. 239 7605 t~ 0.04 14 -~ 2.9 Shallow ittin . 240 7637 U 0.04 15 ~~ 2.93 Shallow ittin . 241 7668 i) 0.03 1 3 2.92 Shallow ittin . 242 7700 t) .04 I ~ 2.92 Shallow corrosion. 243 7731 U 0.04 1 t3 b 2.91 Shallow corrosion. 244 7761 t) 0.03 13 ~ 2.94 Shallow ittin Sli ht Bucklin . 24 7793 0 0.04 15 ? 2.92 Shallow corrosion. Lt De osits. 246 7824 t) 0.03 13 3 2.91 Shallow ittin . 247 7856 U 0.03 11 -6 2.92 248 7887 t) 0.03 1 t) - 2.90 248.1 7919 t~ 0.02 ~) -1 2.90 PUP 248.2 7929 t~ 0 U t) N A GLM 5 Latch @ 3:00 248.3 7937 U 0.01 6 2.89 PUP 248.4 7947 t~ 0.02 i 2.88 PUP Sli t Bucklin . 248.5 7952 t) 0 t) U 2.98 PBR Assembl 248.6 7964 t) 0 U U 3.03 FHL Packer 248.7 7975 c) 0.04 15 t, 2.90 PUP Shallow corrosion. 249 7979 U 0.03 1 t) 5 2.92 Penetration Body Metal Loss Body Page 6 r ~ r ~ ~ ~ ~ ~ _ . s ~ ~ r r ~ w ~ r PDS Report Cross Sections Well: 2G-06 Survey Date: December 9, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L-80 EUE 8RD ABMOD Analyst: _ C. Waldro Cross Section for Joint 113 at depth 3607.14 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 88 Tool deviation = 49 ° Finger 24 Penetration = 0.25 ins Probable Hole 0.25 ins = 98% Wall Penetration HIGH SIDE = UP • • Goss Sections page 1 ar rr rr r r rr rr re ^r rr rr rr rr rr rr rr r ri rr PDS Report Cross Sections ~,. ~ ,. Well: 2G-06 Survey Date: December 9, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L-80 EUE 8RD ABMOD Anal st: C. Waldro Cross Section for Joint 107 at depth 3395.44 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 94 Tool deviation = 48 ° Finger 1 Penetration = 0.238 ins Probable Hole 0.24 ins = 95% Wall Penetration HIGH SIDE = UP C~ Cross Sections page 2 _ _ ~ ~1 ~ KUP r 2G-06 C011000~ll~~lp $ ~ } ell Attributes An le 8 MD TD /1 Wellbare APINWI Reltl Name Well Stales Inc (°) hD (RKB) 500292112100 KUPARUK RIVER UNIT PROD 54.60 4.000.00 Ad Bim (RKB) 8,449.0 ~~~ Comment M2S Ippm) SSSV: NIPPLE 150 DMe 1/11/2009 Arrrot~on Las[ WO: End ale KB-Ord IR) 12/10/2007 36.00 Rig Release Date 6/18/1984 Well Confi -2G-0B ii Srlhametic- 28/[Ct~' Ac["~~ Atrwtadon Depth IIDCB) End Date Anwtatlon Last MO tl ... Fstl Die Last Tag: SLM 8,038.0 11/25/2009 Rev Reason: TAG FILL Imosbor 11/28/2009 Casin Strin s ' ,,. Casing Descnpoon CONDUCTOR Sang 0... 16 S[nrg ID ... 15.062 lop Ptl(B) 380 Set DepN rc... S 110.0 et Depth (TVD) ... 110.0 Slung Wl... 62.58 Stung ... H110 String lop mrd Welded Casing Descnptlon SURFACE slung 0... 9518 Stang ID ... 8.765 lop (RKB) 372 Set DepN It... S 3.133.9 et DepUl (TVD) ... 2.773.9 slnry wt... 36.00 S[nng ... J35 S[nng Top mrd BTC -~ '_ Casng Descnpdon PRODUCTION S[nng 0... 7 Stung ID ... 6.151 Tap IRKeI 35.9 Set Depth P... 8.449.1 Set Depth (ND)... 6.223.8 Stung ~... 26.00 S[nng ... J-55 Stung Tap mrd BTC Tubin Stria s nbin9 Descrlptlon S[nng 0... S[nng ID ... lop QIICB) Set Depm P-.. Set Depth (7VD1 ... Stung Wt... S[nng ... Stung Top mrtl TUBING 3112 2.992 34.0 7.954.6 5.830.2 9.30 L-80 EUE8rdABMOD Com letion Details CONDU380a~ To B) lop Depm (ND) 161 lop Intl 1°I R em Desc Io n Comment NoM... ID Pn) 34.0 34.0 0.10 H ANGER Vetco/Gray Gen 3 3.5"x6" tubing hanger 2.992 NIPPLE. sz9 520.5 520.4 1.10 N IPPLE 3.5" DS Nipple w/ 2.875 profile 2.875 7,953.3 5,829.2 39.66 S EAL PBR Seal Assembly (sheared) w! 1' space out 2.992 Tuhirg Desonpoon Slnn90... Sldng lD ... Top (ro(B) Set Depth lL.. Set pm 17vD)... snrg Wt_. stung ... Stung op Thrd TUBING Packer Assy 31/2 2.992 7,952.2 8,043.6 5,899.3 9.30 L-80 BRD EUE cAS uFT, z es, Com le tion Details . Top Depth (ND) Top Intl Norri... Top nNCB) 1~e1 (°) R em Descnptlo n Cammen[ ID PM 7,952.2 5,828.4 39.67 P BR PBR assembly 2.980 7,965.9 5,838.8 39.53 P ACKER FHL Packer 3.030 8.008.7 5,872.5 39.12 N IPPLE 2.813" DS NVPIe 2.813 ~ 8.041.1 5,897 4 38.70 S HOE 2 ft Sparkle MULE SHOE 3-1/2" EUE 2.980 suRPACE, 37-3,'134 Tublrg Des TUBING O atpdon Stung 0... inal 3112 ri stung ID ... op (rote) set Depth p... set Depm (TVD) _. Stung vW... stung ... sonny lop mrtl 30 L-80 EUEBrdMOD 3 6 021 6 9 992 8 159 0 8 198 2 g Com letion Det , . . , . , . . ails Gus LIFT, 4,753 o B Top Depth (ND) 1~e1 Top Intl (°) R m Descu Io Cantnert Noml... ID pN 8,159.0 5,990.2 37.19 P ACKER FHL RETRIEVABLE PACKER 2.850 8,186.3 6,011.9 36.85 N IPPLE HES NIPPLE wlSELECTIVE PROFILE 2.750 8,197.6 6.021.0 36.70 W LEG WIRELINE ENTRY GUIDE 2.992 Gus LIFT. Other I n Hole !reline retrievabl e lu s, valves, um s fish etc. s,ts4 Top QtiCB) Top Depm (NDI PDCB1 Top Intl (°) Desatptlon Commnn Rut Date ID IIn) 8.166 5,995.5 37.11 P LUG 2.75°'XX' PLUG set 11/15/2007 DROPPED 2007 POST WORKOVER 6/17/2006 0.000 GAS LIFT, 7 za7 Pertorations 8 Slots . Top ITVD) nxe etm ITVD) 6 shot Dens (~ n Top (IlKB) 8,188 Bon Iroc61 8,198 I l 6,013.3 1 1 6.021.3 A Zone 3, 2G-06 Date 9/24/1988 ~~~ 4.0 TYPe IPERF Comme t 90 deg. Phasing; 4" Schlumberger Casi GAS LIFT. ~ 9zs 8.216 8,246 6,035.7 6,059.9 A 4, 2G-06 9/24/1988 4.0 IPERF 90 deg. Phasing; 4" Schlumberger Casi Notes: General 8 Safe End Date Amdaoon 1/?12000 NOTE: WORKOVER SEAL, ],953 12(10/2007 NOTE: "MIT TESTING WILL HAVE TO USE DS NIPPLE ~a18011"" PBR. 7952 1/5/2008 NOTE: CUT TBG TAIL POST WO DROPPED 97', COVERED WITH FILL @ 8159' SLM PACKER, 7gss 7/2/2009 NOTE 5005' =TIGHT SPOT, UNABLE TO WORK 2.6" GAUGE RING PAST 6/27/2009 7/2!2009 NOTE: VIEW W/ALASKA SCHEMATIC 9.0 NIPPLE, 8009 SHOE,8041 PACKER. 8.159 PLUG Z 10G , , NIPPLE 186 6 , , Mandrel Details IPERF e te8-E t9a Sfn To Top DepM (ND) (RKBt lop Intl (°) Make Motlel OD llnl Serv Valve TYPe Latch 1Ype Port Size lip) 7R0 Rtn (psy Rut! Date Com... 198 WLEG 8 1 2.850.9 2,589.9 49.56 Cameo KBMG 1 GAS LIFT GLV BK-5 0.125 1,240.0 1/21/2008 , , 2 4,753.4 3,737.6 53.52 Camce KBMG 1 GAS LIFT GLV BK-5 0.156 1,273.0 1/21/2008 3 6,153.8 4,586.6 51.73 Cameo KBMG 1 GAS LIFT GLV BK-5 0.188 1,303.0 1/21/2008 4 7,246.5 5,311.3 45.75 Cameo KBMG 1 GAS LIFT OV BK3 0.188 0.0 1!21/2008 IPERF, a.ztss zas 5 7,928.7 5,810.2 39.92 Cameo KBMG 1 GAS LIFT DMY BK3 0.000 0.0 1/21/2008 TD, 8,449 PRODUCTION, 36-8.449 • Casing OR Tubin OR Drillin Detail wets zC-os 2G-O6 New Com /efi'on Date: Dec. 7 '07 ~ ~ ~~~~"II~~pS Rig: N3S Maaka, Inc. Dept Jt Number Jants Well Equipment Description and Comments Page 1 Lengtil Tops Ta of S#rin c-r To ofFtan e Vetco/Gra Gen 3 3.5"x6" tubin han er w/9.3# L-80 EUE 8RD AB mod. up 3.07 Jts 248 to 24 1 Jts 3.5" Tubin 9.3# L-80 EUE 8RD AB Mod. 32.22 3.07 3.5" Pu Jt. 9.3# L-80 EUE 8 RD AB Mod. S ace out u s 2 x 10ft & 1 x 8ft 28.17 35.29 Jts 234 to 24 14 Jts 3.5" Tubin 9.3# L-80 EUE 8RD AB Mod. 457.01 63.48 3.5" DS Ni to w/ 2.875 rofile 1.11 520.47 Jts 160 to 23 74 Jts 3.5" Tubin 9.3# L-$0 EUE 8RD AB Mod. 2319.24 521.58 3.5" Pu Jt. 9.3# L-80 EUE 8 RD AB Mod. 10.07 2840.82 3.5"x1" Camco KMBG w! 1" Dumm valve w/ BK-5 Latch 7.03 2850.89 3.5" Pu Jt. 9.3# L-80 EUE 8 RD AB Mod. 9.54 2857.62 Jts 100 to 15 6o Jts 3.5" Tubin 9.3# L-80 EUE 8RD AB Mod. 1875.83 2867.46 3.5" Pu Jt. 9.3# L-80 EUE 8RD AB Mod. 10.12 4743.29 3.5"x1" Camco KMBG w/ 1" Dumm valve w/ BK-5 Latch 7.02 4753.41 3.5" Pu Jt. 9.3# L-80 EUE 8 RD AB Mod. 9.64 4760.43 Jts 56 to 99 44 Jts 3.5" Tubin 9.3# L-80 EUE 8RD AB Mod. 1373.69 4770.07 3.5" Pu Jt. 9.3# L-80 EUE 8 RD AB Mod. 10.01 6143.76 3.5"x1"Camco KMBG w/ 1" Dumm valve w/ BK-5 Latch 7.05 6153.77 3.5" Pu Jt. 9.3# L-80 EUE 8 RD AB Mod. 9.56 6160.82 Jts 22 to 55 34 Jts 3.5" Tubin 9.3# L-80 EUE 8RD AB Mod. 1066.10 6170.38 3.5" Pu Jt. 9.3# L-80 EUE 8 RD AB Mod. 10.02 7236.48 3.5"x1" Camco KMBG w/ 1" Dumm valve w/ BK-5 Latch 7.00 7246.50 3.5" Pu Jt. 9.3# L-80 EUE 8 RD AB Mod. 9.61 7253.50 Jts 1 to 21 21 Jts 3.5" Tubin 9.3# L-80 EUE 8RD AB Mod. 655.49 7263.11 3.5" Pu Jt. 9.3# L-80 EUE 8 RD AB Mod. 10.11 791x.60 3.5"x1"Camco KMBG w/ 1" CV without check 7.04 7928.71 3.5" Pu Jt. 9.3# L-80 EUE 8 RD AB Mod. 9.56 7935.75 3.5" Pu Jt. 9.3# L-80 EUE 8RD AB Mod. 7.97 7945.31 PBR Seal Assembl sheared w/ 1' s ace out 1.32 7953.28 7954.60 7954.60 7954.60 7954.60 7954.60 7954.60 7954.60 7954.60 Remarks: Up Wt ??? K Dn Wt ?? K Block Wt ?? K Supervisors: DolcateNRauchenstein Tubing Well: 2G-06 FHL Run Date: Dec. 6-07 /~-~,,~~~N WI1~II~pS Rig: Nabors 3& Ataeka, inc. Depth Jt Number Joints Well Equipment Description and Comments Page 1 Length Tops To of Strirl ar Ttl! of Ff 3 1/2 IF Pu Joint 14.07 Jts 1 to 256 256 Jts 3-1/2" IF Drill Pi 7928.89 14.07 3-1 /2" m to 3-1I2 I F box X-over 1.25 7942.96 EUE u 'oint 7.97 7944.21 PBR assembl 13.69 7952.18 FHL Packer 7.3s 7965.87 3-1/2" EUE u ~oint 4.10 7973.23 3-1/2" Joint, 9.3#, L-80, EUE 8RD AB-Modified 31.35 7977.33 2.813" DS Ni le w/ RHC lu installed .s6 soa8.6s 3-1 J2"Joint, 9.3#, L-80, EUE 8RD RB-Modified 31.44 8009.64 2 ft Snorkle 3-1/2" EUE 2.48 8041.08 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 8043.56 Remarks: 1-50 are "E" and 51-116 are "G" Up Wt ??? K Dn Wt ?? K Block Wt ?? K Supervisors: • • Page 1 of 1 Regg, James B (DOA) __ From: NSK Well Integrity Proj [N1878@conocophillips.com] ~~~ i~'Z~~~,4,q Sent: Monday, November 16, 2009 3:08 PM l To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: KRU Producer 2G-06 (PTD 184-082) Attachments: 2G-06.pdf Jim/Tom/Guy, Kuparuk gas lifted producer 2G-06(PTD# 184-082) is suspected of having TxIA communication based upon a failed shut in TIFL on 11/14/09. A leaking as lift valve is suspected so slickline will repair if possible. CPAI will add 2G-06 to the SCP Report and th well will be fixed or sh~ ut-in by 12/12/09. Attached area 90 day TIO plot and wellbore schematic. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 11/27/2009 KRU 2G-06 PTD 1840820 11 / 16/2009 Ti0 Pressures TlI/0 Plot - 2G-06 1000 800 /_//~ 600 V/ Boa goo 0 .................................................................................. .. .......... h....~- . ~~...... ..... .............................................................................................................................4 01-Sep-09 01-Oct-09 Date 01-Nov-09 goo 150 cQ G 100 ~ U 50 0 /'-, ~" ~ KUP 2G-06 ~C)tIOCC~~'~1j~~j~75 [~ Attributes Weil _ _.-_ ax Angle. 8r M_D _ iTD ,..1 ~ ~ W III i I(UWI 'Field Name _ -___ _ W II St t I I('/ MD (ftKB) Acl Btm (ftKD) .1112100 KUPARUK RIVER UNIT PRODUCING 54.60 4,000.00 8,449 0 _ rC m nt H75 (ppmJ Date Ann tat End D to KB•Grd (ft) Rig Release Date ° wau conrw-zc-o~;. 7;2~2ros rlsss PM SSSV: NIPPLE 150 1/11/2009 Last WO: 12/10/2007 36.00 6/18/1984 _ s hemaar .4 ai _ _ A notation Depth (RKB) Entl Date Annotation Last Mod By Entl Date Last Tag: SLM 8.028.0 7/2/2009 Rev Reason: TAG FILL SLM. ADD NOTE TRIPLWJ 7/2/2009 1 /-J ,-~ Casing Stnngs -- ~ ~ C . - g Dos r pt on St g 0.. . Sm ng ID .Top (itKB) Set D pth (f Set Depth (ND) . St ~ g Wt . St g String Top Thrtl CONDUCTOR 16 15 062 0.0 110 0 110.0 62 58 H-40 Welded ~~ 4/ ~`%( . -NgrJ ,ER. 's4 - ~ Y ~~ Cas-ng Descnphon String 0.. . String ID .. . Top (ftK6) Set Depth ((... Set Depth (ND) ... Stnng Wt... String ... String Top Thrd ./ ~ ' g ~. .' `: SURFACE 95/8 8765 0.0 6,164.0 4,593.0 3600 J-55 BTC ~~LJ P ~ I _ ~ Casing Description String 0.. ~ODUGTIDN 7 . String ID .. 6151 . Top (RKB) 00 Set Depth (f.. 84490 Set Depth (ND) ... 6 223 7 String WL.. String ... 26 00 J 55 String Top Thrtl BTC ( I qC ~G~ .. _ ~ - . . __ . - ~, f gs I r I o n S str3g 2.. str .. hst pset D L.. st . Top ~SVi D1 ?h d 1 iSe p ~ I 1 W/O TUBI G 2y92 - ^ 7954 a30 930 L 80 EUE 340 ~ CONDUCTOR, MOD 0-110 ~ - Completton Details ___ -- __- ~- - ToP Depth NIPPLE, 520 ~ (ND) Top Incl -=:. Top (ttKB) (RKB) (°) Item Descripti on Comment ID (in) ['; 34.0 34.0 0.10 HANGER Vetco/Gray Gen 3 3.5"x6" tubing hanger w/9.3# L-80 EUE 8RD AB mod. 2.992 4=-:: pup I 520.5 520.4 1.10 NIPPLE 3.5" DS Nipple w/ 2.875 profile 2.813 cns uFT, - _ ~ - 7,953.3 5,829.2 39.66 SEAL PBR Seal Assembly (sheared) w/ 1' space out 2.992 2,es1 y„ Tubing Des cription String 0 ... String ID . .. T ap (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING PACKER 3 1!2 2.992 7,952.2 8,043.6 5,899.3 9.30 L-80 SRD EUE ASSY - 1 ' 'Coin letion Details - ',. ~ Tap Depth _ _ _ _. _ -- (ND) Top Incl I ~ Top (RKB) (ftKB) (°) Item Descripti on Comment ID (In) cas uFr __ 7,952.2 5,828.4 39.67 PBR PBR assembly 2.980 , a ]sa _ ~ ~ , 7,965.9 5,838.8 39.53 FHL Packer FHL Packer 3.030 ~". I s 8,008.7 5,872.5 39.12 DS Nipple 2.813" DS Nipple w/ RHC plug installed 2.831 6,041.1 5,897.4 38.70 Snorkle -Mu le 2 ft Snorkle 3-1/2" EUE 2.980 Shoe ~i Tubing Des cription String 0 ... String ID . .. T op (RKB) Set Depth (/... Set Depth (ND) ... String WL.. String ... String Top Thrtl _i ;~ TUBING 31/2 2.992 8,159.0 8,178.0 6,005.3 9.30 J-55 BTC cnselFT~ ~_ ,- ,_;j ' _ tc) ~I Other In Hole (Wireline retrievable lugs, valves, pumps, fish, e - - - -- Top Depth _ __ _ (ND) Top Incl SURFACE, a ~ ~~ ' Top (ftKe) (ftKB) (°) Description Comment Run Date ID (in) o-s,1sa I 8,159 5,990.2 37.19 PKR BAKER 3.5" x 7" FHL Retrievable Packer, 2.850 drift - 12/27/1999 3.030 '~ DROPPED 9T POST WORKOVER j 8,166 5,995.8 37.11 NIP OTIS'X' NIPPLE WITH 2.75" SELECTIVE PROFILE 12/27/1999 2.750 s _ "WARNING" DO NO USE THIS NIPPLE DROPPED 2007 POST WORKOVER t ~' 8,166 5,995.8 37.11 PLUG 2.75"'XX' PLUG set 11/15/2007 DROPPED 2007 POST 6/17/2006 0.000 GAS LIFT. ].z4] ~ '^a ` WORKOVER ~. __~ 8,178 6,005.3 36.95 SOS BAKER Wireline re-entry guide DROPPED 2007 POST 12/27/1999 2.992 ~ WORKOVER . i ~_ - Petfiorations & Slots ----._-_..__-__.. ._-- i Shot _ ~ Top (TVD) Btm (ND) s D GAS LIFT ~" -~ Top (RKB) Btm (ftKB) (ftKB) (RKB) Zone Date (sh ~~ Type Comment , 7szs ~~' 8,188 8,198 6,013.3 6,021.3 A-5, 2G-06 9/24/1988 4.0 IPERF 90 deg. Phasing; 4" Schlumberger ` - I Casi t 8,216 8,246 6,035.7 6,059.9 A-4, 2G-O6 9/24/1988 4.0 IPERF 90 deg. Phasing; 4" Schlumberger Casi L ~- --- _ .__.. . __ _- _._. ----.- _ _. _-- ---- SEAL ]968 I lNotes: General & Safety _ . PBR. ].952 FHL Packer, k ~ 7,966 ' -' ~' ~ DS Nipple, ~ ' 8,009 Snorkle-Mule I Shoe, 8,041 I, PKR. 8.159 NIP, 8,186 PLUG. 8.16fi !'~`~~~ir'~"~ SOS, 8,178 IPERF, 8.188-8.198 9.0 4115 _ __ _ _ rp Depth Top Port (ND) Incl OD Ir Valve Latch Size TRO Run (ftKB) (°) Maka Motlel 9N 5erv I TYPe ~ Type ~~ (in) (pail Run Date Com... 1 IPERF, 8,216-8,246 PRODUCTION, 'i. 9-8,449 TD, 8 449 I Page 1 of 2 • Maunder, Thomas E (DOA) • From: Regg, James B (DOA) Sent: Thursday, March 13, 2008 2:31 PM To: Maunder, Thomas E (DOA) Subject: FW: Another Missing BOPE Test Attachments: Nabors 3S BOP Test 11-23-07 .xls FYI Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~- ,g~-off' ~~.o~ ~~E~ From: Gober, Howard [mailto:Howard.Gober@conocophillips.com] Sent: Thursday, March 13, 2008 2:04 PM To: Regg, James B (DOA) Subject: RE: Another Missing BOPE Test Jim, Here is the BOP test you requested. The BOP test farm is dated 11/23/07 since that is when the test was finished. Please let me know if you need anything else. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard.Gober@conocophillips.com ~~ ~A~ ~ ~ Zaog From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, March 13, 2008 10:25 AM To: Gober, Howard Cc: Maunder, Thomas E (DOA) Subject: Another Missing BOPE Test Reviewing sundry report for KRU 2G-06 repair; work summary indicates BOPE testing on 11/22/2007. Please check your records and forward a copy if you have one. Thank you. Jim Regg AOGCC 333 W.7#h Avenue, Suite 100 5/13/2008 STATE OF ALASKA 11!14107 OIL AND GAS CONSERVATION COMMISSION BODE Test Report Submit to: Contractor: Nabors Rig Rep.: J.Greco/J.Fritts Operator: CPA! Rep.: R.Overstreet/D.Chapman Field/Unit 8~ Well No.: KRU 2G-06 Operation: Drlg: Test: Initial: Test Pressure: Rams: 250/4000 MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Quantity Size Rig No.: 3S Rig Phone: 659-7594 Op. Phone: 659-7514 / PTD # 184-082 V DATE: 1112312007 Rig Fax: 659-7055 Op. Fax: Woricover: x Weekly: x Annular. 250/2500 Explor.: Bi-Weekly Valves: 250/4000 TEST DATA FLOOR SAFETY VALVES: Test Result Quantity Test Result P Upper Kelty NA P Lower Kelly NA P Ball Type 1 P Inside BOP 1 P Test Result Annular Preventer 1 13 5/8 5000 P Pipe Rams 1 2 7/8 X 5 12 P Lower Pipe Rams 1 2 7/8 P Blind Rams 1 Blind Shear P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 118" 5000 P Kill Line Valves 1 2 1 /16" 5000 P Check Valve 0 NA MUD SYSTEM: Visual Test Trip Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector P Alarm Test P P P P P Test Results CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3050 P Pressure After Closure 1550 P 200 psi Attained .37 P FuN Pressure Attained 2min 32sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg); 4@1800 Number of Failures: 2 Test Time: 7 Hours Components tested Repair or replacement of equipment will be made within Done days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervisor at: Remarks: ,flange on manual kill valve leaked. retiahten & test (2} stem on # 9 choke vale leaked ,grease stem packing and retest ok. 24 HOUR NOTICE GIVEN YES x NO BOP Test (for rigs) BFL 11/14!07 Date 1122/07 Time Test start 23:00 Finish BY John Witness Jimmy Fritts Nabors 3S BOP Test 11-23-07 .xls • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RE~~V~C~ FED ZOD~ REPORT OF SUNDRY WELL OPERATIOI~S_,__ ,,,, a_ r__ r+a.,. rh,w„;~~,R~, 1. Operations Performed: Abandon ^ Repair Well Q ~ Plug Perforations ^ Stimulate ^ Other Ash ~° Alter Casing ^ Pull Tubing ^ ~ Perforate New Pool ^ Waiver ^ Time Extension Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhilllps Alaska, InC. Development ^~ ~ Exploratory ^ 184-082 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-21121-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 140' - 2G-06 8. Property Designation: 10. Field/Pool(s): ADL 25656, ALK 2582 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8485' ~ feet true vertical 6253' - feet Plugs (measured) 8069' Effective Depth measured 8212' feet Junk (measured) true vertical 6033' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SUR. CASING 6024' 9-5/8" 3134' 2774' PROD. CASING 8309' 7" 8449' 6224' Perforation depth: Measured depth: 8188'-8198', 8216'-8246' ~~+t14~EC~ MAY ~ ~ 2008 true vertical depth: 6013'-6021', 6036'-6060' Tubing (size, grade, and measured depth) 3-1/2" , L-80 / J-55, 8081 ' MD. Packers & SSSV (type & measured depth) pkr= BAKER FHL RETRIEVABLE PACKERS @ pkr-- 7968' , 8042' Camco DS nipple @ 521' 12. Stimulation or cement squeeze summary: Intervals treated (measured) n ot 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 SI -- 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 ^ WINJ ^ 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: none contact Howard Gober @ 263-4220 Printed Name Howard Gober Title Wells Group Engineer Signature ~-~ Phone Date ~.~~ t/j~7 C~~{~) ~ su -Dr ke 263-4692 Pre ared b Sha o ~..,~ l Form 10-404 Revised 04/2006 ~ ~~~ NA'~ 2 '~ 20D8 ~(~~ Submi~~~//.~l'~ ~~ C+anocoPhiliips Time Log Summary Vreliv7ew Nieb Reporting Well Name: 2G-06 Job Type: RECOMPLETION Time Logs --- -- ---- -------- Date From To Dur S. Depth _E, Depth Phase Code Subcode T COM 11/16/2007 18:00 20:00 2.00 PROD1 MOVE OTHR P Nabors 3S -Preparing for rig move. 20:00 00:00 4.00 PROD1 MOVE WOW T Rig on Standby. 2G Pad is being prepared for move in of rig (Clearing snow and etc. Leveling pad around we112G-06 & removing flowline etc.) This was dela ed because of weather. 11/17/2007 00:00 07:00 7.00 MIRU MOVE WOW T 2G Pad is being prepared for move in of rig (Clearing snow and etc. Leveling pad around we112G-06 & removing flowline etc.) This was delayed because of weather. Released rig from standby @ 07:00. (11 hrs standb time. 07:00 09:30 2.50 MIRU MOVE RURD P Blowdown steam lines, disconnect modules, scope down and lay down derrick. Pick up Handy Berm and Herculite. Pre for move to 2G ad. 09:30 12:30 3.00 MIRU MOVE WOEQ T On standby 3 hrs for a total of 14.0 hrs standby. wiating for trucks for move - due to other ri movin in field 12:30 00:00 11.50 MIRU MOVE RURD P Release rig from standby. Moving from 3N-11 to 2G-06 11/18/2007 00:00 07:00 7.00 MIRU MOVE RURD P Set camp, shop and generator. Spot mats around wellhead. Spot BOPE and pull herculite for carrier. Spot carrier, jack level and pin carrier. Spot pipe shed and pits and jack down on the mats. Hook up electric to the pipe shed. Berm around rig and inspect derrick. Raise, scope and secure mast. 07:00 09:00 2.00 MIRU RPCOh RURD P Acce t ri 07:00 11/18/07. Rig up hardlines to tiger tank for well kill and circulation. 09:00 11:00 2.00 MIRU RPCOh RURD P RU lubricator and ull BPV. RD lubricator. 11:00 18:30 7.50 MIRU RPCO CIRC P PJSM on well kill. SITP and SICP = 300 psi. Circulate 9.6 ppg brine. Circulated 525 bbls before getting 9.6 returns. SI csg and tbg press staying at 8 psi. Monitor well ,returns slow trickle. SI and monitor for pressure increase. One hour SI, pressure increased to10 si. 18:30 21:00 2.50 MIRU WELCT COND P Bring wt up 9.8 ppg in pits. Page °i t~f 12 m ~" a ..~ 3 C U S ~- ~ ~~ ~' V 6' `~-~ Time Logs Date From To Dur S. De th E. De t h Phase Code Subcode T _ COM 11/20/2007 00:00 06:00 6.00 _ __ COMPZ RPCOh CIRC T Bullhead down tbg 1 bbl every 30 minutes, chart and monitor pressure to prevent freeze up of circulating system, while waiting on 14.5 ppg KWF. Maximum Pressure seen was 1880 psi IA & tbg and dropping back to 1400 si. w/ 8.75 bbls um ed. 06:00 17:00 11.00 COMPZ WELCT CIRC T Load pits with 14.5 ppg drilling mud. SICP = 1360 SITP = 1360 Line up and pumped 14.5 mud down tubing taking returns to Tiger Tank. Starting pump pressure 1560 psi @ 2.5 BPM with 1 to 1 returns. Pumped 336 bbls and switched back to pits (MW = 13.2 ppg) Continued to pump KWF around. Pumped 835 bbls, MW in 14.5 MW out 14.4+. 17:00 18:00 1.00 COMPZ WELCT OWFF T Shut in and monitor well. Static. 18:00 19:00 1.00 COMPZ FISH PULL T ND head pin. LD tubing hanger. PU tubing with no movement from packer. PU worked pipe up and down to max pull 165K, still packer would not move and PBR seals would not ull out. 19:00 00:00 5.00 COMPZ FISH ELNE T Monitored well while waiting on SWS for perforating and tubing cut. Well was static. 11/21/2007 00:00 00:30 0.50 COMPZ FISH ELNE T Contiued to monitor well while waiting on SWS. Well static. 00:30 03:30 3.00 COMPZ FISH ELNE T Held PJSM, RU SWS, could not get a good PT on the a-line pack off, had to o to Deadhorse to et arts. 03:30 12:00 8.50 COMPZ FISH WOEQ T Waiting on xover for pack off coming from Deadhorse Phase II weather . 12:00 14:00 2.00 COMPZ FISH RURD T SWS tools arrived. Complete rig up and test lubricator. PJSM on explosive on ri floor. 14:00 16:00 2.00 COMPZ FISH ELNE T RIH with SWS 1.56" tubing punch. Correlate with log to get on depth but stacked out @ 8090'. W/15' from CCL to shot this would put the shot bottom of shot @ 8075' and top of the shot @ 8073' (middle of packer). Opted not to shoot 16:00 17:30 1.50 COMPZ FISH ELNE T POOH with E-line tubing punch. 17:30 22:30 5.00 COMPZ FISH ELNE T Made up string shot and RIH to rattle the PBR. Tied in and attempted to shoot string shot. POOH and verified mis-fire. 22:30 00:00 1.50 COMPZ FISH ELNE T Make up jet cutter assembly and RIH to cut tubin -8033'. Page 3 cat'S2 I ~~ Time Logs _ _ _ Date From To ur D S De th _ E De th Phase Code Subcode T _ _ COM _ 11/22/2007 00:00 _ 05:30 _ 5.50 COMPZ FISH ELNE _ T Continue to RIH w/jet cutter, tie into GLM #5, shot cutter @ -8032' a-line measurement. No noticable pipe movement but could feel charge go off w/ 15K over pull. Well still static. POOH w/ cutter and rig back SWS. Note: Had to swap out 3.5" IFx8rd crossover, could not get 2.5" jet cutter to dro throw h. 05:30 07:30 2.00 COMPZ FISH RURD P PU on string to verify good cut. Up wt. 70K, no overpull. RU and begin circulating bottoms up. Finish rigging down SWS and clearing/cleaning rig floor. Change bails and rigged up to POOH. 07:30 20:00 12.50 COMPZ FISH PULL P POOH laying down and strapping 3.5" tubing. Separating and marking bad jts. OOH @ 19:00 hrs., clear/clean rig floor and pipe shed and prepare for BOPE test. Note: Jet cut was clean and flared out to 3 7/8". i t ~ z~ .~ 8~ Not due BOP test until .L1~ but need to test lower rams, annular, HCR and Kelly. After discussing with AOGCC we tested all of BOPE and Kell . 20:00 00:00 4.00 COMPZ WELCT BOPE P RU for and begin BOPE test, rams to 250/4000 psi and annular to 250/2500 psi. Well static. BOPE test witness was waived by John Cris AOGCC . 11/23/2007 00:00 07:00 7.00 COMPZ WELC BOPE P Continue BOPE test, rams to 250/4000 psi and annular 250/2500 psi. Phase II weather, trouble getting water etc to rig. ~ State witness was waived by John Cris AOGCC . 07:00 15:30 8.50 COMPZ FISH WOW T Phase III weather conditions. Put rig on standby until weather clears and ad has emer enc access. 15:30 23:30 8.00 COMPZ FISH PULD T Install wear ring. PU BHA consisting of washpipe, hollow mill, overshot, jars & bumper sub, and intensifier, 8 - 4 3/4"drill collars. RIH to approximately 2000'. 23:30 00:00 0.50 COMPZ FISH CIRC T Circulated bottoms up to condition the hole. 11/24/2007 00:00 02:30 2.50 COMPZ FISH TRIP T Finished circulating and continued to RIH to 3900'. 02:30 04:00 1.50 COMPZ FISH CIRC T Circulated to condition the hole while re-loading the pipe shed with more drill i e and PU the Kell . 04:00 09:00 5.00 COMPZ FISH PULD T Make up and test Kelly. 09:00 14:30 5.50 COMPZ FISH TRIP T Continue RIH picking up workstring. ~ ~'a~a 4 of 12 ~~ Time Logs ~ _ _ _ Date From To ~Dur S. De th E. Depth _Phase. Code Subcod_e T COM _ - - - -- 11/24/2007 14:30 15:00 0.50 COMPZ FISH CIRC T PU Kelly, Circulate hole, 3 BPM @ 1010 si. 15:00 18:00 3.00 COMPZ FISH JAR T Up wt. 110K Dwn wt 63K. Work shoe over tubing stub (a7 8005'. Rotate and clean up end of stub from Power Cutter. Lowered down and engaged overshot. Jarred on packer with no movement for 3 hrs. 18:00 20:00 2.00 COMPZ FISH CIRC T Stopped jarring and circulate hole, waitin on Ian forward. 20:00 00:00 4.00 COMPZ FISH JAR T Sat down and rotated to release the grapple, would not release. Jarred @ 210K and pulled to 250K, no movement. Continued to work the string by using a combination of jarring and rotating. Also circulated ~30 to 40 BBLS every hour to prevent freeze u of Kell hose. 11/25/2007 00:00 00:30 0.50 COMPZ FISH JAR T Continue to jar and rotate to attempt to release from fish. 00:30 15:00 14.50 COMPZ FISH WOEO T Circulate to condition hole and standby for SWS to make a back off shot. 15:00 17:00 2.00 COMPZ FISH ELNE T RU SWS. PJSM. 17:00 19:00 2.00 COMPZ FISH ELNE T RIH with double strand string shot. On depth at collar #32, 992'. PU pipe to Neutral with 8 turns to left and hold torque. Shot backoff, released torque and got back 1 turn. POOH with wireline, turned pipe 2 turns while pulling small amount of wt and pipe came loose. 19:00 21:00 2.00 COMPZ FISH PULD T Rigged back SWS equipment. Stand back Kelly. POOH wilth 32 jts of drill pipe checking each connection and standin back in derrick. 21:00 22:30 1.50 COMPZ FISH PULD T PU new single joint of drill pipe and RIH, located and~vas able to stab into box on lower't. at 992'. PU Kell . 22:30 00:00 1.50 COMPZ FISH JAR T After torquing up work string, sat down and jarred up to verify packer & PBR were still stuck. Rotated and straight pulled up to 200K. Well static. 11/26/2007 00:00 01:30 1.50 COMPZ FISH JAR T Continued to attempt to rotate and jar free, max. jar @ 210K and max. straight pull @ 255K. No movement, 'ars ettin weak. 01:30 02:30 1.00 COMPZ FISH CIRC T Circulated to conditon hole. P~ye b of 12 ~~ Time Logs --- - Date From To Dur _ S__._D_epth E. De th Phase Code Subcode T COM __ __ __ _ 11/26/2007 02:30 03:00 0.50 COMPZ FISH JAR T Up wt. 110K Rotate wt 75K Dwn wt 60K. Trip jars 2 to 3 times at 100K over, pulling up to max 250K. Bumped down to release grapple. Pulled back up to neutral wt. Rotate to right and breakover @ 7 rounds torque 8K. Move up in 5K increments attempted to rotate grapple off fish. Pulled up to total of 25K over, maxed out torque @ 12.5K. No success. Attempted this several times with and without pump on. Went back to jarring with no success. ND Kell . 03:00 06:30 3.50 COMPZ FISH CIRC T Circulate hole while contacting and discussin o tions w/ town en ineers. 06:30 10:30 4.00 COMPZ FISH ELNE T Stand Kelly back. RU SWS tools to run CCL, Gamma Ray Press. Temp log. 1 11/16" tools went thru Pump-out-sub (1 13/16") with no problems. Tagged up at 8038'. Located all BHA, tubing stub, 6' pup jt, PBR, FHL packer, and tbg tail with no gaps etc. Everything on depth with drill pipe tally. POOH with wireline. NU Kell . 10:30 12:30 2.00 COMPZ FISH JAR T Up wt. 110K Rotate wt 75K Dwn wt 60K. Trip jars 2 to 3 times at 100K over, pulling up to max 250K. Bumped down to release grapple. Pulled back up to neutral wt. Rotate to right and breakover @ 7 rounds torque 8K. Move up in 5K increments attempted to rotate grapple off fish. Pulled up to total of 25K over, maxed out torque @ 12.5K. No success. Attempted this several times with and without pump on. Went back to jarring with no success. ND Kell . 12:30 00:00 11.50 COMPZ FISH ELNE T Rig SWS up again and RIH with 3 strand stringshot. Could not get thru um out sub -7700'. Attempted to work thru with no success. POOH with string shot. Adjust end to make it go thru easier. Run back in hole. Could not get thru the pump out sub again, POOH. Shortened up the string shot to 8' and added as short centrilizer and a more tapered bullnose. RIH, still could not Qet down. POOH w/SWS. 11/27/2007 00:00 01:00 1.00 COMPZ FISH ELNE T POOH and rig back SWS. Crew was sent into et 8 hours of rest. Paga ~ of 12 Time Logs ~' _! Date From Tn Diir 5. Depth F Depth Phase Cede ~uhrorle T Ct7M 11/27/2007 01:00 12:30 11.50 COMPZ FISH CIRC T Make up Kelly and began circulating at 3 BPM to condition hole and then slowed rate down to 1 BPM @ 560 psi. while rotating @ 28 rpm w/ 8k to 12k torque. Shut down and hang back kell . 12:30 00:00 11.50 COMPZ FISH ELNE T RU SWS w/ 1 11/16" OD Spring bull nose, 6' x 1 11/16" wt bar, gr x 8' string shot w/ 2 x 6' wt bars and ccl. Rih and wasn't able to get thru. Pooh and change out design by adding centralizer and dropping 1 wt bar. RIH w/ 3 strand stri un, able to et down, tied in and made the shot across the seal assembl while pulling n m vement. POOH and verified that the gun did fire, made up a 4 strand gun w/the same configuration. Straight pulled to 275K no movement, begin circulating while making up the new un. 11/28/2007 00:00 02:30 2.50 COMPZ FISH CIRC T Continue to circulate and condition the hole. 02:30 06:30 4.00 COMPZ FISH ELNE T PU and RIH w/ 1-11/16" OD Spring bull nose, 6' x 1- 11/16" wt bar, 8' string shot w/ 1 x 6' wt bar,CCL, and 1 bow spring centralizer. Had trouble getting down thru the pump out~JOt down, tied in and shot, shot interval w 06:30 08:30 2.00 COMPZ FISH JAR T PU/MU Kelly. Work stuck pipe rotating @ 13k max torque and jarring @ 110 k osw of 110k up wt. Break out and hang back kelly. RU bails and elevators. 08:30 13:30 5.00 COMPZ FISH ELNE T Pull and land in slips @ 50k osw of 110k. Hang sheave and and MU split shot and Rih to 8030' and tie in and shoot across 3.5" tb collar 8012.5' wlm. Pooh and RD wireline. 13:30 17:00 3.50 COMPZ FISH JAR T Work pipe up to 140k osw of 110k up wt. cart @ 3 bpm @ 860 psi close bag and pressure up to 1000 psi and bled down to 950 psi in 15 minutes and held. Bled off and blow down land tb 140k osw of 110k u wt. 17:00 21:00 4.00 COMPZ FISH ELNE T RU wireline and MU split shot #2 and Rih to 8030' wlm and tie in. Set shot across tb collar 8012.5' wlm and shoot. Pooh. 21:00 23:00 2.00 COMPZ FISH JAR T PU out of slips, not free, PU Kelly and perform derrick inspection. Jar at 210K and pull to 275K, rotated and 'arred. No success. Page 7 caf '12 Time Logs _ _ _ ___ _ Date From To Dur S. De th E . De th Phase Code Subcode T COM 11/28/2007 _ 23:00 00:00 1.00 __ _ _ COMPZ FISH CIRC T _ _ Begin circulating at 3 BPM @ 850 psi. to condition hole before attempting to back off. 11/29/2007 00:00 01:00 1.00 COMPZ FISH CIRC T Continued to ciruulate at 3 BPM @ 850 si. to condition hole. 01:00 04:00 3.00 COMPZ FISH CPBO T Attem ted blind back off from fish, backed off 7' pup from the 20' pup, just below jt. # 1. Stabbed back into the 20' pup w/ jt # 1. Rotate to torque up the work strin . 04:00 10:00 6.00 COMPZ FISH CIRC T Attempt to reverse circulate, got returns pumped 3 tubing volume, switched to long way and pulled 140k osw of 110k and worked down. Attem ted to release overshot rotated u to 7k for ue and became free. Pump hi visc sweep and recipricate work string. Had to condition mud after sweep due to out of balance. Blow down and hang back kell 10:00 21:00 11.00 COMPZ FISH TRIP T Pooh checking middle connection torque, had 10 U 20k over pull while comin out of the hole. 21:00 00:00 3.00 COMPZ FISH PULD T Lay down BHA, clean up floor and prepare for BOPE test. State witness waived Chuck Scheeve (AOGCC) on 11/29/07 @ 09:00 hrs. per phone conversation. Note: Found that the shoe was swelled and split from the split cutter shots, the tubing stub was torn but not excessively. Well static. 11/30/2007 00:00 11:30 11.50 COMPZ WELCT BOPE P BOPE test, Annular to 250/2500 psi. and rams to 250/4000 psi. State witness waived Chuck Scheeve (AOGCC) on 11/29/07 @ 09:00 hrs. er hone conversation. 11:30 13:00 1.50 COMPZ FISH PULD T Install wear ring. PU Clean out BHA 13:00 20:00 7.00 274 4,000 COMPZ FISH TRIP T Rih conditioning mud every 2000'. 20:00 22:00 2.00 4,000 COMPZ WELC EORP T PU Kelly, change out and test upper Kell valve at 4000'. 22:00 00:00 2.00 COMPZ FISH TRIP T Continue to reverse circulate and condition mud every 2000'. Continue to RIH. 12/01/2007 00:00 10:00 10.00 4,000 8,013 COMPZ FISH TRIP T Continue to RIH stopping every 2000' to condition the hole f/ 4000' to 8013'. Kell u . 10:00 10:30 0.50 8,013 8,021 COMPZ FISH WASH T Gather Parameters: 95k up wt, 63k do wt. 75k Rot @ 20 rpms @ 6400 fUlbs free torque. Work over stub Cad 8013' to top of PBR @ 8021'. Pull up and was not able to et back over stub. Pa~e$of12 Time Logs -- __ From To Dur D~te _ S De th E. De th Phase Code Subcode T COM ___ _ 12/01/2007 10:30 13:30 ___ 3.00 8,021 8,013 COMPZ FISH CIRC T _ Reverse circulate and @ bottoms up had 14.9 ppg mud wt returning. Condition mud till 14.5 coming and going. pressure test to 1000 psi and held. Bleed off. 13:30 22:30 9.00 8,013 0 COMPZ FISH TRIP T Blow down and hang kelly back. Pooh 22:30 00:00 1.50 COMPZ FISH PULD T OOH, swap out BHA, clean up and clear ri floor, and re are to RIH. 12/02/2007 00:00 08:00 8.00 0 8,000 COMPZ FISH TRIP T RIH w/ Rollin Do overshot A fish the collar. 08:00 12:00 4.00 8,000 8,026 COMPZ FISH FISH T Kelly up and obtain parameters: 105k up wt, 65k do wt, 75k rot wt @ 10 rpms w/ 6250 ft/Ibs free torque. SPR: 3 bpm @ 800 psi, 2 bpm @ 620 psi, 1 bpm @ 510 psi, & Rotate over stub, and engage tbg collar Ccil 8012' w/ insert and begin to pressure up. Bleed off and work bumper sub, pushing insert over tbg collar. Wash down to 8026'. Circulate bottoms up and condition mud 14.5 ppg coming and going. Pull 10k osw of 105k and allow jars to bleed off. work up to 40k osw of 105k in 10k increments before pulling free. Pooh and break off kelly and blow down circ a ui ment. 12:00 19:00 7.00 8,000 0 COMPZ FISH TRIP T Pooh to BHA and stand back DC's and break down rolling dog over shot. Recovered nothin do s where sheared. 19:00 22:00 3.00 0 COMPZ FISH WOOR T Conference call w/ town engineer and fishing reps to discuss several options and senarios. 22:00 00:00 2.00 COMPZ FISH PULD T PU/MU BHA w! overshot, drilling jars, and stinger( Dailey accelerator), laid down 2 collars. 12/03/2007 00:00 08:30 8.50 260 8,000 COMPZ FISH TRIP T Finish making up overshot fishing BHA, laid down 2 collars and added Dailey drilling jars and slinger(Dailey accelerator). RIH to 8000' and kelly u. 08:30 09:00 0.50 8,000 COMPZ FISH CIRC T Reverse circulate bottoms up and condition mud wt. to 14.5 ppg. Had 15.0 bottoms u . 09:00 18:00 9.00 COMPZ FISH JAR T En a e fish and 'ar down 45k and Jar up @ 85k osw of 105k. Dead pull to 170k osw of 105k. Ha no m .Set Kelly back w/ 175k in the slips and RU to circulate while Pre arin for slickline. 18:00 21:00 3.00 COMPZ FISH CIRC T Circulate to condition hole until mud wt = 14.5# in/out. 21:00 00:00 3.00 COMPZ FISH SLKL T RU and RIH w/slickline to drifUtag. Could not et down due to heavy mud at -7820' WLM. POOH. P~c~~9of12 r~ Time Logs Date ___, From To Dur S. De th E. Depth Phase _ -Code Subcode _ T__ COM __ __ 12/04/2007 00:00 00:30 0.50 COMPZ FISH SLKL T Cont. to POOH, could not get down due to hea mud, 7820' WLM. 00:30 03:30 3.00 COMPZ FISH CIRC T Stand back slickline and begin circulating to condition hole. 14.5 in/ 14.9+ out, reverse circulated until 14.5 in/out. 03:30 07:00 3.50 COMPZ FISH SLKL T PU slickline and RIH, tagged high again @ -7870'. POOH and release slickline. 07:00 08:30 1.50 COMPZ FISH CIRC T Reverse circulate @ 2.75 bpm @ 950 psi and condition mud until 14.5 ppg returned. 08:30 11:30 3.00 COMPZ FISH JAR T Attempt to release off of fish. gained 2' of movement compared to prior movement. Rotate righthand torque to release from fish with no luck. Max for ue seen was 10k ft/Ibs. 11:30 14:30 3.00 COMPZ FISH CIRC T Reverse circulate 2.75 bpm @ 950 psi and condition mud. Circulate @ 4 b m 1400 si. 14:30 19:30 5.00 COMPZ FISH JAR T Attem t to work free from fish, Rotating @ 80 rpm's w/ 12-13,000 fUlbs of torque, working string from 100k to 30k. Circ @ 3.0 bpm @ 1030 psi, Rotating @ 75 rpm's w/ 12,000 ft/Ibs for ue w/ strin wt of 100k. 19:30 23:30 4.00 8,012 8,005 COMPZ FISH CPBO T Attempt blind back off and backed off @ lower kelly cock and jt# 250. Screw back in and torque to 12,000 ft/Ibs. working torque down from 100k to 20k string wt. Jar @ 85k osw of 115k and dead pull to 160k osw of 115k. Jar 1 time @ 110k osw of 115k and came free w/something. Monitor well and set back kell . 23:30 00:00 0.50 8,005 COMPZ FISH OTHR T Inspect derrick and hang blocks. Ins ect and fill wt indicator. 12/05/2007 00:00 01:30 1.50 COMPZ FISH PULL T Pooh laying down jts 250 and 249. RU to Reverse circulate. 01:30 02:30 1.00 COMPZ FISH CIRC T Reverse circulate bottoms up @ 3 b m 920 si. RD circ a ui . 02:30 11:15 8.75 8,005 COMPZ FISH TRIP T Pooh checking middle conn. torque. 11:15 15:30 4.25 0 COMPZ FISH PULD T Break down BHA. Stand back drill collars. Note: 4.6' of inner packer ,mandrel retrieved PRR ~nnca=tp_ have never moved-original space out evident. Begin break down of overshot/PBR/inner packer mandrel for pictures. During POOH standard fluid fill -- no losses. Call Anchorage for Ian forward. t~asl~ 9i} rt 12 Time Logs ___ Date From To Dur 5 De th E. De th _ Phase Code Subcode T COM 12/05/2007 15:30 23:00 7.50 COMPZ RPCO WOOR P Clean rig. Prepare for re-complete. Call for RHC install. New GLV with DMY check called for. Call for HES to install in pipe shed. Mandrel in pipe shed for intall when HES arrive. Gather the rest of the completion e ui ment to Rih w/ FHL Packer. 23:00 00:00 1.00 0 101 COMPZ RPCOti TRIP P Pull wear ring and PU Mule shoe w/ 10k shear, 1 jt 3 1!2 L-80 AB Mod., DS Nipple w/ 2.813" ID W/ RHC PLug w/ CR Lock installed, 1 jt 3 1/2 AB Mod., 4' Pupjt, FHL Pkr, 80-40 PBR, 8' Pu ~t, X-O 12/06/2007 00:00 08:45 8.75 101 COMPZ RPCO TRIP P RIH w/FHL Pkr Com letion 08:45 10:00 1.25 COMPZ RPCOti TRIP P Sat down on old packer (-6 ft high from tally) with 20,000#. Did not see a definite shear of the pins on the mule shoe. Picked up 15 ft, witnessed slight friction bite to move pipe. RIH pumping at 470 psi, stab back in at previous mark, press increased to 780 psi before pump was stoped. Held ressure. 10:00 12:00 2.00 COMPZ RPCO CIRC P Picked up pipe, reverse circulate 1.5 volumes of drill pipe. RIH while reverse circulating at 500 psi, stabbed back in at previous mark. Pressure increased to 740 psi before pump was shut down. Pressure held. Sat down 10,000#. PU to free wei ht 65,000#. 12:00 13:00 1.00 COMPZ RPCOh PACK P Dro rod and ball. Pressured tubing up to 2500 psi, set packer. Pressure test tubing to 2500 psi, Set packer w/ ~ to of PBR 7947', to of kr 961' bottom of kr 7968',and DS Nipple @ 8003' w/ RHC PLUG INSTALLED and stabbed into previous pkr body @ 8036'. THE MULESHOE @ 8036' has (3 - .375 x 16 brass shear screws inside and out w/ 3565 Ib shear per screw totaling 10,695 Ib shear) bleed tubing down. Pressure test IA to 1000 si, bleed IA down. Pressure up tubing to 2000 psi, pulled out of PBR with 90,000#. 13:00 13:30 0.50 COMPZ RPCOh CIRC P Pull up and circulate bottoms up. 13:30 15:00 1.50 COMPZ RPCO TRIP P POOH and laying down drill pipe. 15:00 16:00 1.00 COMPZ RIGMN RGRP T Shut down to replace load cell for blocks. 16:00 00:00 8.00 COMPZ RPCOh TRIP P Continue to Pooh laying down 3 1/2 IF DP, w/ 50 jts laid down PU Kelly and break conn, hang back kelly and continue to POOH La in down DP. Pane 11 ssf 1~ r~ _ Time Logs _ -- - ---- ---_ Date Frorn To Dur S. Depth E. De th Phase - Code Subcode T COM __ _ 12/07/2007 00:00 07:00 7.00 COMPZ RPCOh TRIP P Continue to Pooh laying down 3 1/2 DP and kell . 07:00 17:30 10.50 COMPZ RPCO RCST P DP Layed down. Pick up and RIH with com letion. 17:30 19:45 2.25 COMPZ RPCOh RCST P Completion run, up wt 65,000#. RIH wt 45,000#. Sat down 10,000# and marked. POOH 20 ft, RIH pumping @ 540 PSI. Pressure increased 11.5 ft shallow of mark to 1100 psi before pump was shut down. Landed com letion with 1 ft s ace out. 19:45 20:15 0.50 COMPZ RPCO DHEQ P Pressure tested tubing and casing in combination to 1000 psi. Bleed off `~ and set BPV. 20:15 00:00 3.75 COMPZ RPCO OTHR P Wash drlg mud from stack and clean and clear ri floor. 12/08/2007 00:00 01:00 1.00 COMPZ RPCOM1 OTHR P Continue to clean and clear rig floor of drl mud. 01:00 10:00 9.00 COMPZ RPCO NUND P Held PJSM on ND BOPE and NU Tree. PT test tubing packoffs to 5000 `~ si. Test tree to 250/5000 si. 10:00 18:00 8.00 COMPZ RPCOh CIRC P Held PJSM. Rigged up and pumped to displace 14.5 mud to 9.6 brine from the IA and tubin . 18:00 19:00 1.00 COMPZ RPCOh NUND P RU Lubricator and Set CIW 3" BPV w/ 1500 psi wellhead pressure. RD Lubricator. 19:00 00:00 5.00 COMPZ RPCOti OTHR T Wait on 3x2 X-O for Vac hose. Wash and clean drlg mud from rig pits. Released ri 24:00 hrs on 12-8-07. Page 12 of 12 . 2G-06 Well Events Summary DATE Summary 12/16/07 BAILED DRILLING MUD f/ 4602' TO 4699' SLM. JOB SUSPENDED. 12/18/07 Perform Mud Cleanout, RIH with 2.1 JSN pumping S/W to 7950 CTMD, Pumped 110 diesel down IA with hot oil taking rtns out tubing, Displaced Well with Diesel, left S/I. 12/23/07 PULLED BALL & ROD (LOST BALL) IN PROGRESS 12/24/07 BAILED MUD FROM RHC PLUG BODY @ 8011' RKB, IN PROGRESS 12/25/07 BAILED ON RHC PLUG BODY, IN PROGRESS 1/3/08 STBY for weather phase 2 conditions. STBY for snow removal. Perform weekly BOPE test. 1/4/08 Removed RHC from nipple profile @ 8,000' CTMD. (NOTE) Ball accounted for. Cleaned out mud to 8,055' CTMD. Well freeze protected to 2,000' with 100% meth. 1/5/08 TAGGED W/ 2.75 IMPRESSION BLOCK @ 8159' SLM. PULLED CV @ 7929' RKB AND SET DGLV. MITIA TO 2500 PSI (PASSED ). 1/6/08 TAGGED HARD MUD @ 8158' SLM (APPEARS THAT LOWER PACKER FROM OLD COMPLETION, PXX PLUG, AND REST OF TBG. DOWN TO WIRELINE RE-ENTRY GUIDE IS IN FILL ). 1/10/08 RAN PFCS AND PMIT CALIPERS. LOGGED PASSES WITH PFCS/PMIT-A FROM 8170- 7900'. RESULTS: jUBING SEPARATED AT MULESHOE/FHL PACKER AT 8048'. REMAINDER OF TUBING TAIL APPEARS TO BE COVERED BY FILL. 1/21/08 SET 3" CATCHER SUB (2.75" BAIT SUB,2' X 1.875" STEM & 2.85" G.RING/ OAL= 56.5") @ 8011' RKB. PULLED DMY VLV @ 7247' RKB. REPLACED WITH 3/16" ORIFICE VLV. PULLED DMY VLV @ 6154" RKB. REPLACED WITH GLV (.188" PORT/ TRO= 1303). JOB IN PROGRESS. 1/22/08 PULLED DMY VLV @ 4753' RKB. REPLACED WITH GLV (5/32" PORT/ TRO= 1273). PULLED DMY VLV @ 2851' RKB. REPLACED WITH GLV (1/8" PORT/ TRO= 1240). PULLED CATCHER SUB @ 8011' RKB. JOB COMPLETE. 2/12/08 TAGGED MUD IN TBG @ 7707' WLM. JOB COMPLETE. 2/22/08 CLEAN DOWN TO TOP OF PACKER @ 8148' CTMD. CIRCULATED WELL UNTIL RETURNS WHERE CLEAN. SEEN LARGE AMOUNT OF DRILLING MUD DURING WELL SWEEPS. SHUT IN AND FREEZE PROTECT. JOB COMPLETE. • Conc~~4Phillips Ataska, lnc. 2G=os __~_ ._ API 50029211210( Tue+NG SSSVType. NIPPLE (o-8oaz, OD:3.500, ID:2.992> Annular Fluid: Last Tag Date: 16/7/2006 I Casino String -ALL STRINGS • KRU 2G-06 Well T e: PROD An le TS: 38 de 8093 Orig 6/18/1984 Angle @ TD: 36 deg @ 8485 Com letion: Last W/O: 12/10/2007 Rev Reason: WORKOVER Ref Lo Date: Last U date: 12/10/2007 TD: 8485 ftK6 Max Hole Angle: 155 deg (o7 4000 Descri tion Size To Bottom TVD W< Grade Thread CONDUCTOR 16.000 0 110 110 62.58 H-40 Welded SUR. CASING 9.625 0 6164 4593 36.00 J-55 BTC PROD. CASING 7.000 _ 0 8449 - _ _ 6224 26.00 J-55 BTC Tubing String -TUBING _ _ J Size To Bottom TVD Wt Grade Thread 3.500 0 8042 5898 9.30 L-80 8rdEUEABMOD 3.500 _8042 8081 5928 9.3(1 ~ JJ-5 _ _ BTC ! Perforations Summary _ _ Gas Lift Mandrels/Valves mrerva~ ~ vu cone acaws rc arr uare i ~.ommem 8188 - 8198 6013 - 6021 A-5 10 4 9/24/1988 IPERF 90 deg. Phasing; 4" Schlumber er Casi 8216 - 8246 6036 - 6060 A-4 30 4 9/24/1988 IPERF 90 deg. Phasing; 4" Sr`hiumberrJer Casi ar mu i vu man mrr man i ype v mrr v i ype v vu ~arcn rorc i nu uses nun vnr Cmnt 1 2851 2589 Cameo KBMG DMY 1.0 BK-5 0.000 0 12/5/2007 2 4753 3737 Cameo KBMG DMY 1.0 BK-5 0.000 0 12/5/2007 3 6154 4587 Cameo KBMG DMY 1.0 BK-5 0.000 0 12/5/2007 4 7247 5311 Cameo KBMG DMY 1.0 BK-5 0.000 0 12/5/2007 5 7929 5811 Cameo Other Plugs, equip,, etc De h TVD T e KBMG DMY 1.5 BK-5 0.000 .) -COMPLETION........ Descri ion 0 12/5/2007 _ _ ID 521 521 NIP CAMCO DS Ni le NO GO 2.875 7955 5831 PBR BAKER 80-40 PBR sheared w/40 K, s aced out 1' above 2.980 7968 5841 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 8011 5874 NIP CAMCO DS NIPPLE CR LOCKw/RHC PLUG BODY 2.813 8042 5898 PKR BAKER 3.5" x 7" FHL Retrievable Packer, 2.850 drift 3.030 8069 5919 NIP OTIS'X' NIPPLE WITH 2.75" SELECTIVE PROFILE **WARNING** DO NO USE THIS NIPPLE 2.750 8069 5919 PLUG 2.75"'XX' PLUG set 6/17/2006 0.000 8081 5928 SOS BAKER Wireline re-entry Guide 2.992 General Notes ~ Date 1 Nole _ ~ 2/If 10/200 NOTE: ** MIT TESTING WILL HAVE TO USE DS NIPPLE Cad 8011' *** ~ I TUBING (8042-8081, OD:3.500, tD:2.992) Perf (8188-8198) Perf (8216-8246) gyp~py{, k ~ ~' .. 4' p~ r ("~44~? Schlumberger -DCS `1 ` ' ~~ ~ , 2525 Gambell Street, Suite 400 , Anchorage, AK 99503-2838 ATTN: Beth , ~ ~~a~b'0 ~~.~ s. ~. ~~~~' Well Job # Log Description C. ~-- NO.4564 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 01 /25/08 2B-13 11996584 PRODUCTION PROFILE ~jL ' Jp 01/10108 1 1E-112 11994598 INJECTION PROFILE v~ - ~{ 01/11/08 1 1J-164L1 12005203 MEM INJECTION•PROFILE ~d5 - ~ ~ ~~ 01122108 1 2M-20 11996596 PRODUCTION PROFILE -(~~( 01/22108 1 1C-170 11970605 USIT 12/02/07 1 2G-06 11994596 PSP MULTI-FINGER CALIPER - 01/10/08 1 3K-102 11994599 MDT ~ - 01/14/08 1 1J-127 11994603 INJECTION PROFILE (~_.~ ~p(o-pt(~- 01/21/08 1 2T-21 11839639 RST 1 ~ 08/02/07 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. • C] lb 2G-06 Well Control Incident Page 1 of 2 • • Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Friday, November 23, 2007 10:22 AM To: Maunder, Thomas E (DOA) Subject: RE: 2G-06 Well Control Incident Attachments: 2007-1119 BOP Nabors3S KRU 2G-06.x1s BOP test attached; note that they did not test the accumulator either before pulling the tubing. Jim Regg ~ ~u _^~ AOGCC - ` ,v 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ..-.-- From:. Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, November 21, 2007 8:28 AM To: aogcc_prudhoe_bay@admin.state.ak.us Subject: FW: 2G-06 Well Control Incident FYI. It was not intended to pull the packer. `~~~`~~~ MAY ~, ~ 2~~8 From: Gober, Howard [mailto:Howard.Gober@conocophillips.com] Sent: Tuesday, November 20, 2007 5:37 PM To: Maunder, Thomas E (DOA) Cc: Cawvey, Von; CPA Wells Supt; Thomas, Randy L; Ennis, J J; Packer, J.Brett; Cheng, Carl L; Jackson, Darron B.; Burd, lames A; CPA Wells Supt; Yoakum, Vance D. Subject: 2G-06 Well Control Incident Tom, Here is a recap of the events on 2G-06 along with our plan forward as we discussed earlier today. 2G-06 is a Kuparuk A sand producer that has several tubing leaks. A successful combo MIT was performed when the tubing tail plug was set on 11/15/07. The reservoir pressure was measured on 11/13/07 at 4387 psi mid pert (14 ppg). The plan was to use a plug below the packer to isolate us from the perfs and utilized 9.6 ppg brine for a workover fluid. The BOP stack has the 2nd set of pipe rams due to the high reservoir pressure. They have not been tested yet due to the clearance between the rams and the blanking plug in the hanger. We were going to test the lower rams once we had the hanger laid down. Here are the sequence of events on this well: 0 11/18/07 MIRU Nabors 3S 0 11/18-11/19 circulate in 9.6 ppg brine. Had to weight up to 9.8 ppg to get the tubing and IA in balance. The tubing holes were hampering our efforts to get a consistent fluid density in the wellbore 0 11/19 0645 Set BPV. ND tree. NU BOP with extra set of pipe rams. 0 11119 1400 Test choke and double gate BOP to 250/3900 psi. Test annular to 250/2500 psi. Could not test lower pipe rams due to clearance issues. 0 11/19 1800 Pull blanking plug and BPV. 5/25/2008 2G-06 Well Control Incident • • Page 2 of 2 0 11/19 1900 MU landing joint in hanger. Pull up on hanger. Acting like the seals were pulling and then it started taking weight. Worked up to 155k and suddenly the weight went to 70k and then 40k. PU to position for shut in and the well began to flow. SI with 1300 psi on the well. Notified John Crisp of the situation at 2100. Ordered 14.5 ppg mud. 0 11!20 Received mud mid-morning and began pumping the 14.5 ppg fluid. It appears we are getting circulation down to the open GLM just above the packer. Currently have 14.5 ppg going in and 14.3 ppg corning out. Plan Forward o Make sure well is dead. o Pull a couple of joints to see if the packer is going to swab. o MU test plug and land in tubing head. Test annular to 250/2500psi. Test lower pipe rams and choke skid to 250/3900 psi. o If we are not swabbing, continue to POOH laying down tubing. o If the well is swabbing, RU E-Line and shoot tubing punches between the packer and the tubing tail plug. Please give me a call if you have any questions or if you need more information. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard.Gober@conocophillips.com 5/25/2008 "' STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submat to: Contractor: Nabors Rig Rep.: Gene Sweatt Operator: CPAI Rep.: Rick Overstreet Field/Unit & Well No.: KRU 2G-06 Rig No.: 3S Rig Phone: 659-7594 Op. Phone: 659-7514 PTD # 184-082 DATE: 11 /19/2007 Rig Fax: 659-7055 Op. Fax: Operation: Drtg: Workover: X Exptor.: Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular. 250PL500 Valves: 250/3500 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Re Location Gen.: P Weil Sign P Upper Kelly NA Housekeeping: P Drl. Rig P Lower Kelly NA PTD On Location P Hazard Sec. P Sall Type 1 P Standing Order Posted P Ir~.side BOP 1 P BOP STACK: Quantity Size Test Result CHOKE MANIFOLD: Annular Preventer 1 13 518 5000 P Quantity Test Result Pipe Rams 1 2 7/8 X 5 1/2 P No. Valves 13 P Lower Pipe Rams 1 2 718 NT Manual Chokes 1 P Blind Rams 1 Blind Shear P Hydraulic Chokes 1 P Choke Ln. Valves 1 31/8" 5000 P HCR Valves 2 3 1/8" 5000 P ACCUMULATOR SYSTEM: Kill Line Valves 1 2 1/16" 5000 P Time/Pressure Test Result Check Valve 0 NA System Pressure NT Pressure After Closure NT MUD SYSTEM: Usual Test Alarm Test 200 psi Attained NT Trip Tank P P FuR Pressure Attained NT Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 0 Test Time: 4 Hours Components tested Repair or replacement of equipment wiH be made within Done days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: Remarks: John Crisp wavied testing of bottom rams ~ accumtator until! out of hole with tubing. 24 HOUR NOTICE GIVEN YES x NO Waived By Bob Nobel Date 11/18/07 Time Witness G.Sweatt Test start 14:00 Finish 18:00 BOP Test (for rigs) BFL 11/14/07 2007-1119 BOP Nabors3S KRU 2G-06.x1s Page 1 of 1 Maunder, Thomas E (DOA) From: Crisp, John H (DOA) ~~-~=°~~,'~ ~ ~ e~.c~r e~ Sent: Tuesday, November 20, 2007 1:46 AM ~~'~`~'~-.'T-his ~~S c`~i~' @~Csn~ To: Regg, James B (DOA) ~~ ~t ~ Cc: Maunder, Thomas E (DOA) Subject: Welt control KRU 2G-06 & \ Got a call about 2100 hrs. from Nabors 3S on KRU 2G-06 that the weft was shut in with Annular preventer, 1300 psi surface pressure. The well flowed when the packer was pulled loose. They are having 14.5 kill weight fluid made & trucked to the Rig. My understanding is present mud wt. ~a? g.5 ppg. The Operator Rep. stated the circulation would probably begin morning 11/20/07. They also stated that lower pipe rams were not tested previous to attempted tubing POOH. 110 hrs. 11/20/07 from Doyon 15 on KRU 1 J-174 that total circulation was lost while a to cement a ca oreman stated that calculated surf I to{d the Foreman that t othin I co him, that i understanding cement to su em k for the life of the fief ore v had 1" not help him from e n state ey had to ad & they needed no help. The calf was just notifica ' e me eir tap J e Fareman that cement to surface was State en a problem for the life o e to witness. I told_h' e p ftom the Fietd. 1 don't know if permission had been granted from AOGCC Ancho o top off this welt, they just stated they needed no help from me. is top job common on KRU 1 J Pad? I know of nothing else thay could do Q this point without Tam collar or 2 stage cement job, it just seemed like they considered the top job SOP. ~~ J~R~i~ i~o~ 4~ ~~~ i . . RECEIVED WELL LOG TRANSMITTAL AUG 2 9 2006 PRoAcTiVE DiAGNOSTiC SERvicES, INC. Alaska Oil & Gas Cons. Commission Anchorage To: AOGCC. Attn: Ceresa Tolley 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501-3539 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 : ProActive Diagnositc Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 - 8952 1J 2J 3J 4J 5J 6J 7J 2G-06 Caliper report 12-Jul-06 SCANNED AUG 3 0 2006 Print Name: ¿QL-- C [I r ¡-?(-h /) ~ (hDj,U1.)< e. (A Date: 0/ ß1r/?h I Signed: PRoACTivE DiAGNOSTic SERvicES, INC., I ~o W. INTERNATioNAl AiRpoRT Rd SuÎTE C, ANChoRAGE, AK 99 ~ I ß PIIONE: (907)24~/ß9~ I FAX: (907)245/89~2 E/MAil: 1!billidIQRI\!iL@MLM!!!\YJmi,!QM WEbsiTE: MEMoRyloG.COM ! 1~4~o~é3- C:\My Documents\ W ork\ DistributionLablesNewl Transmit_ Original.doc I I I I I I I I I I I I I I I I I I I . /ti/- Dad- . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. July 12, 2006 8041 2 3.5" 9.3 lb. Tubing Well: 2G-06 Field: Kuparuk State: Alaska API No.: N/A 6"b-a9'1-911,g.t-Oó Top Log Intvl1.: Suñace Bot. Log IntvI1.: 8,075 Ft. (MD) Inspection Type : Co"osive & Mechanical Damage Inspection REeEtVEfT COMMENTS: AUG 2 9 2006 ~OH & Gas Cons. Commission Anchorage This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damages. The 3.5" tubing logged appears to be in good to poor condition with respect to corrosive damage. Holes and possible holes are recorded in joints 92 (2,896'), 93 (2,913'), 94 (2,953'), and 43 (1,356'). Penetrations in excess of 20% are recorded in 214 of the 271 joints analyzed. The damage appears in the forms of isolated pitting, lines of corrosion, and general corrosion. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the 3.5" tubing interval logged. This caliper data is tied into the Tubing Hanger @ 0' Depth. This is the second time a PDS caliper has been run in this well, the first of this tubing. A comparison between the current and previous log (September 23, 1999) indicates a change of the tubing string. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum - recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WAll PENETRATIONS: Hole Hole Possible Hole Possible Hole Line Corrosion ( 100%) ( 100%) ( 91 %) ( 86%) ( 83%) 92 @ 93 @ 94 @ 43 @ 103 @ 2,896 Ft. (MD) 2,913 Ft. (MD) 2,953 Ft. (MD) 1,356 Ft. (MD) 3229 Ft. (MD) Jt. Jt. Jt. Jt. Jt. MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No significant areas of cross-sectional wall loss (> 9%) are recorded throughout the tubing interval logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded throughout the tubing interval logged. I Field Engineer: R. Richey Analyst: M. Tahtouh ~rtness: T Senden ProActive Diagnostic Sen¡ices, Inc. I P.O. Box 1369, Stafford, T>< 77497 Phone: (2.81) or 565-9085 Fa>;: (281) 565-1369 E-mail: PDS(ã:memorylog.com Prudhoe Bay Field Office Plìone: 659-2307 Fa;<: 659-2314 I I I Well: Field: Company: Country: 2C·06 Kuparuk ConocoPhíllips Alaska, Inc. USA Survey Date: fool Type: fool Size: No. of Fingers: July 12, 2006 i\1FC UW 24 No. 211387 1.69 24 I I loss ("I" wall) I Iwnetration body metal loss body penetration 300 2.50 200 150 I CLM 1 ¡OO I 50 o o to 1% 10 to 20% 40 to over 85% 85% 1 to 10% I 1055 19 o o o I Damage Configuration I CLM 2 200 CLivI 4 150 I 100 GlM 3 I 50 o I Isolated pitting w'nera! !me ring hole / po')') corroSIon COfTOS!On CO!TOS!On ¡blp hole GlM 5 Damage Profile (% wall) metal 1055 body 50 100 Bottom of Survey = 254.5 89 o 4 I I I Analysis Overview page 2 I II I I Pipe 1 I I I I I I I I I I I I I I I Bottolll of I I Recorded Borehole 3.5 in (0.3' - 8069.2') Well: Field: Company: Country: Survey Date: 2G..o6 Kuparuk ConocoPhillips Alaska, Ine. USA July 12, 2006 Approx. Tool Deviation Approx. Borehole Profile GlM 1 GUv\2 GlM 3 -----~ ClM 4 - GlM .5 --- 2.54..5 o 50 Damage Profile (% wall) / Tool Deviation (degrees) 254..5 14 ì77 1555 2336 3130 3912 ,:t c: 4687 5487 6284 7050 7853 8069 100 I REPORT JOINT U ON SHEET I Pipe: 3.5 in 9.3 ppf 1.-80 Well: 2G-06 Body Wall: 0.254 in Field: Kuparuk Upset WaHl 0.254 in Company: ConocoPhiUips Alaska, Ine. I Nominal 1.0.: 2.992 in Country: USA Survey Date: July 12, 2006 I loint Jt. Depth Pen Pen. Pel !\îetíl Min Profile No. (Ft.) I I.D. Comments wall) ill I (Ins.) (Ins.) 0 50 100 .1 0 0 0.01 I 2.96 PUP I I I 4 !J ! 3 2.93 Isolate( nitting. L1 V'i 0 I 1 PUP Shallow U 4') II 1 Pi P Shallow Ditting. I } ')') I) 2 Isolate( DiuilN. I 3 1'\7 !J ! Shallow Dittiml:. 4 119 0 1 .2,.2:1 Shallow Ditting. i I S lS0 0 0.06 ) 3 2.93 Isolated Dittiq&. () 131 I 0.05 3 2.93 Shallow corrosion. I 7 211 0.05 2 2.92 Shallow DittínR. 8 244 ) 2.91. Shallow DiUiml. , 9 276 i) 2.91 Shallow corrosion. 10 107 T91' Shallow Ditting. Lt. Deposits. I 1 ':;39 2.91 Isolate! Ditting. Lt. r ¡pnn"ít" 1 170 pitting Lt. 1 401 !J 0.06 Lt. )pnr""t" I 413 n 0.05 Lt 14.1 ~"'1~t 0 0 0 I Nipn!p I I 1 I) 0.05 19 Lt 1 197 U (W6 22 )iUing. 1.1. De()osits. 1 }29 0 OOS IR 2 Lt. Deposits. 1 }59 0 0.05 )1 S I }90 !J 0.04 16 I 2.92 ., It. ') 0 OJ)5 2 C' 2.92 .5 !J 0.04 16 I 2.91 !J 0.05 19 1 2.9:; I U 0.06 21 I 2.9:; U 0.06 >3 II 2.91 It. I")ply",it" I I ~~.~ U 0.04 17 1 2.91 I I 26 !J 0.08 22 R 2.91 Corrosion. 77 U 0.06 23 I 2.92 Isolated nittil}¡L I 28 U 0.04 ¡ 2 2.93 I 29 903 0.07 29 9 2.93 Corrosion. 1.1. Deposits. 30 934 0.04 ¡ 4 2.93 Sh, lI!w nitting. 11 %5 OJ)6 2 3 2.93 Iso ate! nittìlìQ. I I 12 996 ') ~c~H~ 4 2.92 Iso ate! nitting. '11 1028 .> 2.93 Iso ate! nitting. 14 1059 ') 2.91 Isolate! niUimz. ! 35 109 U 2 2.91 ! I I 36 1121 II 1 41 i~I=¡·91 Isolate! nitting. 17 115:; I) ,n7 21 .91 Isolate! nìttíng. IQ I ì 3.5 Iì !('9 V 22,93 Isolatec nitting. I 39 J214 Iì eLl 8 6 2,2J IsolatecWW:iDlL._.. I 40 !245 I) 0.11 a 2.91 - Isolated nittirlg'-.~..__~~ 41 1277 Iì f)') n I) 2.91 ... Corrosion. 42 1308 n fU5 11 2.92 Line 43 1339 n on Hi B . 2.91 HOLE! 44 1170 n 0.19 76 C' 2.91 Line i.IQHosion. Lt. Deposits. I 45 1401 n 0.19 74 6 2.92 Line , 46 1433 n 0.16 6.5 Fj 2.92 Line i I Body Metal Loss Body Page 1 I I I JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: Nomina! 1.0.: 3.5 in 9.3 ppE L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2 G-06 Kuparuk ConocoPhiUips Alaska, !nc. USA July 12, 2006 I I Joint i Jt. Depth Pi' Pen. Pen Met11 Min. Damage Profile No. (Ft.) 111'9'\ ID. Comments (%wall) I I Ons.) Ons.) 10 50 100 ~- 1463 - () 0.1B 2.90 Line corrosion. Lt. Del2Q~____ 411 ¡49;L__ ..~ 0.1B (, 29i Line corrosion. 49 1 'i2i () 0.19 n 2.92 LiI1e.corm~QIL_._~_ ~~^~~------- SO I'iSS () 0.1 ¡ 2.92 Line corrosion. Lt. Denosits. SI ¡S8e, () .1 I, 2.90 I ilJP ')2 1611i 0 .1 I (. 2.91 IsolMPeI nittinQ I 'ii 1{¡.dc) 0 '.I 2 . 2.91 IsoLllpd oi ttillR.....__.___._..._______._._ 'i4 1{¡liO () 0.10 9 3 2.91 l2.o!at~JJinilw. 'i'i 1711 () .. 0.16 .. 2.91 Corro!¡ion. .... Se, 174-{ () 0.1B I 2.92 1774 () 0.12 2.90 solate( Dittin\!. I 1B04 () 0.14 2.92 ~~~:::~:~ :~:~~::~: It. ~~_.--_.- ^~~^- ~^^._.._..m~ 1B36 () I 2.91 1867 (I 2.91 solate( nittinQ. I I ( 1898 () Isolated Ditting. -~,~...~-_.,...,....~~~_..._....._~.._-~--_. { 1930 () Isolated DittinQ. ( 1961 U O. solate( DininQ. I Y)2 U O. solate( D ttim!. ~3 I) 0.20 solate( D nin\!. ;4 0 0.13 sn"Üpr D nin\!. 0 (1.05 20 ) )q: ,h ,!1m.,· D ttin\!. I ~ II 0 0.20 79 7 2.91 "" l;1tpf D nin\!. ~ 141 0 0.13 53 'í 2.92 "" Lüp( DittinQ. 17' 0 0.17 65 (, 2.93 ",·I"tp( D ttil!Q. ) 0 0.19 76 " )(M ked;>!p, c in\!. tj±-tH- 5a : )Q1 knlMPI C in\!. 53 I, 2.93 !<en !;,tpi c tJim!. 26 ) )q() kn LÜPi ,. tl inu . 1 I 0.07 o 0.07 ) "')()1 k"l;üpi ,. Hinu Lt. rJpnnc;k 76 U .1· I jC)) k" I" Ip, r: tl ing l- n u I I., 2cji ~·I;¡tp, ¡; tJilì\:!. 711 U d ) )()1 Isn IMp, n Him, ! 79 24 0 ! ) )'» 'kn "tp, n Iling SO 241111 0 1 { 2.93 '<n'>N nitting RI 2')20 0 i1 ) 2')~ niHi,w I 82 2')' ;¡ 0 2 41 4 2é)¡ 83 2')82 I) 2 41 4 2c)2 i I rbn<",;'" 114 2614 0 2 4/ I 2.(j{} i5 2646 0 12 I 4 i ) 2(i! 267/ 0 0.12 +=1:~.92 I I 2706 0 0.14 2.92 2718 0 () 2.93 2769 II 0 4 2.91 I"n ;]11'( nining 2801 0 () I 2.91 1,,0 ;¡IPf nitting q .1 283;2 0 () 3 2.91 PUP q .2 2838 0 0 0 ! 0 ! NT.\' CLMI (I ;)tch (ijì! :OOì CJ '{ 2845 0 (H)4 7 2.90 PUP Shallow pitting,_ Lt.X)eposits. 285{) 0 0.21 ß{ 2.92 i inE' I t. P 28112 II 0.47 ¡Of) ( ) c)1 HOLE! n 2911 II 0.26 )00 ) C)) HOLE! "- Body Metal Loss Body Page 2 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I JOINT u ON SH Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in 2G-06 Kuparuk ConocoPhillips Alaska, Ine. USA july 12, 2006 Well: Field: Company: Country: Survey Date: joint jt. Depth Pen. Pen. PE'n I !rvlE';]I Min. Damage Profile No. (Ft.) I i I.D. Comments ('%wall) I (Ins.) I (Ins.) 0 50 100 94 2942 0 n,23 ( 6 2.91 HOLE! I I 9r¡ 2973 OJ I 0.12 ¿ i ~jtt~~1~~ :~:~~::~:'.. ~:~)ep:~~~::----'-- 96 i(){),) ... Ij U)< - :2 I I 97 :mii Ij 10 :2 I 9R ";06R 0 ! :2 2.93 Line corrosion. ~^~ ~_._-~~"_.._....._-~---~~ 99 'i099 0 10( :2 2.94 ' " ~~~~.,---_.~~~--,-~- ---- 10f) ',130 I 0 ,J11l i I I 2.93 Isolated Dittìng. 101 1162 0 0·]5, ¡ 5 2.92 ..ljlle,LC)rrº~QiL,.____,_,_,,__,_,_ 102 -\194 o Og 0.16 ,- 2.91 Line corrosion. líB inS 0 0.21 2.91 l:;ne~"'---"-' . 104 ,256 0 0.16 ¡, 2.90 Line I.t. rÞnn",í¡", I lOr¡ ,2Sf) i OLi Z..2L.. Line corrosion. ¡ t. Depo2Ì~__,~_ I 106 nl8 I o.n I Line corrosion. 107 B50 I 014 ne Lt. npnn",i¡", , 10R 1',82 I 0.14 ne Lt. Deposits. 109 1412 Ij on ne Lt. Deposits. 110 ',444 0 0.1) ne U. npnn",i¡", ! 3476 00: 0.16 61 ne 1 3S06 0 O.IR 72 Line corrosiQ!l. U. Deposits. I 3537 0 O.B 51 Line corrosion. Lt. DeDosits. 1 356R 0 0.14 55 4 L90 ' :. 1 3600 0.0' 0.13 50 e L86 line I t. DeDosits. ~ _0- 1 3630 0 CJ.! 8 70 . 2.91 I inp Lt. DeDosits. 1 jj 0 0.15 59 5 2.91 I inp corrosion. It. DeDosits. II 0 g:iij-j 4 I 2.B8 line It. Deposits. ! 1 l) 0 4 2.91 Line corrosion. ¡ [J 0 is 2.B8 I:' I 0 0.11 4 2.91 I:' ~~" .16 4 2.89 I It. Deposits. 3 0 .1 57 ) 2.90 line corrosion. 3880 0 .1 62 ') 2.90 [" Lt. DeDosits. 39J;2 ¡) .1 ¡)j ') 2.90 Line corrosion., L,t. Qeposit'i, I 126 L n .1 . 4 2:91 lme 127 n .21 B 7 2.90 Lme It. 121'\ 0 .1 4 2.91 Line It. ¡pn""',K I 129 () .1 4 2.91 Line liO 0 .1 3 2.89 lme HI 0 15 it'Li"e Ll li2 41 0 I 0.16 I 4 .91 line U. In 4162 n 0.12 5 line It. Li4 4Fn 0 0.1 4 line corrosion. liS 42)4 i: n 1 'L U¡¡~.CºH·º5iº¡}Œ~[)~Q'Q~ít;~~=" H6 42r¡6 0.1 ) 2,9n. line corrosi.Q11...Jt. D~¡2<lslt5~_~_~_~~~__,.~ FJ7 42S7 0 0.12 4 2.90 lille corrosiQI1._._._..__.._..._..~~~_.,..,.....~~__.. ---_...~~ liS 4i17 0 á12 5 T89 ~ line corrosion. It. DelÆ'>.Ì~__,~_..._ 1 Vi 4348 0 O.I'i 2.U9 Lilliê_Ç(Jffosiolì. Lt DeDosits. 140 4iLB () 0.15 2.89 Litle COItQ5.i9JJ....1LQ§lo?Ü." ~- -- ------ -------- 141 4410 0 (L14 2.88 line corrosion. Lt. Deposits. 142 4440 ( 0.14 2.8R line corrosion. ...~ .~ ~~ I 143 4470 0 0.13 ') ( 2.B9 line .... It'' .: J Body Metal Loss Body Page 3 I RT JOINT TABULATION SH EET I Pipe: 3.5 in 9.3 ppf 1-80 Well: 2G-06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Ine. I NominaII.D.: 2.992 in Country: USA Survey Date: July 12, 2006 I ¡oi It. Depth Pi'll Pen. I PeiL ,'vk,t;·,I Min Damage ProtÎle No. (Ft) Body Comments (% wall) I (Ins) ! (Ins.) 0 50 100 144 4500 'n' II n.14 S Line corrosion. Lt. DeDosits. I I 145 4531 0 n.15 e¡1 Line corrosion. Lt. DeDosìts. I 146 45(;2 0 0.17 6' Une _t. f)c,",nc;k 147 4594 0 0.12 41 3 Isolated DittiD.g, Lt. I 14(J 4624 0 n.09 ) I Isolated Dittil1\z. Lt. DeDosits. I 149 4656 0 n.ll 41 (, 2.86 Isolated Dittilì\I. Lt~~:~: ¡SO 46B7 !) 0.13 S } :¡¡ ISI [ 1S0.1 I 4718 !) 0.03 Î I 15 P¡)P i 1502 I 472.S !) 0 fA CLM 2 II",.!. Iii) 6:0OJ I I" .3 4733 !) 0.02 39 PUP I 4737 II 0.11 4? 37 Line corrosion. Lt. DeDosits. 1 4768 ° 0.07 2 2.89 Isolated nittimz. _t. ¡",n,,<ok 1 4800 ° 0.11 2.88 Dittim!. _t. PMV',.;", J ;31 O.U7 I CLIO UnE:_g2rrosiorl. Lt. Deposits. .. I I 1 362 0 0.12 I Line corrosion. Lt. DeDosits. I 394 0 0.11 , Une corrosion. Lt. Denosits. 1 )25 !I 0.11 45 UIlE:cqrrosiOll, I t.QE:pqsij:s, 158 156 !I 0.09 3S 'I ;0. I i"p-nuCt. I 159 ifF 0 0.11 43 " In Line Lt. Jenosits. 1 (,n Wi 0 0.11 44 "4 :6 I i"p It ¡",nn",k 161 50{9 0 0.07 29 I Ii RR iT"p corrosion. It. Deoosits. 5081 0 0.08 ¡ ) :)fIfI AWlw. It. Deoosits. I 511C) 0 0.10 40 I 2.90 Line corrosion. Lt. Deoosi15. 5141 0 (J.O 8 33 ) :)C)(¡ Isobtp¡J nítting t. 1-), ",,·w: t,· I i 0 40 ) 7 flCJ I I Deoosits. I I 5172 0.10 1(i( 5204 0 0.12 49 I 2.88 Line corrosion. Lt. Deoosits. I 1(, : ;:; n 0.12 46 3 2.90 -lin",' It IIpnn"ik Hi8 n 0.12 47 ) ... j.RC) ! in", . t "'''no' .., HiCJ n 0.14 54 t. ) fii, 'Ii"p I 170 n 0.12 49 4 >.ä'Y Ii" I 171 0 . non 0.11 '14 ) :)')() .¡;;;:; ;"ltp, . nilting It I , In n I 0.08 I ) ;¡q¡) ¡;:::; ;ltpI niltimz. I I Deoosits. l'7c 0 0.08 ¡)em I~~; atpI nittimz ¡ I ¡ n ) ¡i.')i1 Tim' ¡ t. DeDosìts. 17' 0 .RR i~~¡latp( nitti"q I I. I 1 '( 0 ~fI k(~latp( nitti,,;. Lt. Deoosits. I 177 ~ 0 1CJ 1,(,L¡jp( oìttilw. It Deoosits. 17(J 0 ) iO 1~(~lajp( nitti!l\I I t. 179 ')6]( 0 } II ¡,,,Ialp( nittimr. Lt I 180 .5642 0 0.10 4 19 1,,,lalp( niHilHI. Lt. I 181 5674 n 0.08 ) 11i knlMp( Dittill&.U. DE:Qosi~... I IR2 5705 0 0.09 j <(~ nirtin\!. L t. II I I I I ~=t='j7'{') 0 0.14 ) 2.8'L Lil1e corrosiOll,-..L112fJ]osit~.___ ~~-- I 184 5766 0 0.11 :2 2.91 Line corrosion. Lt .c2~po~its. 1 Wi 5797 Ii 0.09 ) :TI~o I inp It. I R(, I 5828 n 0.08 ) I 290 I ¡np t. i 1R7 586(1. n 0.07 2.92 LiE?_ÇQIIIQsioll. Lt Denosits. I 138 5891 n I 0.10 1·1 2.90 Line corrosion. It Denosits. 189 5923 n.n5 o.m :1:1 ) "" -i¡;W _t r I 190 5954 n 0.09 17 7 "t) Line _t. r1Pnn"ik Body I Metal Loss Body Page 4 I I I I I I Pipe: Body Wall: Upset Wall: NominaII.D.: Joint I I 191 192 .......19'\ 194 194.1 194.2 ¡eM -.¡ 19) 19(, 197 19R 199 200 201 202 203 204 205 I I I I I I I 210 211 212 213 ~ 14 15 220 221 2:0 221 224 22S 226 I I I I I ~z 2?R 229 229.1 229.2 2)9) 230 ~31 ~32 33 34 I 3.5 in 9.3 ppf 1.-80 0.254 in 0.254 in 2.992 in Jt. Depth (Ft.) S9ß4 6016 1,041, 60n ¡,¡ 0(, (,114 1,12,\ 6127 61';9 6191 6221 (,253 (,284 , (,315 (,346 6'\n 6407 6438 646, 149' ~ ' ~ ' 68% '2, 15 IS, II 70')0 ?OR1 7112 7144 717') n07 nli 7221 7226 7257 72ßB 7320 7351 : 1 52 PH 1.\ ) (.) Pen. o o o 00" I I I I I I I I 1 I o o o o 1 I) o o o o o o o o o o o o o o o o o o o o o o o I I} o o o o o 0.09 0-1 ... O. 11 o ( ,0.03.. 0.07 0.06 0.07 1107 0.08 0.08 I 1106 0.09 (10417 0.08n 0.06 24 (LO 5 21 0.05 20 0.09 37 0.0519 0.07 29 0.07 JO !Ft=c~~ 0.10 ... JB 0.04 0.06 0.07 I 0.0/ 0.04 0.08 0.04 0.04 0.04 Olì(, DOS o n.04 OOS 0.03 0.04.. 1 0.06 0.05 Pen IVlptll1 M.in. I.D. I , (Ins.) II', ) WI : 1 ') II 2 1 ) o 2 ) 21 ¡ 3 ¡ .' , } , , 2 .:. ) .) ) I ! i 2 . 1 I ) 19 o '1, 19 10 HI 23 HI jne ,t. jne ,t. ,.¡net. solated D¡ttim~. Lt. "UP CLM 3/Latch@12:30) "UP Lt. Ii" solated Dlttlng. Lt. Deposits. Isolated Plttll1g. Lt. Deposits. _. LlIle COIrOSlon. Lt. DeposIt:;. ..n ..~ _.~.. Isol,ìted plttmg. Lt. Deposits. ......._.....n Isolated Plttmg. line COlroslon Lt. Deposits. sob tpd n Jt nQ. I t. ¡pno< Its ;h,lilov p tt ng. solate( D lit ng. Lt.')pno"ìts solatp( I n ,tt mL solate(! pH ng. Lt. I)pno<;;t<; so!ate(! ntt nQ. I t. r 2.9( solated !J itt nQ. It. I)pno";t,, 2.91 ;hallow n tt nQ. 2. 91 Isolated nittimr. I t. I)pno<;it<; 2.91 Isolated nittinQ. It. I)pn""ik 2.86 Shallow nittínQ. I t. I)pn"cik 2.91 Shallow nittil1Q. It. I)pn""ik 2.91 Isolated nittìl1Q. ! t. I)pn""ik 2.88 Isolated nittinQ. i L 7.88 Sh ¡lIo\" DittinQ. 1.1. I)pn"",k 2.89 Isc late(! DittÍl¡Q. Lt. 2.90 Isclate(! DittimL 2.90 ! ¡sc ate(i nìttinQ. Lt. DeDoslts 2.91 Sh lllow nittinQ. 1.1. .89 Isolated nittinQ. Lt. )0 Shallow nittinQ. ..t. Isolated nittinQ. ollted DlttU]j,~. Lt. DeDoslts. Slow Dlttlng. S ìa low nittìmz. ..1. Slow Dittim!:. .t. Lme of nits. Lt. PI ¡P ,., A ;HI G.M 4 _atch ~IJ 6:30) PI JP Jltt¡ng. Lt. DeDoslts. Shallow Dlttmg,.l.LD..5'!2Q?lts. n... "_u..~n Shallow,l.ð::DQ~i1~ Isolated Dltting. Lt~ ,t. ~ '. I 2.89 2.92 N!A 2.90 2.85 2.90 2.90 .2..89__. .2..139 2.90 2.B9 ) n 2.90 ) 2.91'" 4 2.B8 o N!A ) 2.B9 I I 2ci'{ 2.8B 2.89 2.91 N SH Well: Field: Company: Country: Survey Date: 2G-06 Kuparuk ConocoPhillips Alaska, Inc USA July 12, 2006 Comlllents 2 ~~(~ ~ Page 5 Damage Profile (%wall) 'it I I ¡ II I I I I I I I I 1 o !II Body Metal Loss Body I I II I 'I' I II [ II LLLLLJ I I I I I I I I I I I I I I I I I I I JOINT TABULATION SH Pipe: 3.5 in 9.3 ppf L-80 Well: 2G-06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhíllips Alaska, Inc. NominaII.D.: 2.992 in Country: USA Survey Date: July 12, 2006 loint i Jt Depth iF'1 Pen. Pen \;Ìf,i;\I!~ Damage Profile No. ('I Body Comments ("10 wall) Ons.} (Ins,) -11 50 100 21'3 7382 0 0.06 ¡ ¡ 2.90 Isolated nining II 236 7414 Iì 0.04 1 ( 2.94 Shallm\iJ}ittil}g. 217 7445 Iì 0.05 1 I VIR It 238 7477 n fU16 2 ) 2}13 ¡sobler! nitting 239 7508 0 0.04 1 I 2.94 Shallow nining. 240 7539 0 00:; I 2.94 I 241 7571 0 007 ) ) .'r! Isobted nitting I t I 242 7602 0 0.09 2 2.89 Isohter! nitting I t T '4 /634 n i.06 } 2.94 Isohter! nittimr '4 . 0 L04 } ~q' Shallow niaing. i t 7664 I '696 0 '.04 I )2 S!1aUo\¡\ nining I '727 0.06 0.08 Isolate( nitting. '759 0 0:Ö6····· nitting. I t. ì90 0 0.08 Iso later niHimz. It I I11I 9 321 0 0.0< Isolate( nitting. I I. 0 353 n 0.0 1 Isolate( nittilw. I t 1 385 0 0.0, ° iso!ater nítting. I t 2 n 0,0, J1 ¡ late( nitting. L1. Deposits. 3 0 0.03 2.90 I Ilk)" v Dittiml. 1 0 0.04 } ) qn I PS Ilow nitting. I ) n 0 0 Iì N/A M atch @ 1 :om I '1 79.93 0 0.05 Iß 4 2.91 PS Uow I I[ 254 8000 0 0.05 20 ) -:; on ,red [¡íttiml. LI. )'141 8()2 9 0 0.03 ¡ 1 7 I II )')4 ) 0 0.09 37 ': Lt. I J Ilill 7')4'1 :) 0 {) Iì \I 00 7')44 0 0.03 I ) ( UI III )')4') 0 0.02 8 I ( P II End of Lml III! Body Metal Loss Body Page 6 .. .. .. .. .. .. .. .. Well: Field: Company: Country: 2G-06 Kuparuk ConocoPhillips Alaska, Inc. USA Cross for Tool speed = 43 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 94 % Tool deviation = 47 0 .. 2895.953 ft Finger 4 Penetration = 0.474 ins Hole .. .. .. .. .. .. .. DS rt C Secti ns Survey Date: Tool Type: Tool Size: No. of Fingers: July 12,2006 MFC UW 24 No. 211387 1.69 24 0.47 ins = 100% Penetration HIGH SIDE = UP Cross Sections page 1 .. .. .. .. .. .. .. .. - Well: field: Company: Country: .. .. 2G-06 Kuparuk ConocoPhillips Alaska, Ine. USA for Joint Tool speed'" 44 NominallD '" 2.992 Nominal OD '" 3.500 Remaining wall area'" 94 % Tool deviation'" 56 0 .. - - - - .. - .. s ns Cross S Survey Date: Tool Type: Tool Size: No. of Fingers: July 12, 2006 MfC UW 24 No. 211387 1.69 24 2913.37ft Finger 1 Penetration 0.258 ins Hole 0.26 ins 100% Penetration HIGH SIDE'" UP Cross Sections page 2 - - - .. .. .. .. .. .. .. .. Well: Field: Company: Country: 2 G-06 Kuparuk ConocoPhillips Alaska, Inc. USA Too1 speed 43 NominallD 2.992 Nominal 00 = 3.500 Remaining wall area 95 % Tool deviation = 57 0 .. .. .. .. .. .. .. .. S R ep rt S ns Survey Date: Tool Type: Tool Size: No. of Fingers: July 12, 2006 MFC UW 24 No. 211387 1.69 24 2952.533 ft Finger 23 Penetration = 0.232 ins Possible Hole 0.23 ins 91% Wall Penetration HIGH SIDE = UP Cross Sections page 3 .. .. .. I I (0-8114. OD:3.500. ID:2.992) I I I I I I I Gas Lift ,"dral/Dummy Valve 5 I IAOO!U>OOO I I I I I I P"rf (8188-8198) . ......... ... ........ .... ........... ...... m.. . .._.. . I ............... ------ P"rf ........ ........... (8216-8246) ....... .......... I .... ... .. .............. ......... ------- ----- .. .m I I 'G.OS API: 1500292112100 SSSV Type: I LOCKED OUT I A.. n.. n. ular FIUiL ...B.eI".r:.ence Lo : __ , Last Tan: '8212 ~i~/7/2006 ,Mnllr To SUR. CASING P WD. CASING Tubim ."-'-- I VDU'!\: 2:13 1 Top :01 1 0 Interlfa 8188 - 81 t8 TVD 6013 - 6021 KRU 2G-06 Anale ® TS: 38 deg @ 8093 I Angle @ TO: 36 deg @ 8485 ·..·1 Rev Reason: TAG FILL, GLV C/O _ LasLLJPdate: ~1/2.Q0~_.__ , I WellTvDe: PROD I Orìg 6/18/1984 í Completion: ~- La..s.. t W/O: 1/2/200~._.. .... Ref Log Date: TO: 8485 ftKB I Max ~~~~4000 ~ize2..~·L~ TVD 000 11 0 .625 6 4593 .000 8 6224 I 6: 8 31 0 21 0 I Bottom 1 I 8114 I TVD 5954 , Wt I Grade I I 9.30 T 'J-55' I Grade H-40 J-55 J-55 Thread BTC lone A-5 A-4 Status Ft ISPF I Date TVDB 10 I 4r9'724/1988 IPERF 90deg.Phasing;4" I I Sehlumberç¡er Casi 30 14119/24/1988 IPERF 90 deg. Phasing; 4" Sehlu V Mfr V Type V 00 latch Port :;ameo KBM!IJ ·2 :;amco KBM!IJ ·2 :;ameo KBM!IJ ·2 :;ameo MMIv I DMY GLV GLV OV DMY 8216 - 8246 I {;()':¡{;. (;(){;() I ~TVD Man Man Type ~.Mfr 2866 I 2599 Cameo KBMM-2 4749 3735 e137 4576 7737<;:'\04 .1 :Ie R R S 8060 5912 8075 5924 8102 5945 8114 5954 Data I Nom 1/2/2000 "V ~ TRO Date Run 1/2/2000 1-11 above ') ¡¡¡;;() rlrift 2.75" ::>I::U:::C IIVt PROFILE !lIne re-entrv Guide w/40 K. ;" x' 1S .1'\1: Broken, 0.000 I 0 Off I F 5 0.188 1290 ~ 5 ~ :~~gf1208.o 6.00010' "../.,....>/ 1.0 Thraad Welded BTC BTC VI" Cmot 6/9/2006 ..... §/9/2006 ......_ 6/9/2006 . "iTS72000T' . ID 2.875 3.,QQL 2.850 2.750 2.992 I Schlumbergel' Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well ../ 2N-305 Jo J-ì )5- J .2N-308 I qq -(ji~ .l2N-317 ~ q S .~ NJ v 2G-06 13 \.f - c.&,). ~/ 1 Y -04 Î 8> - fi ~ l. \/3J-10 '~'f... ¡çò J 2U-10 IJ)' - C y~ ~ '1 C-178 *0) - C '-if Job# 11047348 11047344 11047345 11022913 11047351 11058227 11047352 11022908 ;;t~f~t\\HEC "41 \;¿ r, -\0.. .." ~- Log Description SBHP SURVEY SBHP SURVEY SBHP SURVEY FLOWING BHP INJECTION PROFILE \; í <- MULTI-FINGER CALIPER LOG PRODUCTION PROFILE WIDEFT PRODUCTION PROFILE WIDEFT I /,,'1 / ('! f'..".~'. ! If ! :~,¿ I II i,. ,¡ /\j-I1~"", (~; I ' 1,~I SIGNED: ~¡:D v1.,! r. " c. 2 n r¡J:O; ~;.,~ ú - J W ù Date 07/25/05 07/24/05 07/24/05 07/20/05 07/27/05 07/18/05 07/28/05 07/14/05 NO. 3443 Com pany: 08/03/05 \Çf4~-o9'J- Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL DATE: Color CD - 1 1 1 1 1 1 1 1 --~/ ¡;f-' ~..~ )~~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATI©N COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Pull tubing _X 2. Name of Operator: 15. ARCO Alaska, Inc. I 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 547' FSL, 236' FWL, Sec. 32, T11 N, R9E, UN At top of productive interval: 1387' FNU 1339' FEL, Sec. 32, T11 N, R9E, UN At effective depth: At total depth: 1268' FNL, 1198' FEL, Sec. 32, T11 N, R9E, UN 12. Present well condition summary Stimulate__ Alter casing _ Type of Well: Development X. Exploratory ~ Stratagrapic __~ Service . Total Depth: measured 8485' Plugs (measured) true vertical 6252' Effective Deptt measured 8074' Junk (measured) true vertical 5922' Casing Length Size Cemented Conductor 110' 16" 202 sx CS II Surface 3134' 9.625" 1035 sx Permafrost E & 250 sx Permafrost C Production 8449' 7" 575 sx Class G & 250 Liner Plugging _ Repair well _X Perforate _ Other _ 6. Datum of elavation (DF or KB feet): 140' Rig RKE 7. Unit or Property: Kuparuk River Field 8. Well number: 2G-06 9. Permit number/approval number: "'--84-82/399-239 10. APl number: "' 50-029-21121 11. Field/Pool: Kuparuk River Field/Kuparuk Oil Pool Measured depth True vertical depth 110' 110' 3134' 2774' 8449' 6224' Perforation Depth measured 8188'-8198', 8216'-8246' true vertical 6013'-6021, 6036'-6060' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 8118' Packers and SSSV (type and measured depth) Baker FHL packer @ 8075', Camco DS nipple, No SSSV RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured~ N/A Intervals treated (measured) ORIGINAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 174 85 1006 1453 744 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil _~ Gas _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /'~-~d ~ Title: Drilling Engineering Supervisor Chip Alvord, Suspended Service _ Questions? Call Mark Chambers 265-1319 Date Z./2~ ]Z o o o SUBMIT IN DUPLICAT,~ Form 10-404 Rev 06/15/88 Prepared by Sharon AIIsup-Drake Date: 02/16/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:2G-06 RIG:NABORS 19E STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:12/22/99 START COMP:12/21/99 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21121-00 12/21/99 (Cl) TD: 0' PB: 0' 12/22/99 (C2) TD: 8368' PB: 0' 12/23/99 (C3) TD: 8368' PB: 0' 12/24/99 (C4) TD: 8368' PB: 0' 12/25/99 (C5) TD: 8368' PB: 0' 12/26/99 (C6) TD: 8368' PB: 0' RIG ACCEPTED MOVING ONTO MW:15.5 DOILW SUPV:R.W. SPRINGER PJSM. Accept rig @ 1800 hrs. 12/21/99. PJSM and safety walkthrough. Continue to rig up. MOVING KILL/ RETURN TANK SUPV:R.W. SPRINGER Continue to rig up. MW:15.5 DOILW MONITORING WELL F/FLOW, P MW:14.6 LSND SUPV:R.W. SPRINGER Prepare to kill well. Move tank due to change of wind direction. PJSM & safety walkthrough. Rig up to kill well. Attempt to blow down, line frozen. Break lines and thaw out. PJSM. Pump hole w/seawater down tubing followed by viscous spacer and mud to kill well. LIFTING STACK TO PLUG LEA MW:14.6 LSND SUPV:R.W. SPRINGER Continue to kill well by displacing seawater w/mud, shut well in. Returns gas cut, circ and weight up to 14.6 ppg. R/U and set 2-way valve. N/D tree & adaptor. PJSM. Install HCR kill valve. Install riser flanger. LAYING DOWN 3-1/2" COMPLE MW:15.0 LSND SUPV:R.W. SPRINGER Rig up to test BOPE. Test all choke manifold valves (250/5000). Attempt to test BOP's, 2-way check valve failed. Blow down all choke & kill lines. Re-test still leaking off. Test BOPE to 250/3500 psi. R/U to pull hanger and tubing. Circ while pulling loose work pipe all indications that all off assembly loose. Well flowing, circ & weight up to 15.0 ppg, condition mud. LOADING PIPE SHED MW: 15.0 LSND SUPV: R.W. SPRINGER Pull 3.5" tubing. PJSM. Continue to pull tubing. Run 6.06" guage ring, junk basket to 8118' tag fill. Date: 02/16/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 12/27/99 (C7) TD: 8368' PB: 0' 12/28/99 (C8) TD: 8368' PB: 0' 12/29/99 (C9) TD: 8368' PB: 0' 12/30/99 (C10) TD: 8368' PB: 0' 12/31/99 (Cll) TD: 8368' PB: 0' 01/01/00 (C12) TD: 8368' PB: 0' 01/02/00 (C13) TD: 8368' PB: 0' COMMUNICATION BETWEEN TBG MW:15.0 LSND SUPV:R.W. SPRINGER Guage ring/junk basket tagged @ 8118' WLM. POH. R/U to run completion. PJSM. Run completion. Tag fill @ 8196' Set packer w/tail assy @ 8114' ATTEMPTING TO THAW OUT FR MW:15.0 LSND SUPV:R.W. SPRINGER Test annulus to 2000 psi, OK. Circ to even out unbalanced mud. Stingback into PBR w/ pump on. Circ to even out unbalanced mud. RIH w/slickline to latch shear valve, no luck, POH. add weight bar. RIH & attempt to latch spear valve. POH w/shear valve. Set BPV. PJSM. Blow down kill line, choke line frozen, trip tank line, mud manifold blown down. CLEANING MUD PITS MW:15.3 DOILW SUPV:R.W. SPRINGER Remove XO spool wellhead to BOP's, dress grease hanger stump install XO spool f/wellhead to tree, test to 5000#, NU tree, BPV frozen in. Wrap wellhead, heat w/Tioga heater to thaw out. Pump out tree try to pull BPV, N/D tree, clean out ice, pull BPV, install plug. Test tree to 5000#. PUll plug. Break circ slowly, broke free. Pump hivis sweep and dirt magnet, switch to seawater. PJS> Pump diesel down tubing, U-tube back to annulus. Set BPV. Secure tree. WAITING ON WEATHER TO MOV MW:15.3 DOILW SUPV:R.W. SPRINGER Secure tree, install flanges. Clean mud pits. Phase 2 weather conditions. Release rig @ 0800 hrs. R/D Rig floor. R/U to scope derrick in. RIG RELEASED, WAITING ON MW:15.3 DOILW SUPV:R.W. SPRINGER Prepare & retract cattle chute. Fold derrick board and windwalls. Remove all windwalls above drawworks. Waiting on weather. WAITING ON WEATHER TO MOV MW: 0.0 SUPV:R.W. SPRINGER Rigdown and lowering mast curtailed by highwind conditions. Continue to rig down. Waiting for high wind conditions to calm before laying derrick over. MOVING TO 3F-20 MW: 0.0 SUPV:R.W. SPRINGER Wait on wind to lower mast. General rig maintenance. Safety meeting. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _X Variance _ Perforate _ Other ~X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface V/ V/ v/ 547' FSL, 236' FWL, Sec. 32, T11 N, R9E, UM At top of productive interval 1387' FNL, 1339' FEL, Sec. 32, T11N, R9E, UM At effective depth At total depth 1268' FNL, 1198' FEL, Sec. 32, T11 N, R9E, UM 5. Type'of Well: Development __X Exploratory __ Stratigraphic __ Service _ 6. Datum elevation (DF or KB feet) RKB 140' feet 7. Unit or Property name Kuparuk River Unit 8. Well numbs, 2G-06 9. Permit number/approval number 84-82 ¢ 10. APl number 50-029-21121 11. Field / Pool Kuparuk River Field/Kuparuk Oil Po( 12. Present well condition summary Total depth: measured true vertical Effective depth: measu red true vertical Casing Length Conductor 110' S u rface 3134' Production 8449' Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 8485 feet,/,. Plugs (measured) 6252 feet' 8368 feet Junk (measured) 6158 feet Size Cemented Measured Depth True vertical Depth 16" 202 sx CS H 110' 110' 9.625" lO35 sx Permafrost E & 3134' 2774' 250 sx Permafrost C 7" 575 sx Class G & 250 sx Permaffc 8449' 6224' 8188'-8198', 8216'-8246' 6013'-6021,6036'-6060' ORIGINAL RECEIVED Camco HRP-ISP pkr @ 8088', Otis 'FMX-TR' SSSV @ 1903' ~~ll~l~O011~,~'Ollllll~ Anchorage 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation Nov. 30. 1999 115. Status of well classification as: 16. If proposal was verbally approved I Oil __X Gas__ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedChipA,vord ~ ~. ~'"~.~ Title: Drilling Engineering Supervisor FOR COMMISSION USE ONLY Suspended g Questions? Carl Mark Chambers 265-1319 Date I,/,~(.~ Prepared by Sharon AIIsup-Drake Cond~,jof approval: Notify Commission so representative may witness (.. Plug integrity_ BOP Test _~ Location clearance__ ~t'~O.4 ~ ,, Mechanical Integrity Test __ Subsequent form required 10; t.~(~)t,~, ~er of the Commission ORIGINAL SIGNED' BY commissioner ........ Robert N: Cnnstenson { Appr°valn°S% Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE PRE-RIG WORK: KRU 2G-06 GENERAL WORKOVER PROCEDURE 1. RU Wire Line Unit. RIH and dummy off all Gas Lift Mandrels. 2. RU CTU. RIH and lay sand plug from top of fill @ 8237' to tubing tail. 3. Set BPV in tubing. Install VR plug in annulus valve. Prepare Location for Pool 9. GENERAL WORKOVER PROCEDURE: 1. MIRU Pool Rig 9. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits with seawater. Displace tubing and annulus with seawater by circulating through hole in tubing @ +/- 8070'. SI well and monitor pressure to determine kill weight. 3. Load pits with kill weight mud. Displace tubing and annulus with kill weight mud by circulating through hole in tubing @ +/- 8070'. SI well and monitor pressure to ensure well is dead. Set BPV. 4. ND / NU and test BOPE. 5. Screw in landing joint. POOH laying down 3-1/2" tubing and spooling up SSSV control line. Lay down SSSV and continue POOH laying down 3-1/2" tubing and jewelry. Note: Tubing is corkscrewed from the packer to approximately 6811 '. If unable to pull off OEJ it will be necessary to cut the tubing as deep as possible and fish the remaining tubing from the well bore using drill pipe. 6. Load, strap and drift 3-1/2" drill pipe. 7. RIH with cleanout assembly picking up 3-1/2" drill pipe off the rack. 8. Cleanout to top of packer and POOH laying down 3-1/2" drill pipe. 9. Load, strap and drift 3-1/2" tubing. 10. RIH with 3-1/2" completion assembly as per schematic. 11. Circulate over slick stick, spaceout with tubing pups and land tubing hanger. 12. Pressure test tubing and annulus. RECEIVED 19 1999 13. ND / NU and test tree. 14. Displace well to seawater and freeze protect with diesel to +\- 2000' TVD. Lower Limit: 4.5 days Expected Case: 5.5 days Upper Limit: 7.0 days No problems pulling or re-running completion Difficulties encountered pulling completion, or re-running completion MAC 11/18/99 ARCO Alaska, Inc. ,~, GKA 2G-06 APl: 500292112100 Well Type: PROD Angle ~ TS: 38 deg ~ 8093 S S S V / ~=.=.~== SSSV Type: Otis 'FMX-TR' Orig Completion: 6/18/84 Angle @ TD: 36 deg @ 8485 (1903-1904. locked out 4/9/99 ~ Annular Fluid: Last W/O: Rev Reason: Tag fill by ImO OD:3.500) ; Reference Log: Ref Log Date: Last Update: 8/27/99 Last Tag: 8237 TD: 8485 ftKB Last Tag Date: 8/26/99 Max Hole Angle: 55 deg ~ 4000 ]~1~1 .... 16.ooo~'~e .... it T0P 'JDOff°m0 I 't ,vO, o I ,.,oWt I Grade IH.40 Thread ~ih~St~in~SURFACE : : .... ' '~i~e I Top IB°~°~ TVD I Wt ~ GradeI Thread 9.625 I 0 I ~ 4593 36.00 J-55 C~i n ~ St~ih~ Re D U CTION ]~~1 ~ze7.000 '°" t "°"°m I 'v° Iw'o , 8449 6224 ~.oo I Grade r~-~ Thread , . ~ 8066, (12115197)) Size I ~o, I Bo,om I ~vo I wt I Orade~ Thread ~:~ 3.500 I 0 I 8118 I 5958 I 9.30 J-55 EUE 8RD 1~:~~:~ = Inte,a, TVD Zone Status Feet SPF Date Type Comment ~=j 8188- 8198 6013- 6021 A-5 10 4 9/24/88 IPERF 90 de~. Phasing; 4" Schlumberger Casi J ~~ 8216 - 8246 6036 - 6060 A-4 30 4 9/24/88 IPERF 90 de~. Phasing; 4" Schlumberger Casi GaS E iE Ma ~d ~el~l~es Stn MD TVD Man Man V Mfr V Type V OD Latch Po~ THO Date VIv Mfr Type Run ;omment I 1942 1881 Camco KBUG DMY 1.0 BK 0.000 0 12/1/97 ]~~ I 2 3846 3204 Camco KBUG DMY 1.0 BK 0.000 0 12,1/97 3 5717 4318 Camco KBUG DMY 1.0 BK 0.000 0 12/1/97 4 7301 5349 Camco KBUG DMY 1.0 BK 0.000 0 12/1/97 5 8032 5890 Camco KBUG DMY 1.0 BK 0.000 0 12/1/97 ~ .:.~:~ Depth TVD Type Description ID ~':' 1903 1846 SSSV Otis 'FMX-TR'. LOCKED OUT 4/9/99 2.813 ]~~t 8070 5920 PB, Camco OE,-10 2.973 8088 5934 PKR Camco HRP-1SP 2.867 8106 5948 NIP Camco 'D' Nipple NO GO 2.750 ::'~ 8117 5957 SOS Camco 2.992 :. ~:':~ 8118 5958 TTL 2.992 ::::::;~ G~:r~l N~:t~s : ; PBR ................... ~;;~;~;?~;~ ~;~; Date INote I (8070-8071, ::?.::~'.~ ~:~ ~;~::~;~[:.~::::~(::~ : ~ 419199 IObstruction or corkscrewed tubing ~ 8041' WLM o~:3.~00) 0D:6.151) RECEIVED 0D:3.500) (0-8118, OD:3.500, IB:2.992) Peri (8188-8198) Peri (8216-8246) 2G-06 Proposed Completion 9-5/8" 36# J-55 BTC @ 3134' 7" 26# J-55 BTC @ 8449' TD @ 8485' M. 3-1/2" 5M McEvoy Gen III tubing hanger with 3-1/2" L-80 EUE 8rd pin down. L. 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to the tubing hanger. K. 3-1/2" Camco 'DS' Nipple with 2.875" ID No-Go profile set @ +/- 500' MD. J. 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to the 'DS' Nipple with 3-1/2" x 1" Camco 'KBMM' GLM's w/DV's spaced out as follows. GLM # MD TVD I TBD TBD 2 TBD TBD 3 TBD TBD 4 TBD TBD Note: Each GLM should have 6' L-80 handling pups installed on top and bottom. RECEIVED D .C 19 1999 I. 3-1/2" x 1" Camco 'KBMM' GLM w/DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. H. 1 Joint 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing. F. Camco 'OEJ' 10' expansion joint (2.973" ID, 5.975" OD). E. 7"x 3-1/2" Camco 'HRP-1-SP' Hydraulic Set Retrievable Packer @ 8088'. Packer pinned for 60K release (2.867" ID, 5.937" OD). D. 10' Pup Joint 3-1/2" J-55 9.3# EUE 8rd IPC Tubing. C. 3-1/2" Camco 'D' Nipple w/2.75" No-Go Profile (2.75" ID, 4.50" OD). B. 10' Pup Joint 3-1/2" J-55 9.3# EUE 8rd IPC Tubing. A. Camco 3-1/2" PE-500 shear out @ 8117' (2.937" ID, 4.5" OD). Tubing tail @ 8118'. A5-Sand Perfs 8188' - 8198' MD / 6013' - 6021' TVD A4-Sand Perfs 8216' - 8246' MD / 6036' - 6060' TVD Cork screwed tubing from packer to 6811' MD. Sand plug laid by wells group from top of fill to tubing tail in preparation for workover. PBTD @ 8237' - Fill tagged on 8/26/99 PBTD @ 8368' - Actual 7" casing PBTD to FC. 11/18/99 MAC Re: 'Kuparuk 2G-06 Flow Request Subject: Re: Kuparuk 2G-06 Flow Request Date: Fri, 19 Nov 1999 10:10:39 -1000 From: "PRB Problem Wells" <p 1041 ~mail.aai.arco.com> To: Blair Wondzell <blair_wondzell~admin. state.ak.us> Thanks for the response Blair. I believe the intent is to flow until approximately 1 week prior to the RWO so they have time to prep the well with slickline, etc. I will forward your email to the appropriate Kuparukites. Thanks! Jerry Dethlefs Blair Wondzell <blair wondzell@admin.state.ak.us> on 11/19/99 08:30:36 AM -- To: PRB Problem Wells/AAI/ARCO, Chuck Scheve <chuck scheve@admin.state.ak.us> CC: Subject: Re: Kuparuk 2G-06 Flow Request Jerry, Go ahead and flow the well - be sure and monitor the pressures and rates for possible additional problems. Chuck agrees and is clued in, so don't hesitate to call him if you have questions or want to pass on information. Sincerely, Blair PRB Problem Wells wrote: > Blair: Well 2G-06, as previously reported, has T x IA communication via a leak > near the packer resulting from a coiled tubing milling operation and is capable > of unassisted flow of hydrocarbons to the surface. Originally intended for a RWO > in 1998, it did not make the schedule and the RWO was not done. The well is now > scheduled for a RWO to start within the first two weeks of December 1999 to > replace the tubing. Engineering and Drilling would like to flow the well from > now until the RWO to draw down the reservoir pressure as much as possible and > obtain flow data for post-RWO activities. As usual, wellhead pressures will be > monitored daily for any indication of additional communication problems. You > should be receiving a Sundry Notice for the Drilling operation shortly. Please > let me know of your decision on the temporary flow request. > Jerry Dethlefs > ARCO Problem Wells 1 ofl 11/19/99 11:53 AM [Fwd: Kuparuk 2G-06 Flow Request] Subject: Re: [Fwd: Kuparuk 2G-06 Flow Request] Date: Fri, 19 Nov 1999 08:42:52 -0900 From: Blair Wondzell <blair_wondzell@admin. state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Chuck Scheve <chuck_scheve@admin. state.ak.us> Good Morning Chuck, Thanks for responding. Since we seem to have the some ideas on producing the well, don't see a need to discuss it further. However, John C. on 11/1/99 tested SVS valves on DS 16 and noted that there were no well houses on this pad and that the pilots were sluggish. He also commented "There is no doubt that colder temperatures will adveselly affect Safety Valve Systems." Whats the story; how many wells do not have well houses? How effective are blankets covering the pilots? Regards, Blair Chuck Scheve wrote: Hi Blair Sorry I didn't call today, went to KRU early and got back late. I have no problem with them producing this well as long as the workover starts in Dec. and they monitor it. I hope a month of production don't draw down the reservoir pressure but it might provide usefull info for post workover production. I intend to head out to Endicott early in the Ai~ if you would like to talk further give me a page and I will find a phone. Chuck. Blair Wondzell wrote: > Chuck, > Please review and we will discuss. I'm in favor of the proposal. > Regards, Blair > > Subject: Kuparuk 2G-06 Flow Request > Date: Thu, 18 Nov 1999 12:16:23 -1000 > From: "PRB Problem Wells" <PlO418mail.aai.arco.com> > To: Blair Wondzell~admin.state.ak. us -- > CC: "Well Operations Supervisors AAI" <P2OlOSmail.aai.arco.com>, > "Andrus&Balog" <Nl135~mail. aai. arco. com>, > "Ronald B Marquez" <RMARQUE~mail. aai. arco. com>, "Todd J Mushovic" <TMUSHOVSmail. aai. arco. com>, "Mark A Chambers" <MCHAMBE28mail. aai. arco. com>, "Beck&Zuspan" <N1052~mail. aai. arco. com>, "PRB Problem Wells" <PlO418mail.aai.arco.com> > > Blair: Well 2G-06, as previously reported, has T x IA communication via a leak > > near the packer resulting from a coiled tubing milling operation and is capable > > of unassisted flow of hydrocarbons to the surface. Originally intended for a RWO > > in 1998, it did not make the schedule and the RWO was not done. The well is now > > scheduled for a RWO to start within the first two weeks of December 1999 to > > replace the tubing. Engineering and Drilling would like to flow the well from > > now until the RWO to draw down the reservoir pressure as much as possible and 1 of 2 11/19/99 8:43 AM ~e:' [Fwd: Kuparuk 2G-06 Flow Request] > > obtain flow data for post-RWO activities. As usual, wellhead pressures will be > > monitored daily for any indication of additional communication problems. You > > should be receiving a Sundry Notice for the Drilling operation shortly. Please > > let me know of your decision on the temporary flow request. > > Jerry Dethlefs > > ARCO Problem Wells 2 of 2 11/19/99 8:43 AM SENT BY:ARCO AI~SIC~ D-Il-B§ ; 9'40PM ; KP$/WFIIS/CNST/PROJ~- ARCO Alask,~, Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 Eric L, Zuspan Wells Engineering Tech Kuparuk Wells Group NSK-69 Phone: 659-7285 Fax: 659-7314 807 27§ 73ei2;g 1/ 1 ~-o~ May 11, 1998 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Pomupine Drive Anchorage, Alaska 99501 Blair, This letter is a follow up to today's telephone conversation concerning the tubing x 7' communication on production well 2G-06. Tubing x 7" integrity was lost during CTU milling operations on 12/23/97. The leak was estimated at a depth of 8035', 33' above the top packer. Several attempts have been made to identify the leak, but failed to pass an obstruction. The well is scheduled to be side tracked in November. ARCO will continue to produce the well in hopes of. reducing the reservoir pressure before side tracking this winter. If you would like to discuss this matter further please don't hesitate to call. Sincerely, Edc L, Zuspan REEI IVED 12 1998 ,~laska Oil & Gas .(ions, ~allamis,' Anchorage 1. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address 5. Type of Well: Development Exploratory Stratigraphic P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 547' FSL, 236' FWL, Sec. 32, T11N, R9E, UM At top of productive interval 1387' FNL, 1339' FEL, Sec. 32, T11N, R9E, UM At effective depth 1290' FNL, 1224' FEL, Sec. 32, T11N, R9E, UM At total depth 1268' FNL, 1198' FEL, Sec. 32, T11N, R9E, UM 12. Present well condition summary Total Depth: measured 8 4 8 5' feet true vertical 6252' feet X 6. Datum elevation (DF or KB) RKB 140' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2G-06 Producer I9'84-82Permit nT~.~r/app~o~,~number 10. APl number $o-029-211 21 I-Il. Field/Pool Kuparuk Ri¥or Oil ~ool Plugs (measured) Effective depth: measured 8 3 6 8' feet true vertical 6158' feet Junk (measured) Casing Length Size True vertical depth Structural Conductor I 1 0 1 6" Cemented Measured depth 202 Sx C.S. II 1 1 0' 110' Surface 31 3 4' 9 - 5 / 8" Intermediate Production 8449' 7" 1035 SX Permafrost E 3134' 250 Sx Permafrost C 575 Sx Class "G" 8 4 4 9' 250 Sx Permafrost C Liner Perforation depth: measured 8188'-8189' , 8216'-8246' MD true vertical 6013'-6021', 6036'-6060' TVD Tubing (size, grade, and measured depth) 3 1/2", J-55 9.3 Ib/ft, EUE, 8118' MD Packers and SSSV (type and measured depth) 2774' 6224' 13. Stimulation or cement squeeze summary Intervals treated (measured) 8188'-8198', 8216'-8246' MD Treatment description including volumes used and final pressure 1227 bbls Gelled Diesel, 91200 #16/20 Carbo-Lite Proppant, WHTP = 4220 PSI . 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 5 / 6 Subsequent to operation 5/1 5 1020 980 0 700 140 2409 2927 0 500 252 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-'40-4 I~ev 06/15/88 ~ SUBMIT IN DUPLI(~ATE ARCO Alaska, Inc, Sul~idlar/of Atlantic Richfield Company WELL D~,=// ~EMARK$ IPBDT g'3~ 8 WELL SERVICE REPORT :FIELD- DISTRICT- STATE OPERATION ~T REPORT TIME ~e ~.,~/eT~ ]DATE /07' r-"] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK W"ther' I Temp' [ Chill F'~ [ Vi'lblllty IWlnd Vel'Report 'F °~'F mil. REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL CAMCO SCHLUMBERGER DRESSER-ATLAS DowIELL / z,/~,~ .~ o~. ~ HALLIBURTON ARCTIC COIL TUBING FRACMASTER S. J, HUGHES Roustabouts Diesel /~O ~Z~ ~ 7~O~ 'Methanol Supe~ision "Pre-Job Safety Meeting ...... AFE ,,, ..... TOTAL F~EL~ ~S~a~T~ / ~/~ 3 4 ~ ARCO Alaska, Inc. Date: February 9, 1989 Transmittal #: 7422 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 B - 1 3 Kuparuk Fluid Level Report 2 - 0 6 - 8 9 Casing 2 W - 01 Kuparuk Fluid Level Report 2 - 0 2 - 8 9 Casing 2 X- 1 4 Kuparuk Fluid Level Report 2 - 0 2 - 8 9 Casing 3 F- 1 5 Kuparuk Fluid Level Report 2 - 0 2 - 8 9 Tubing 3A-01 Kuparuk Fluid Level Report 2 - 0 2 - 8 9 Tubing 2G-06 Kuparuk Fluid Level Report I - 3 1-- 8 9 Tubing 30-14 Kuparuk Well Pressure Report I 0-25-89 Amerada Receipt Acknowledged: Alask2 Oil & ..... Anchorage ........................... Date: ............ DISTRIBUTION: D&M state of Alaska Chevron Mobil Unocal SAPC ARCO Alaska, Inc. Date: September 30, 1988 Transmittal #: 7306 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. 2G-06 Bottom-Hole Pressure Survey 9 - 1 2- 8 8 PBU Receipt Acknowledged: DISTRIBUTION: D&M SAPC(vendor package) State of Alaska Unocal(vendor package) Mobil(vendor package) Chevron(vendor package) STATE OF ALASKA ~ ALASK,,~ OIL AND GAS CONSERVATION COMM,,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown ,. ] Re-enter suspended well '~-; Alter casing Il TIme extension Change approved program Plugging "'~_ Stimulate ,~ Pull tubing Amend order .r Perforate [ ' Other 2 Name of Operator ARCO Ala.~ka.- Inc. 3 Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 547' FSL, 236' FWL, Sec. 32, TllN, RgE, UM 5. Datum elevation (DF or KB) 140' RKB 6. Unit or Property name Kuparuk River Unit 7. Well number 2G-06 Producer At top of productive ~nterval 1387' FNL, 1339' FEL, Sec. 32, T11N At effective depth 1290' FNL, 1224' FEL, Sec. 32, T11N At total depth 1268' FNL, 1198' FEL, Sec. 32, T11N 11. Present well condition summary 8485 Total depth: measured true vertical 6252 R9E, UM R9E,' UM R9E, UM feet feet 8. Permit number 84-82 9. APl number 50- 029-21121 10..POOlKuparuk River Oil Pool Plugs (measured) Effective depth: measured 8368 true vertical 6158 I feet Junk (measured) ' feet Casing Length Structural Conductor 110 ' Surface. 3134' Intermediate Production 8449' Liner Perforation depth: measured Size Cemented Measured depth 16" 202 Sx C.S. II 110' 9-5/8" 1035 Sx Permafrost E 3134' 250 Sx Permafrost C 7" 575 Sx Class "G" 8449' 250 Sx Permafrost C 8188' -8198' 8216' -8246' MD true vertical 6013'-6021' 6036'-6060' TVD Tubing (size, grade and measured depth) 3 1/2", J-55 9.3 lb/ft, EUE, 8118' MD Packers and SSSV (type and measured depth) Packer' £amcn HRP-I.~P 0 RORR' MrS..q.~.qV: CJti.~ FMX 0 1903' MD 12.Attachments Description summary of proposal ,~ Detailed operations program [; BOP sketch Re-fracture stimulate the A Sand w/gelled diesel and 16/20 Carbo-Lite proppant. 13. Estimated date. for commencing operation 05/07/88 True Vertical depth 110' 2774' 14. If proposal was verbally approved Name of approver ~tt~t~e~t W'oz-]~ ~egortea oa ~or~ NO.- ...... . ]3ated--/.--~-..l~ate approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,//~~ //~ J.,.3,v,-~.~ Title ~)"1,- ~-~~,",-~~'~-, ~'~Date Commission Use Only Conditions of approval Approved by Notify commission so representative may witness Approval No. ~ Plug integrity [] BOP Test ~ Location clearance ORIGINAL SIGNE0 BY ~,pproved Copy LONNIE C. SMITH . Retu_r[~d ~,~ ~'~r~jfder of Date ~_~~ ~~~ ~ Commissioner - The ~u,,,,i~sion feet Form 10-403 Rev 12-1-85 Submit in triplicate Kuparuk Well 2G-6 Well 2G-6 is currently an 'A' Sand-only producer. The 'A' Sand will be re-fractured to improve flow efficiency. A copy of the proposed procedure is attached. The fracture stimulation will utilize Carbo-Lite proppant and will use gelled diesel as the carrying fluid. A 10,000 psi 'tree saver' will be used during the fracture stimulation. Wellhead pressure/fluid level analysis indicates an average reservoir pressure of 2600 psig in the 'A' Sand. There is no gross C Sand interval present in this well. REEEIVED JUN 2 011 & Gas Cons. Commission Anchorage Messrs. Lyden and Wade April 20, 1988 Page2 Kuparuk Well 2G-6 'A' Sand Re-Fracture Procedure Charge Code: 230DS28GL 1. Obtain an 'A' Sand 24 hour well test. . MIRU Slickline unit, Tag bottom. Pull GLV's and Run DV's. Set blanking plug in Camco 'D' nipple at 8106' MD-RKB, Pressure test the tubing. Pull blanking plug, 3. Pump Diesel/10% Musol per the attached schedule. Shut down overnight to soak. Note stabilized WHP after pump-in. 4. RU fracture equipment. Install "Tree Saver", Pressure up 7" annulus to 3500 psi. . . . . . Check diesel for contamination prior to gelling for frac. Obtain a sample of the proppant and of the gelled diesel with breaker. Check the proppant for fines. Record proppant weight prior to pumping. After frac, verify and record weight of remaining proppant. Pump fracture treatment per the attached schedule. Record the 5, 10, and 15 minute pressures following the ISIP. Expected wellhead treating pressure: WHTPE = 5200 psig Fracture Gradient -- 0.85 psi/ft (6037' TVD) Tubing Friction = 270 psi/1000 ft (8118' MD) * If treating pressure during the job exceeds 6000 psi, shut down job and confer with engineering. Rig down frac equipment. Begin flowing well to tanks as soon as practical after minimum 6 hr. SI at a rate not to exceed 5 BPH (120 BPD). Record tank straps (rates), choke settings, and WHP's during flowback period. If proppant is produced at surface, shut in well and begin flowback again after 4 hours. After 24 hours, switch well to test separator. Follow a gradual flowback schedule by dropping WHP by 100 psi/day. Take BS&W samples after every choke change and every 8 hours. Inspect samples for Carbo-Lite. If Carbo-Ute is found, increase WHP by 100 psi and contact Operations Engineering (Currier/O'Dell). Well can be turned into CPF when BS&W is less than 2%. Continue the flowback schedule until a 150 psi WHP is acheived. Obtain a 12 hour 'A' Sand well test. KUPARUK WELL 2G-6 'A' SAND FRACTURE PUMP SCHEDULE 4120188 S~AGE FLUID CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT DIRTY VOLUME HIT PERFS DESCRIPTION BBLS BPM PPG DESCRIPTION LBS STG/CUM BBLS ,, 1 DIESEL/10% MUSOL 50.0 5 0 - - 0 50/ 50 73 2 DIESEL FLUSH 71.0 5 0 - - 0 71 / 1 21 123 ............................................. SHUT DOWN OVERNIGHT ................................................. 3 GD PRE-PAD 100.0 25 0 - - 0 100/ 100 73 .............................................. SHUT DOWN FOR ISIP .................................................. 4 GDPAD 650.0 25 0 0 650/ 750 1 73 5 GDw/2PPG 87,3 25 2 16/20 M CARBO-LITE 7334 95/ 845 823 6 GDw/4PPG 80.8 25 4 16/20 M CARBO-LITE 13568 95/ 940 918 7 GDw/6PPG 75.1 25 6 16/20 M CARBO-LITE 18933 95/ 1035 1013 8 GDw/8PPG 70.2 25 8 16/20 M CARBO-LITE 23599 95/ 1130 1108 9 GDw/10 PPG 69.4 25 10 16/20 M CARBO-LITE 29152 100/ 1230 1203 10 GDFLUSH 71.0+SV 25 0 - - 0 71.0/ 1301.0 1303 TOTN_DIESEL= 216.0 BBLS+SV 16/20 M CARBO-LITE = 92586 LBS TOTAL GELLED DIESEL = 1103.8 BBLS TOTAL MUSOL = 5.0 BBLS Stage I is Diesel with 10% Musol Stages 3&4 are Gelled Diesel with 40 lbs/1000 gal silica flour and enough breaker for a 8 hour break. Stages 5 through 9 are Gelled Diesel with 6J)~rer'aker and without silica flour. Stage 10 should include' a volume adjustment for surface equipment between the wellhead and densitometer and Iow temperature breaker(6 hr. break). This job is intentionally underflushed by 2 bbls. The blender tub should be bypassed at flush. All fluids should be maintained at 70 to 90 F on the surface. ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 11, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton: Enclosed are Well Completion Reports and Well History Addendums for the following wells' 2G-5 2G-6 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU5/L11 Enclosures pcCF. IVED MA~ 1 ]) 19B5 Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~.~-~ STATE OF ALASKA ALASKa, iL AND GAS CONSERVATION Cp- .;{MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL dX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ,,, 2. Name of Operator'" 71 Permit Numb'er ARCO Alaska, Inc. 84-82 "3. Address 8. APl Number ' P. 0. Box 100360, Anchorage, AK 99510 50- 029-21121 4. Location of well at surface 9. Unit or Lease Name 547' FSL, 236' FWL, Sec.32, T11N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1387' FNL, 1339' FEL, Sec.32., TllN, RgE, UM 2G-6 At Total Depth 11. Field and Po°l 1268' FNL, 1198' FEL, Sec.32, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri var 0i 1 Pool 140' RKB ADL 25656 ALK 2582 '12.' Date Spudae~ 13. Date T.'D. Reached 14, Date Comp., Susp. or Aband. I 15. Water Depth, if offshOre 116. N°. of Completions 06/11/84 06/16/84 09/24/84I N/A feet MSLII 1 "17.'TotalDepth(MD+TvD) 1B. PlugBa~:~Depth(MD+TVD) 19. DirectionalSurvey [ 20. Depth where ssSV set 121. Thickness of Permafrost 8485'MD,6252'TVD 8368'MD,6158'TVD YES [] NO I-1 1903 feet MD 1500' (Approx) 22. Type Electric or other Logs Run D I L/SFL/GR/SP/FDC/CNL/Cal, Gy rD (GCT). Temp/CCL 23. CASING, LINER AND CEMENTING RECORD ...... SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED .[ .'"16'~ .62.5# H-40 Surf 110' 24" 202 sx Cold Set II , , 9-5/8" 36.,0# J-55 Surf 3134' 12-1/4" 1035 sx Permafrost E & 250 sx Permafrost C 7" 26.0# J-55 Surf 8449' 8-1/2" 575 sx Class G & 250 s~ Permafrost C , , 24. Perforations open'to ProduCtion (MD+TVD of T°p and Bottom and 25. TUBING RECORD ,,, interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) .._ 8246' - 8226' 3-1/2" 8118' 8087' 8225' - 8216' 8188' - 8198' 26. ACID, FRACTURE, CEMENT sQuEEzE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ,, See attached Frac;ure Stimulation Summer,y. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) ' I Date of Test Hours TeSted PRODUCTION FOR OI L-BBL GAS~MCF WATER-BBL cHOKE SIZE "1GAS-OI L RATI'O TEST PERIOD '" Fl'ow Tubing Ca~'ing Pressure CALCULATED OIL-BBL GAS-MCF WATER~BBL OIL GRAVITY-APl (corri Press. 24-HOUR RATE 28. CDR E DATA Bri'ef description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Form 10-407 GRU4/WC70 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. 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 B 8096' 5940' N/A Top Lower Sand 8173' 6001' Base Lower Sand 8330' 61 27' 31. LIST OF ATTACHMENTS Addendums 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ ~ y Title Associate Engineer Date --~°~'~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- .iection, Gas Iniection Shut-in~Other~e×p!a;n r:orm 10-407 ADDENDUM WELL: 10/19/84 2G-6 8368' PBTD MIRU WL unit. RU lub & tst to 2500 psi. TIH w/Temp/CCL log, tag btm @~8357', log f/8340'-8000'. POOH, RD WL unit. Operations completed. Secure well. Drilling S~perintendent ADDENDUM WELL: 10/19/84 11107184 11/10/84 11/11/84 11/14/84 11/27/84 2G-6 8368' PBTD MIRU WL unit. RU lub & tst to 2500 psi. TIH w/Temp/CCL log, tag btm @ 8357', log f/8340'-8000'. POOH, RD WL unit. Operations completed. Secure well. Frac'd well with 50 bbls gelled diesel w/1 ppg 100 mesh, 85 bbls gelled diesel w/3-7 ppg 12/20 mesh. Screened out w/7 bbls. Flush away leaving 10,910# 12/20 mesh in tbg. Att to CO, CTU frozen. Well SI. 8368' PBTD RU CTU f/CO. RIH, pmp gel @ .5 BPM/3000 psi to 7661'. Tag sand, inc rate to 1.6 BPM/3700 psi w/650 N? rate. Wrk CTU f/7835'-8335'. Flush w/85 bbls diesel-& POH SI well. 8368' PBTD RU lubr, tst to 3000 psi. RIH, tag 8368' PBD, POH, RD. Turn well over to Production. FRACTURE STIMULATION SUMMARY Begin Frac Work At: 0845 hrs, 11/27/84. Dowell frac'd "A" sand perforations 8188'-8198' & 8216'-8246' in 8 stages per 11/21/84 procedure using hot diesel & gelled diesel. Pressured annulus to 1000 psi with diesel. Test lines to 6500 psi; OK. 1. Pmp 140° diesel ahead @ 12 BPM/4550 psi 2. Pmp 140 bbls gel/diesel @ 20 BPM/5000 psi 3. Pmp 5 bbls gel/diesel @ 20 BPM/4500 psi 4. Pmp 98 bbls gel/diesel w/.5#/gal 100 mesh @ 20 BPM/4500 psi 5. Pmp 30 bbls Spacer @ 20 BPM/3400 psi 6. Pmp 26 bbls gel/diesel w/2#/gal 12/20 @ 20 BPM/2700 psi Batch mixer sanded off at manifold; unable to CO. Abort any further att to flush to perfs. Pmp 1800# 100 mesh in formation leaving 2000# 12/20 & 200# 100 mesh - 90' fill in casing. Load to recover 159 bbls of diesel. Job complete @ 1130 hrs, 11/27/84. (cont'd) WELL: 2G-6 11/30/84 12/01/84 12/03/84 8368' PBTD, SI; waiting f/WL ck on PBTD Flowing well to tst tank. Total fluid produced = 367 bbls. RU S/L, tst lubr & BOP to 3000 psi. RIH & ck PBTD following frac attempt. Tag PBTD @ 8242'. Temporarily turned over to Production to test. 8242' PBTD, Temporarily turnover to Production RU S/L, RIH to ck PBTD, tag PBTD @ 8242' KB. Drilling~ Superintendent Date ADDENDUM WELL: 10/19/84 11/07/84 11/10/84 11/11/84 11/14/84 2G-6 8368' PBTD MIRU WL unit. RU lub.& tst to 2500 psi. TIH w/Temp/CCL log, tag btm @ 8357' log f/8340'-8000' , · POOH, RD WL unit. Operations completed. Secure well. Frac'd well with 50 bbls gelled diesel w/1 ppg 100 mesh, 85 bbls gelled diesel w/3-7 ppg 12/20 mesh. Screened out w/7 bbls. Flush away leaving 10,910# 12/20 mesh in tbg. Att to CO, CTU frozen. Well SI. 8368' PBTD RU CTU f/CO. RIH, pmp gel @ .5 BPM/3000 psi to 7661'. Tag sand inc rate to 1.6 BPM/3700 psi w/650 N2 rate. Wrk CTU ~/7835'-8335'. Flush w/85 bbls diesel & POH SI well. 8368' PBTD RU lubr, tst to 3000 psi. RIH, tag 8368' PBD, POH, RD. Turn well over to Production. (cont ' d) 11/27/84 11/30/84 12/01/84 WELL: 2G-6 FRACTURE STIMULATION SUMMARY Begin Frac Work At: 0845 hrs, 11/27/84. Dowell frac'd "A" sand perforations 8188'-8198' & 8216'-8246' in 8 stages per 11/21/84 procedure using hot diesel & gelled diesel. Pressured annulus to 1000 psi with diesel. Test lines to 6500 psi; OK. 1. Pmp 140° diesel ahead @ 12 BPM/4550 psi 2. Pmp 140 bbls gel/diesel @ 20 BPM/5000 psi 3. Pmp 5 bbls gel/diesel @ 20 BPM/4500 psi 4. Pmp 98 bbls gel/diesel w/.5#/gal 100 mesh @ 20 BPM/4500 psi 5. Pmp 30 bbls Spacer @ 20 BPM/3400 psi 6. Pmp 26 bbls gel/diesel w/2#/gal 12/20 @ 20 BPM/2700 psi Batch mixer sanded off at manifold; unable to CO. Abort any further att to flush to perfs. Pmp 1800# 100 mesh in formation leaving 2000# 12/20 & 200# 100 mesh - 90' fill in casing. Load to recover 159 bbls of diesel. Job complete @ 1130 hrs, 11/27/84. 8368' PBTD, SI; waiting f/WL ck on PBTD Flowing well to tst tank. Total fluid produced = 367 bbls. RU S/L, tst lubr & BOP to 3000 psi. RIH & ck PBTD following frac attempt. Tag PBTD @ 8242'. Temporarily turned over to Production to test. Drilii~u-pe~intendent ," tDate ARCO Alaska, Ir~'~ Post Off, icc Uox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 6, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2G-6 Dear Mr. Chatterton' Enclosed are the Well Completion Report and the gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU2/L73 Enclosures RECEIVED Nov o Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ' ' "' ~~. ,L STATE OF ALASKA ~------, , ALAs AND GAS CONSERVATION . ..,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , ,., 2. Name of Operator ' ~'7. Permit Number ARCO Alaska, Inc. 84-82 ,,. "3. Address '8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21121 4. Location of well at surface 9. Unit or Lease Name 547' FSL, 236' FWL, Sec.32, T11N, RgE, UM ~~' Kuparuk River Unit' At Top Producing Interval 1 VERIFIED ~ 10. Well Number 1387' FNL, 1339' FEL, Sec.32, TllN, R9E, UM~_~iSurt~i 2G-6 ...... At Total Depth ~B. trl-_~t 11. Field and Pool 1268' FNL, 1198' FEL, Sec.'32, TllN, RgE, UM~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.)16.Lease Designation and Serial No. Kuparuk Ri vet Oi 1 Pool 140' RKBI ADL 25656 ALK 2582 , 121 Date Spudded06/11/84 13. Date T.D. Reached06/16/84 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °'f c°mpleti°ns09/24/84 N/A feet MSL 1 17, Total Depth (M D+TVD)i 18. Plug Back Depth (MD+TVD)19. Directional Survey I 2o. Depth ~here SSSV set ! 211Th,ckne'~'s of Permafrost 8485'MD,6252'TVD 8368'MD,6158'TVD YES [] NO [] 1903 feet MD 1.500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/Cal · Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD · CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H~40 Surf 110' 24" 202 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3134' 12-1/4" 1035 sx Permafrost E & 250 sx Permafrost C , 7" 26.0# J-55 Surf 8449' 8-1/2" 575 sx Class G & 250 s~ Permafrost C _ 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) 8246' - 8226' 3-1/2" 8118' 8087' 8225' - 8216' 8188' - 8198' 26. ACID, FRACTURE' CEMENT SQUEEZE, ETCi DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED , .N/A .... 27. N/A PRODUCTION TEST Date First prOduction I MethOd of Operation (~lowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION'FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE.. GAS-oIL RATIO · TEST PERIOD I~ ,, Flow Tubing Casing Pressure CALCULATED :1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE -~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips' NONE Alaska Oil & ~as Cons. Comrnissio~ Anchorage ,,. Form 10-407 GRU2/WC08 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30; 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 B 8096' 5940' N/A Top Lower Sand 81 73' 6001' Base Lower Sand 8330' 6127' 31. LIST OF ATTACHMENTS We!! History, Workover We!! History, Gyr .... pie Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Area Dri ] ] i ng 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 (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. r-orrn 'i O~4t) / ARCO OII ~nd Git ~~y,, ~ lallm~k.~l: Pmplrl ItM tl~i~~ ~1¥,111t flrll W~ ~ · ~1 i~ ~d~ or wooer o~1~ ~ ~. Oal~ w~ ~ ~ ~~ ~ ~~ ~ the ~ giving I~lu~i~ dat~ only. Oiltd~t Alaska Field Kuparuk River Auth. or W.O. no. AFE 902161 Well Hlltory - Initial Report- Dally lState lCounty, pariah ~' I~orough North Slope Borough ADL #25656 or Unit Title Drill, Complete & Perforate Alaska ,~Gell no. -6 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate IHour Spudded 6/11/84 0830 Hrs. Date and depth aa of 8:00 a.m. 6112/84 Complete record for each day rePorted 16" @ 110' 2172', (2062'), POOH to PU Navi-Drl Wt. 9.6, PV 26, YP 30, PH 8, WL 10.6, Sol 8 Accept ri~ at 0700 hfs, 6/11/84. 6/11/84. Drl 12¼" hole to 2172'. 500', Assumed vertical 669', 4.1°, N45.3E, 668.86 TVD, Spud well @ 0830 hfs, 6.04 VS, 24.57N, rARCO W.I. Prior stltUl 56.24% If a W.O. 6113184 6114/84 6/15/84 1169', 16.6°, N44.9E, 1159.96 TVD, 94.37 VS, 98.96N, 66.92E 1310', 20.2°, N42.SE, 1293.73 TVD, 138.75 VS, 151.86N, 97.52E 1713', 20.3°, N45.3E, 1672.49 TVD, 276.14 VS, 198.07N, 193.04 2122', 30.1°, N48.3E, 2042.67 TVD, 448.85 VS, 317.33N, 318.01E 9-5/8" @ 3134' 3155', (983'), Prep to cma Wt. 9.5, PV 19, YP 23, PH 8, WL 10.8, Sol 7 Navi-Drl to 3155', 10 sad short trip, C&C, POOH. RU & rn 79 its, 9-5/8", 36#, J-55 HF-ERW BTC csg w/FS @ 3134', FC @ 3052'. 2237', 34°, N46.3E, 2140.12 TVD, 509.86 VS, 358.71N, 362.84E 2567', 43.2°, N49.7E, 2397.49 TVD, 715.77 VS, 495.58N, 516.72E 2942', 49.7°, N45.6E, 2653.80 TVD, 989.17 VS, 680.07N, 718.49E 3072', 49.7, N48E, 2737.88 TVD, 1088.31VS, 747.94N, 790.76E 9-518" @ 3134' 3808', (653'), TOH f/DD Wt. 9.3' PV 5, YP 7, PH 9.5, WL 12, Sol 5 Cma 9-5/8" csg w/1035 sx PF "E", followed w/250 sx PF "C". Displ using rig pmp, bump plug. ND diverter & 20" Hydrl. NU & tst BOPE to 3000 psi. RIH w/8½" BHA to 3052', tst csg to 1500 psi. DO plugs, FC, cma, FS + 20' new formation. Conduct formation tst to 12.5 EMW. Drl 8½" hole to 3808', TOH f/Navi-Drl. 3403', 52.6°, NS1.6E, 2945.49 TVD, 1345.84 VS, 914.32N, 987.60E 3716', 53.4°, NS1.2E, 3133.86 TVD, 1595.23 rS, 1070.27N, 1182.95E I 9-5/8"'@ 50~') 6308', (2 , Drlg Wt. 9.6, PV 14, YP 17, PH 9.5, WL 4.8, Sol 8 Drl & surv 8½" hole to 6308'. 4049', 54.4°, NSOE, 3330.06 TVD, 1863.89 VS, 1241.05N, 1390.36E 4726', 53.6°, N49E, 3728.76 TVD, 2410.57 VS, 1594.11N, 1808.82E 5250', 52.9°, N47.7E, 4042.28 TVD, 2830.37 VS, 1873.13N, 2122.53E 5752', 52.4°, NSO.3E, 4346.84 TVD, 3229.26 VS, 2134.92N, 2423.68E The above la correct ARCO Oil and Gas Company Daily Well History-Final Report inatructio.a: Prepare and submit the "1~ I~' on the first Wednesday after allow&hie has been assigned or well is Plugged. AblndOnld. or Sold. "Final Rel~el't" should be submitted al~ w~ op~rotlol~l are suspended for an indefinite or aPDrscisOle length of time, On workoverl whln In offtciai lilt il not required upon completion, report comll~etl~ an¢:l relDre~efltatlve teat data in blocks provided. The "Final Rel~ell" form may be u~ed for reporting the entire operation if space is available. District I Pariah Alaska County or Field Lease or Unit Kuparuk River Auth. or W.O. no. ~Title I AFE 902161 Roll'n #4 Operator ARCO Alaska, Inc. Spudded or W.o. begun Completion Date and depth Complete record for each day reported as of 8:00 a.m. North Slope Borough ADL 25656 Completion IAccounting State coat center code Alaska IWell no. 2G-6 AP1 50-029-21124 IA.R.Co. W.I. 56.24% lost, 9/23/84 Intel number of wells (active or inactive) on ttlia, pst center prior to plugging and bandonment of this well our ' IPrior status if a W.O. 0330 hfs J 9/23/84 9/24/84 7" @ 8449' 8368'.PBTD, Drop ball Accept rig @ 0330 hfs, 9/23/84. ND tree, NU & Cst BOPE. RU DA, perf 8246'-8226', 8225'-8316' & 8188'-8198', POH, RD DA. RU & rn 253 its, 3½", 9.3#, J-55 8RD EUE tbg w/SSSV HRP-1SP pkr @ 8087', "D" Nipple @ 8105', Shear Sub @ 8117', tbS tail @ 8118'. ND BOPE, NU & tst tree to 5000 psi. Displ well w/30 bbls diesel, followed by 255 bbls crude otl. Drop ball to seaC on shear sub. GLM's: 1942', 3846', 5717', 7300', 8031' 7" @ 8449' 8368' PBTD, RR Set pkr. Pressure up to 3200 psi. Test tbg. Test annulus to 2500 psi. Shear ball out. Test SSSV. SeC BPV. RR @ 0930 h~s, 9/24/84. Old TO Released rig 1530 hfs Classifications (oil. gas, etc.) Otl tNew TD IPB Oep,h 7697' PBTD Date Kind of rig 10/13/84 Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval' Oil or gasTest time Produciion Otl on reit Gal per day .... . Pump size, SPM X length Choke size TP. C.P. water % GaR Gravity Allowable Effective date corrected ..... I ,,, The above is correct For form preparation and c~tribution, see Procedures Manual, SeCtion 10, Drilling, Pages 86 and 87. AR3B-459-3-C 10/24/84 ITM Dri~i~ NOV 0 8 Ig84 Alaska 0ii & Gas Con.~_ Nnmmi~.~inn ... Number iii dally well hlltory forms al they a~e prepared for each wel. ~tlve~ Page no. DlVlillo~l M At~k:~l~Ml~dComl~y i, Eastman A PETROLANE OOM~ REPORT SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA, INC. COMPANY Pad 2G, WEll Number: 6 WELL NAME Kuparuk Field, North Slope, Alaska LOCATION .J, qB NUMBER A0684Z0277 'r.,.,,~,o~ su.v~¥ DATE 27-JU~?- 84 Nov 0 Alaska Oil & Gas Cons. Commission Anchorage SURVEY BY COR~/JR~N OFFICE Anchorage, Alaska Eastman DATE: July 26, 1984 (907) 563-3650 P. 0. Box 4-1970~Anchorage, Alaska 99'309-1970 ARCO ALASKA, INC. P.O. BOX 360 Anchorage, Alaska 99510 Well Number: Pad 2G, WEll No: 6 Location: Kuparuk Field, North Slope, Alaska Type of Survey: SIGMA-Gyro Date: 27-JUN-84 Method of Computation: Radius of Curvature Surveyor/Driller: CORAM/JAHN Job Number: A0684Z0277 Attn: Mr. BILL CONGDON Dear Mr. Congdon, We are enclosing the original and one copy/copies of the SIGMA-Gyro survey run on the above mentioned well. To date, the following distribution has been accomplished: A. 1 copy/copies delivered to drilling for in-house distribution. B. 6 copy/copies for noted oil company representatives. C. 3 copies for E/W permanent well files. We wish to take this opportunity to thank you for using Eastman Whipstock and look forward to being of service in the future. TOM Dis Technical di tot t~t Coor na cc/file P.A. DIMMOCK KAREN MESTAS STEVE LAMBERT T.A. EDMONDSON N.H. SMITH JR. J.C. WILLNER BP ALASKA.EXPLORATION, INC. SOHIO ALASKA PETROLEUM CO. UNION OIL CO. CHEVRON U.S.A., INC. MOBIL OIL CORP. PHILLIPS PETROLEUM CO. Directional Drillers/Sub-Surface Suweyors/Ins~rnent & Tool Rentals/Sales/Worldwide ARCO ALASKA-, INC:. PAD 26, WEL. L NO: 6 .?;IBMA-GYRO .JOB NO: AO6:--.:4Z0277 KUPARUK FIELD, NORTH SLOPE, ALP-~SKA SIGMA-GYRO: 0-82'50 Mit, SURVEYOR: CORAM/,JAt4N., DATE RUN: 27-JUN-'.--_:4 S I OMA 300 I',10: 27 ;!. ,. F'Rr')BI::' I',,I0: 05'7 FORESIGHT: DUE NORTH SURVEY TAKEN FROM WELLHEAD VERT I L:AL '.=;ECT I ON CAL¢:ULA'I'ED I N F'I Al',.!E "OF pFiIOPOSAL £1IREC'fll2'i~,ll N 4-7 DEG. 30 MIN. E i-if:: '.E:i..IRVE Y R~l-III..l:3 L')I:-- I-:URV~TURE METI-400 RCO Al_ASEA, INC:. AD 20, WELl_ NO: /:, SIGMA-GYRI] UPARUK FIELn, NORTH SI...OF'E, ALA'.E;KA ._lf"tB r, ll'i: ~(')6:.=:4 Z(")';]'77 F:flMF'U"r A'T I ON "f' I MIE DA'TE 0'7: 53: 4 (:) 2 ,'::.-' ...I i_1 L- F-: 4 PAGE NO. EASURED DRIFT DRIFT DEPTH ANGLE DIRECT I ON LENGTH DI--F'TH FEET D M D M. FEET FEET TRUIS COURSE VER'rlCAL VERTICAL '.:-::UB:=;EA R E C T A N G U L A R C L. 0 .S; I_1 R E DCIGLEG SECTION TVD C 0 0 R D I N A T E '.:_; DISTANCE DIRECTION SEVERII'Y FEET F'EET FEET FEET D M DO/100F'f i 100. 2'00. 300. 400. 0 0 0 0 0 18 ¢'._. 40 0 W 0 36 S 20 24 W 0 41 ¢'._. 7 F.A_. E 0 19 S 40 56 E 0. 0.00 0.00 - 14.(). 00 0.00 0.00 '=' 0,17 W 100. 1AC}. _. C~0. -.0. '::' ~.~. .., -40 . ('~(').. 0..~.?(] .., ,=,o ,:. 0 ~'" W 100. 2(')c~. 00 -- 1 .02 ,S0.00 0 ~ ..... :, ..... ._, 7 100. 299.79 -1.8'7 159.'P9 2.01 'S 0 69 W 100. :3'P'F~. 'P'F' --2. 14 '259. 'P'P 2.81 S 0. :3:3 W 500. 600. 700. 800. 900. 0 43 N 63 42 E 2 ::6 N 50 6 E 4 48 N 41 19 E 7 5 N 4:3 2 E 9 41 N 45 45 E 1 O0. 479, 'F~8 - 1.64 359. ?E: 2,9'7 S 0.50 E 100. 5'P':,. ?'3 1.21 459. ':73 1.40 S 2.9:3 E 100. 699.72 7,67 559.72 3.12 N 7.55 E 100. 799.17 18.03 659. 17 J0.49 N 14.84 E 100. 8'PE:. 07' 32.63 758.09 20.47 N 25.51 E 1000. 1100. 1200. 1300. 1400. 1500. 1600. 1700. 1800. 1~00. 12 12 N 39 32 E 14 59 N 39 43 E 17 40 N 4-:3 41 E 20 35 N 43 58 E 21 47 N 4:3 35 E 2021 N 44 3 E 19 25 N 44 17 E 20 47 N 44 4 E 22 27 N 44:34 E 24 42 N 45 I E 100 100. 1470.42: 100. 1564.46 1 A 0. 1/- ?]':' 37 --. '-- '--' n 100. 17.51. :3 ::-: 100. 1 :--: 4'T-:. 'p7 171.56: 1237.12 '-"-' ~ 43 207,44 1 .-,.=,C , 241,40 1424, 4-/_-, 2,7~ 71 151:3.37 312.50 1611. :.-=::3 :=:52.4/:. 1702.97 O. 00 0 0 0.2/:, ¢' 40 0 W 1.05 S "32:38 W 2.,12 S 18 58 W '2,::'l::'::.:,'-' 6 40 W .:,'-',02 '.:; c-.~. 36 E :3.24 :-.:; 64:30 E :::. 17 N 67 .:,'-"-:'..., E 18. 1::3 N 54 45 E :32.70 N 51 15 E 0.00 0.30 O. 34 0 ,, :2:3 0.") 0.71 1. '?0 2.26: 2.38 2.62 34.44 N 3:3.37 E ~S2~ 54., . ~2.53" 06:3/:' EE '-:', 7 15 ..~,ir~,.~~. N ??:~. 75 E ]149.19 N 144.66 E 17:3.58 N 168.:]:6 E 198.23 N 192.3'2 E 224.59 I',1 218.06 E '--'.=,'---' '--.~::: N 24/:, 2~ E 51.56 N 4.8 6 E 74,8:-: N 45 27 E lC)'..-_-' '-~ N 44 '-'- /6 E . - . .~!._l 17:5.71 N 44 17 E 171.85 N 44 11 E 207.80 N 44 7 E :241.""'-',:.~ N 4.4 7 E 276.1':? N 44 8 E :::].:-_-:.04 N ~4 9 E :353.04 N 4-4 14 E 2.77 2.78 2.91 2.91 1.2:2 1.45 0.94 1.3:7 I.,./ ) .-- , 2000. 2100. 2200. 2300. 2400. 27 37 N 46 8 E :=:0 ~ N 46 :=:1 E 33 12 N 46 22 IS 36 ? N 46 3:7 E 3:.? 6 N 47:36 E 396.53 17'P2.71 44-4.79 1880.28 497.2.5 1965.40 554. 14 2047./:,2 615.20 2126.80 2:.::::3. :::4 N 277, 74 E 317, 16 N :E:12./-.'.6 E 353.31 N 350. ,.'":,"P E · -.o-. :_--:$/ . 96 .:...,'.48 N 1 E 4:34.0:3 N 4:---:6.70 E .39'7. 12 N 44 2:3 E 445.2:6 N 44 35 E 497.81 N 44 47 E 554,6? N 44 58 E 61!q_.'7. Cl.. N 4.J ~ IIE 2500. 2600. 2700. 2800· 2~00. 40 57 N 49 43 E 43 59 N 48 46 E 46 2/:. N 45 56 E 47 56 N 46 42 E 49 18 N 44:3? E 00. 2343.36 00. '2417. 11 00. 24:37. :].~ 00. 2555,49 00. 2621,5'=? 67'?. 51 220:3 · 36 74/:.. ?'F,' 22'7'7, I 1 8 t 7. ':? 6 2347,55 8'Pl. 31 2415.49 966. =: 1 2481.5'.=.' 476.51 N 485,00 E · _,..'0.58 I',1 .~:::A ..... . 1=._, E 5/:.:3.66 ri. 5L:::-:: · :5:5 E 61'?.:::2 1'.1 6.41.41 E /:.71.74 N 6.'P5.10 E 67':?.92 N 45 L=:O E '74'7. :30 N 45 51 E 81:!::. '25 N 4..=.; 5'P E :E:gl.~t.l N 46. 0 E 'P66.65 N 45 5'.-.-/ E 2.2? 3. I 0 :E: 1':' 1.60 "=' C) 7 -' ~ _ . ARCO ALA:_=:KA. INC. PAD ~.l-.' . ,~.,~ WELL NO. 6 ..,':'IGMA-AYRn,, _ KUPARUK FIELD, NORTH ::~LOPE, ALASKA ._10 B N 0: A 0/:.84- Z 0277 COMPUTAT I ON 'r I ME 1]ATE 07: 5.3: 40 26 -,_11_11_-84 F'AOE NO, ,. '2 TRUE MEA:::URED DRIFT DRIFT COURSE VERTICAL VERTICAL '.::LIBSEA R E C T A N G I_1 L. A R F: L. 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEF'TH SECTION 'rVD C 0 iD R D I N A T E S DISTANCE DIRECTION .SEVERI FEET D M D M FEET FEET F'EET F:EET FEET F'EET D M DG/100F] 3000. 48 47 N 45 29 E 3100. 50 19 N 47 22 E 3200. 52 7 N 48 13 E 3300. 52 45 N 48 I E 3400. 52 51 N 48 3 E .'::.'=,,AO ~":' I N 47 4-9 E 3600. 53 /_-, N 47 41 E 3700. 53 17 N 47 48 E 3800. 52 46 N 4:3 14 E 3900. 54 33 N 47 31 E 100. 2687. 12 1041.77 254'7.12 100. 2751.99 1117.86 2/:.11.99 100. 28 ] 4.62 1195.80 2674./:)2 100. 2:E:7.5 · 5'.'} 1275. 07 2735. 5':} 100. 2936. 04 1 :}54. 73 27'96. 04 '725. 0:3 N 74'8.5:3 I-- 1042. 17 N 45 55 E 7'7'7.5::: N 80:]i:. 72: E 1118.27 N 45 57 E 82'2.89 N 861.4.7 !-- 11'96. 18 N 46 4 E 882.80 N 920.4'.--.~ E 1275.40 N 46 12 E 936.06 N 979.73 E 1:355.02 N 46 18 E 100. 2996.31 1434.5:3 ~'--":'~/:.. :31 98'-}. 5:2: N iA:--:::: ..... 97 E 1434 7? N 46 24 E 100. 3056.40 1514.45 291. 6.40 1043.26 N 10'98. 14 E 1514.6':.;~ N 46 28'E 100 :311 Z--, .31 1 ~ ~ . . .:,~ ..... :,;~4,51 2976.:.31 1097.09 N 1157 41 E 1.5.94 74. N 4/:, '-"-' E 100. 3176.44 1674.41 3036.44 1150.52 N 121.6.81 E 1/-,.74.61 N 46 36 E 100 ':"---"--'~. 6'? 17._ 4 '--.M, 3095.69 2A4 55 . ........... ~ .. - 1 . N 1276.57 E 1'755 15 N 46 40 E 0.82 2.09 I .92 0.66 0.25 0. ~ :3 0.21 1.87 4000. 54 36 N 47 18 E 4100. 54 16 N 47 7 E 4200· 53 48 N 47 8 E 4300. 53 53 N 47 18 E 4400. 54 0 N 47 24 E 4500. 53 48 N 48 3 E 4600. 53 49 N 48 21 E 4700. 53 37 N 48 40 E 4800. 53 26 N 48 40 E 4900. 53 30 N 48 32 E 1AO. :329:-] .......... 6,~' 1':":'/--._, 4/:, :315'-"' ........ ::,..,'"': 1'-''=''''~...,?. 69 N 13:2:/_-,. 57 E 1:336. .64 N 46 42 E 100. "'"~ 80 ~' · :,o._,1 ' 1917 ,:,0 3211 80 1314.94 N !3¢//-,.27 E 1.'~1'? oF': N 46 4:3 E . : ,~ ee · : , ,~ : ~ .... · .. -- 100' 3410.5~ 1~,_<3.'74 3270..'5.2_' 1:_'3'7'0. Of.'hi 14$~. 60 E 1998.'92 N 46 44 E 100'.; - 34/-,9 . '-; 1 26)79.49 ...,":":'"~":~,_,~....._% 1 ~1424. . ~.5N 1~4:. 87 E 2c)79.. . 67 N 46 45 E 100, ~'='-"-' . ,a...,;o. 3,5 21/~0. ~.5 33L98. :35 1479. &i.2, N 1~,.~ 34 E 21/:,0.5'7.' N 46 47 E . , , :,~. :,,, 00. 358'7.25 2241.15 3447.25 1533.~.~8 N 1634.14 E 2241.3:2 hi 46 49 E 00. 3646.28 2321.87 3506.28 1587.77 N 16'94.32 E 2322.01 N 46 52 E · -' ' '=' '-"=' '-' . 5 . 2402./_-,A :i.~ E c}0. .:,7o._,. 45 2402.47 .:, ._, 6 ._, . 4.5 1641 18 N 17._ 4 71 E N 4/:, 00. 3764.87 2482.:37 3624.89 16'74.27 N 1815. 10 E 2482.97 N 46 58 E 0c). :2::--:24.41 ".:.'5/-_..3. 20 :36:E:4. 41 1747. :39 N 1 ::::75.39 E 2-5/:.3. '2'.'.-;N 47 1 E 0. 1:3 0.37 0.4/.-., 0·16 0. ] 5 0.56 A. 24 0.32 A. '] 5000. 53 0 N 48 28 E 5100. 53 14 N 48 33 E 5200. 52 56 N 48 25 E 5300. 52 51N 48 24 E 5400. 52 47 N 48 21E 100. :3:3::34.2 q- 264 :.3. :3:3 :3744.24 1800.47 N 19 :::5.42 E 2..' 64 :'::. 4 () N 4. 7 4 E 10 ~.]). :3944.25 272:3. :30 3804. '-'.=, 853 1995 N =.. I .46 N .35 E 272:3. :_--:6 47 7 E 1.00 40()4:30 2:3(')3 2.5 :3:364. :30 19(]/-.. 45 N '-'"'~ .... ....... · -- ...... _,. 2:3 E 280:-::. :'::A N 4-7 '? E 100. 4064.61 2882:.01 3924.61 1959.39 N 2114.89 E 2:E::B3.05 N 47 11 E 100. 4125.03 2962.68 39~85.03 2012.32 N 2174.46 E 2962.72 N 47 13 E 0.51 0.25 0.32 0.08 O. 08 5500. 52 48 N 48 25 E 5600. 52 42 N 48 29 E 5700· 52 21N 48 26 E 5800. 52 ? N 4:3 59 E 5900. 51 51N 49 4 E 00. 4185.49 .'_--.:042. 33 4045.49 2065.21 N 2234.02 E :3042.2:6 N 47 15 E 100. 4246.00 3121.'.92 4106.00 2118.00 N 22'93.60 E 3.~21.'95 N 47 17 E 00. 4306.83 3201.28 4166.83 2170,6'2 N 2:-::53.03 E 3201.:30 N 47 19 E (1)0. 4368 o 03 32:E:0. :::5 4228. 03 2222. 80 N 12412.45 E 32:::0. :36 N 47 21 E 00. 4429.58 3359.13 4289.58 2274.46 N 2471. '96 E :?.:--'.5'-]. 1 3N 47 23 E 0.0/:, O. 10 0..'.--.: 6 0.47 0..'31 ~RCO ALASKA, INC:. :°AD 2G· WELL NO: 6 SIOMA-.F:YRO <UPARUK FIELD· NORTI~ SLOPE, ALASKA .JOB NO: AO684Z0277 COt.IPLITAT I ON T I ME DATE 07: 5:=:: 40 26-01_1L_-84 PAOE NO. :.'3 TRUF MEASURED DRIFT DRIFT , COLIRSE VERTICAl_ VERTICAL SLIBSEA R E E: T A N O U L A R C L 0 S I_1 R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION, TVD C O O R D I N A T E S DISTANF:E DIRECTION SEVERITY FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/1 OOFT 6000. 51 50 N 49 0 E 100. 4491.36 343'7.74 4:351.36 2:=:26.01 N 25:31.35 E 3437.74 N 47 25 E 6100. 51 58 N 48 53 E 100. 455:=:.05 :3516.41 4413.05 2377.69 N 25'.=/0., 71 E 351/...41 N 47 27 E /.,200 51 54 N 48 4.1 E ' 'i 00 4/-, 14.70 '-'=':,'~ .... . . .=.._,.-.... 1:.2 4474.70 242'.:.? 55 N 2649 '-}4 ,"-!: :35'P5 12 N'-"'47"~2-~)'" E 6300. 52 16. N 4:==': :35 E 100. 4/..7/...14 3/=.74.01 4536.14 24:.:.:1./..,9 N 2709.16 E :'::674.01 N 47 31 E 6400. 51 47 N 4.7 38 E 100. 4737.67 :2:752.8:3 4.597.67 2534.:31 N :2'767.8!5 E :3752.:3:3 N 47 31 E 6500. 50 16 N 47 45 E 6600. 48 20 N 47 57 E 6700. 47 25 N 49 4 E 6800. 46 57 N 49 34 E 6900. 46 28 N 4'? 18 E 100. 4800.'57 ::-:8:3C~. ~;7 4660.57 25:=:6.6:3 N 2825.35 E ::-:830.57 N 47 32 E 100. 4865.76 3906.39 4.'725. '76 '2637.50 N 2881.5-/ E 3'P0/=.. :}'F* N 47:32 E ,: .... , ,-,.:, .-,¢~,-,r~ F,= 33 100 4.'~.:,~.,: .... .... , 4.7'T¢2 8:3 26:::6 6:3 N 2'.:237 14 E :=:.9~:0 :i:' N 47 E 100. 5000.7'.~ 4053.87 4860.7'~ 27:34.44 N 29'P2.77 E 405:3.87 N 4'7:5:5 F 100. .506'.--.~ · 35 4126,. 62 4'.'.-'~2'P. :=:527:::: 1.78 N :3048.0'7 E 4126.6:5: N 47 37 E · . 0.06 0. 16 0.17 0.36 () ~'~ 1 · 52 I. 9:3 I. 25 0. 0.51. 7000. 46 15 N 49 23 E 7100. 45 57 N 4'? 21 E 7200. 45 18 N 49 32 E 7300. 45 18 N 49 10 E 7400. 44 27 N 4'.:.~ 0 E 7500. 43 52 N 49:32 E 7600. 42 46 N 49 57 E 7700. 42 15 N 49 41 E 7800. 41 6 N 49 24 E 7.900. 40 13 N 4'P '=-.~ E 100, :.51:3:3..'2:(~ ..... 419:3. ?7 4-'F¢'2:3. :3/'=,'2:32::3. 'F¢:3 N :'=: 1 (:):3. C)0 E 41 '.;,':=:. ?8 N 47:39 E 1()0;':' /5207.6~~''- a~l,.O0 5067.6.'~ -=,:.A'~.~ c, 5 ~,, o,. 69 01 4C) /'-4~",~,~ ¢:B'2-,"'""-"44', 51'37 61 """:'*~:""~? ''~' 't'""'57" E 4.:271. N 47 E ILO,] ' ¢ ':'""..,.-'77. . 2'.~¢~' 1~'~':;~:~t~.!2.()1 E 4:342.47 N 47 42 E · '='-' w.'F,'4 5207.':-.¢4 . . N 47 44 E 1(~,,~ ._,.=,4, 44!:3.,4~ 27.>68,d.:3 N ~,~,.'76. E 44.13 5:'::: I,D,);.',, 54,1,:3.7'2, 44:34.0.]: 527:3.79 30{4:,:3~::r4 ~;?.2e E 4484..0c.i: N 4.7 45 E 100. :5490.52 455:3./.,7 5350.52 3060.2c/ N :=::372.09 E 455:3.7:2: N 47 47 E · ' '-"-' =; '-"-' "::':~ .6',7 .... 100 5!56.:]:. 28 4,.:-,.,::..-. · 22 ._ 4..:...:- .....31 (:)4 N :3424.4-6 E 4/-.22'.. '.;"-.-* N 47 4:_:: E 100. 56,:::6.'.-.-¢9 468?,'. 75 54'?6. '?? :'::148.21 N :::476.0'? E 44):=:9.8:=: N 4.7 50 E 100. 571 I./_-..7 4756.. 21 5571.4..7 3191.36, N :3526.. 70 E 4'756.. :3(.'.) N 47 51 E 100. 57 :=: 7 . .~;_ 2 4 ~-:: 21 . :34 .=;._ ,..."- -, ~ ~, . F;_ .'2 .-,'-' .,:.'-"='._, '='..... ::: ...... 6 N :=: .='; 7/-. . O'P E 4. 821 . 44 N 47 F;_ :3 E 0.2~ 0.29 0.67 C). 26 0.85 0.70 1.]4 0.53 C) · ':.- ,= 8000· 39 10 N 48 57 E 8100. 37 57 N 49 4 E 8200. 36 40 N 47 5 E 8250. 36 I1 N 47 43 E 100. 58,'34.47 4:385. 18 5724.47 3275.71 N 3624.33 E 4:385.2'.:.'~ N 47 54 E 100. 5'P42.65 4'..7-'47.50 5802.-65 3316.60 N 3671..3'F.~ E 4.'747.62 N 47 54 E 100. 6022. 18 5008. 10 5882. 18 3.356.29 N 3717.22 E 5008.2:3 N 47 55 E 50. 6062.40 5037.78 5922.40 3375.61 N 373".:.?. 77 E 5037.92 N 47 56 E 1.05 1.22 1.2:3 1.22 PROJECTED TO PBTD 8368. 3!-_. 11 N 49 43 E 118. 6157.6:? 51C)7.42 6C) 17.6'--/' 3420.67 N :37'=}2.94 E 5107.5:3 N 47 57 E o.00 PROJECTED TO TD 8485. 36 11 N 4':.* 43 E 117. 6252.04 5176.46 ./:,112.04 3465.34 N :3::-..:45.65 E 5176.64 N 47 5'.=7 E 0.00 F I NAL CLOSLIRE -- D I RECT 101',1: [I I STANC:E: N 4'7 DEOL=; 5:3 M INS 4(:) SECS E 517/=.. 4,4 FEET ARCO ALASKA, INC, PAD 2G, WELL NO: 6 SIGMA-GYRO ._lOB NO: AO684Z0277 KUPARUK FIELD, NORTH .SLOPE, ALASKA :E:IOMA-GYRO~ 0-E:250 MD, SLIRVEYOFi.': C:ORAM/.]AHN, DATE RLIN: 27-._ILIN-84 SIGMA 300 NO: 271, PROBE NO: 057 FORESIGHT: DUE NORTH SURVEY TAKEN FROM WELLHEAD Rt~COR01 ,JIF ]NTERF'OLATED ~I~V~¥ ~Ri'_:O ALASKA, IhiE:, :'AD 2G_, WELL NO: 6 c.._,ir~MA_AYRn .... ::UPARUK FIELD" NORTH SLOF'E~ 'ALA'.-=;KA MARKER ........ · ' CODE .................. NAME MEASLIRED nEF'TH FEET "1 ' ' I" "B" TOP K.IF ARLI .... TOP LOWER SANr~ BASE LOWER :E;AND 8096. O0 817:3.00 i--:330.00 TRUE VERT I CAL DEPTH FEEl' 6000 · 71 61 '-" ~- 'P6 ." ~-~ I COMF:'Li"rA"r I ON PAGE NO.' ,_lOB NO: AO684Z0277 TIME [lATE 07: 5 ~;: 0:3 .... -$. ,'~, :...:,'j Ot/:~'84 ............ SUBSEA V ERTIC:AL R E'"r: T A N G U L A R f'~EF'TH E: 0 0 R D I N A T E ¢'._, FEE'T FEEl' :}.':314,'.-76 N 3669.57 E · _7 N :]-:704 91 E ._.._i __ ._ · i~ . 3406.16 N :3775.8'.-T~ E C L 0 S'U"R E D I STANCE D I RECT I ON FEET D M 4'.--.~45, 17 N 47 54 E 4'P'.:.~1.92 m 4'7 55 E 5085]"2('i ....... 'N'" 47 57 E ,SKAg.'* · :. ~IELL ~ 6; Si I INC. ! HOR'~ ,ii, ,~, ,~. SuggeSted form to be inserted in each "Active" well folder to d~.eck f©r timely ccmpliance with our regulations. ' - Opera[orfW&ii Nafne' a~d Numbe'~ Reports and Materials to be received by: /~--~/~/--~'~ Date ,Required Date Received Remarks Completion ReFort Yes //_~,~ ,~ ~,~ _.. Well History Yes //_dF_~ · · · P/ ~ , . j . .. . Core Chips '' ,////~/~/~-. ._ n ~ ~,.. · , . .Core Description Registered Survey Plat . Incl±nation Survey · Directional Survey KUPARUK ENGINEERING Date: / Well Name: Transmittal Log Date Run # DISTRIBUTION NSK Operations Dr il 1 ing acgy /Ken o£I AK_--. -. Bluel{ne ~ .7_..~ e atta~ched '.!~ BluelineFilm ~ ' .~o3y a~ rece~p~f,~f'~~ .. ATO-1115B P.0. Box 100360 Anchorage, AK 99510 ARCO Alaska, ind''''~'~ Post Office =ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 20, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Enclosed are the Monthly State Reports for the following wells: 2G-5 2G-6 2G-7 2H-1 2H-2 2H-16 WSP #11I WSP #13 Thank you. Sincerely, JBK'jh LO1 06/28/84 Enclosures RECEIVED JUL 2 5 198~ Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany ,,'-'~ STATE OF ALASKA ?-', ~;j(~ ALASKA ~..' AN.D GAS CONSERVATION CO,..,vllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-82 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 5o- 029-21121 547' 4. Location of Well at surface FSL, 236' 5. Elevation in feet (indicate KB, DF, etc.) Pad 104, RKB 140 FWL, Sec. 32, T11N, R9E, UM 9. Unit or Lease Name Kuparuk River Unit 6. Lease Designation and Serial No. ADL 25656 · ALK 2582 10. Well No. 2G-6 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. June ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud well @ 0830 hrs 06/11/84. Drld 12-1/4" hole to 2172'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 8485'TD as of 06/16/84. Ran logs. Ran, cmtd & tstd 7" csg. Secured well & released rig @ 1700 hrs 06/18/84. Performed Arcticpk w/250 sx PF "C" & 60 bbls Arcticpk. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 9-5/8" 36# J-55 HF ERW BTC csg w/shoe @ 3134'. Cmtd w/1035 sx P'F "E" & 250 sx PF "C". 7" 26# J-55 HF/ERW BTC csg W/shoe @ 8449' cmtd w/575 sx Class "G". 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/aR/SP/FDC/CNL/CAL f/8481 '-3133'. 1 6. DST data, perforating data, shows of H2S, miscellaneous data N/A RECEIVED JUL2. 5/9 Alaska Oil & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. /~,/ i~~ ' Area Drilling Engineer S 'G N E D ' /~f/,/~-~/"f/l~ TITLE ' DATE 7/~/~,~'/~// NOTE--_Re~t-- - "" "' "~ °n/th~/~m ~s required-- for each calendar mOnth, regardless of the status of operations, and must be~ile(;~n-- -' duplicate with the Alaska Oil and ,~s Conserv~;i6n Commission by the 15th of the succeeding month, unless otherwise directed. Fnrm ln_/11~/1 UTI I 1~[31 '7r~ Submit in duolicate KUPARUK ENGINEERING Well Name: Transmittal # Date _, _ \/ DISTRIBUTION NSK Operat ion Dr il 1 ing Geology/L. J. R&D D&M State F.G. Baker -___-_ fl_i__f G eology/Ken Blueline Blueline B1/Se Bluel ine Bluel ine Bi/SE ' Blueline -- _ Film the attached /~laska & ?~°~r~mfi~s. ion ARCO ALASKA, INC. ~n~,~'~e ATTN: ?au~ m. ~~ ~ ATO-1115B P.0. Box 100360 Anchorage, AK 99510 OHFinal KUPARUK ENGINE£RING "'~ Type of Tape, Date Tape Number DISTRIBUTION State of ,AK Geoiogy/C · Smith ~ - hed ~/S'ign & return the att~ac_ cop~ as r ipt o ~ ~E OH LIS Return to: Alaska Oil & Gas Qogs. Commission ARCO ALASKA~nc~e.. ATTN: ?~u~a m. ~TI~ ATO-1115B P.0. Box 100360 ~choraEe, AK 99510 Please note: Blueline, Sepia,~ Tape, Photocopy ARCO Alaska, Inc./'-''~' Post Office b~x 100360 AnchOrage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat Wel 1 s 5-16 Dear Elaine' Enclosed is an as-built location plat for you have any questions, please call me at Sincerely, Gruber Associate Engineer JG/tw GRU8/L26 Enclosure - 2G Pad the subject wells. If 263-4944. RECEIVED A!aska Oil ,& Gas Cons. Commission A ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ CON 0 &S~UI T '": .5 ,,,6 .7 DS 2G I HEREBY CERTIFY THAT I AM PEOPERLT REG I STERED AND LICENSED TO PRACTICE LA~D SURVEYING IN THE STATE OF- ALASKA AND THAT THIS PLAT REPREXENTS A SURVEY. MiS.DE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE A 49th 527~- $ 5. Y-~94419.5.05 '1- ~0~929.92 236 FWL 6, Y-5944t$5.21 X- 50892~.90 236 FWL 7. Y,5944075.12 X- 505950.00 2:6 F'WL &, ¥-59440 ! ~,09 X- 50&929.94 Z3~ FWL tAT- 70- LONG= 149-55-40. 607 FSL %,AT- 70-15-~0.911,5 LONg-- I 547 FSL t~T= 70-15-~03204 LON~ 149-55-40.164 487 FSL LAT- 70-15- 29,72~J LONG.. 149-55-40.1S& 427 FSL LOCATKD I# SEll'lOll 5,TII#,ltg£,U.M. 9. Y-594~465.24 I~T- ?0-15-24.$215 X- 50~969.91 ~N~149-55-39.024 273 ~L 123 ~ ~- 5089~,~5 ~0N~!~9-55-39.031 272 ~L 183 ~ I1. Y-5943345.24 ~T- 70-15-23.14~ X- B08969.gZ LON~I49-55-39.028 Z7Z~L Z43 ~: X- 50S9~.~4 ~ON~149-55-39,0~ 272 ~L 30~ ~ ~~ED l~ $ECTIO~ 6,TION,R~E,U.~ tS, Y-J94S2SS.l$ ~T- 70-15-22.5542 X- 50S~09.92 ~N~149-55-49,504 88 ~ 303 ~ 14. Y-~94~MS.15 ~T- 70-15-23.1441 8S ~ 243 ~ I~. Y-~94~405.~ ~T- ~0- Y-~943465.22 ~T- 70-15-24.3252 87~ 123 ~ D.& 2, G CONDUCTORS 5' 16 AS- BUILT M E-MORA, .DUM TO: THRU - FROM: Sta.e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION t~on DATE: June 19, 1984 ~,LENO: D.11.17 Lonnie C. Smith /~ ~''~. ~EpHoN Commissioner ~~~_~ ENO: m~[l ~~]~n SUBJECT: Witness ~O~E Te~ts ua ~etrole~ I~s~ec~= ~CO~ s Kupa~k 2G-6, Sec. 32~ TllN~RgE,.~, Kupa~k River Unit. Monday, June. 11, 1984: I departed my home at 1:50 pm for a 2:20 pm '~h~ an~-3':20~-pm departure via Alaska Airlines, Flt. ~61 for Deadhorse arriving at 5:00 pm. Weather: +46°F, clear, light wind. Plugging for abandonment of Exxon's J-1 began at 10545 pm . . . Tuesday, June 112, 1984: . . .and was completed at 7:10 pm, the ~bjeC:~ a~ sepArate---report~ We~esday, June 13, ~1_98~: BOPE tests on Sohio's U-6 were complet- -ed-,~ the-:-sUbject Of a separate report. BOPE tests on ARCO's Kuparuk 2G-6 were completed. BOPE inspection report is attached. Thursday, J~e 14, 1984: 'Meter proving at ARco's Kuparuk CPF-1 was C0M~'le'ted, the"iSubject of a separate report. Friday~ June 15~. 1984: BOPE tests on ARCO' Kuparuk 2H-1 were -~-ompi~i~ed',' the'.":'~j'e~t of a separate report,s I departed Deadhorse via Alaska Airlines, Fit #56 at 5:40 pm arriving in Anchorage .at 7:20 PM and at my home at 7:50 pm. In s~ry, I witnessed successful BOPE tests on ARCO's Kuparuk 2G-6. Attachment 02-001A(Rev. 10/79) O&G -#4... STATE OF ALASKA ALASKA OIL & ~AS OONSERVATION CCMMISSION B .0. P.E. Inspection Report .Inspector ~ ~ ~/~ ~/;$ Date Operator ~ Well __/~O~~ U/< _~_ ~'-~ Location: Sec 3 Pril linq Contractor Representative ~~' ~'j'~-r~ Permit #. ~F--F~ ~~asing set 8. ~/~'~ ft. Representat ire Location, General Well Sign Ceneral Housekeeping____ Reserve pit . BOPE Stack Annular Preventer Pipe Rams .~ Blind Rams. Choke Line Valves__ H.C.R. Valve. Kill L~ne Valves :% Check Valve Test Pressure ~Oo o -- ACCUMULATOR SYSTEM Full Charge Pressure ~ Pressure After Closure Pump incr. clos. pres. 200 psig. Full Charge Pressure Attained: psig psig min~__~.sec. _,~ min~o sec. Controls: Master ~ Remote ,.,9/~_ Blinds switch cover Kelly and Floor Safety Valves · Upper Kelly Lower Kelly. Ball Type. , . Inside BOP Choke Manifold No. valves,, /~ No. flanges ~0 ~justable Chokes / Hydrauically operated chcke Test Pressure Test Pres sure Test Pressure Test Pres sure... ~ Test Pressure Test Results: Failures ~ Test Tim~' Repair or Replacement of failed equipment to be made within_ Inspector/ccmmission office notified. days and Distribution orig. - AO&OCC cc - OPerator cc - Supervisor Inspector~ ARCO Alaska, I~''''''''~* Post Office aox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 7, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built LocatiOn Plat - 2G-Pad Wel 1 s 5-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG7/L85-tw Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~._ 5 .? DS 2G $! $2 TI 1If 6 5 TIO~ I HEREBY CERTIFY THAT I AM PROPERLY REGI STERED AY{D LICENSED TO PI~ACTICE LAI{D SURVEYING IN THE STATE OF ALASKA At{D THAT THIS PLAT REPRESENTS A SURVEY. MADE UHDER MY DIRECT SUPERVISION AlJD THAT ALL DETAILS ARE CORF. ECT AS OF- 5-~,~>-~- OF A. DAVID Fi[ 5Z76- S $1 sZ :53 T~'N~G CONDUCTOE AS 13UILT LOCATIONS LOCATED IN SECTION 32.TI IN.RgE. U.M. 5. Y-5944195.05 X- 508929.92 236 FWL 6. Y-5944135.21 X- :50~929.90 236 FWL 7. Y-5944075.12 X- 505930.00 236 FWL 8. Y-5944015.09 X- 508929.94 23:5 FWL LAT- 70-15-31.5000 LONG- 149-55-40.162 6O7 FSL LAT- 70-15-30.9115 LONG- 149-:55- 40.165 547 FSL LAT- 70-15-30.:3204 LO,%'G- 149-55-40.164 487 FSL LiT- 70-15-29.7299 LONG- i 49- 55-40. ! 6,8 427 FSL LOCATED IN SECTIOI~ 5,TI ON,RgE,U.M. 9. Y-5943465.24 LAT- 90-15-24.3215 X- 508969.91 LONG-149-55-39.024 273 FWL 123 FNL I0. Y-5943405.10 LAT- 70-15-23.7297 X- 50;3969.75 LONC-149-55-:39.1~31 272 FWL ~1. Y=5943345.24 X* 50S969.92 272 FWL 12. Y-5943255.17 X- 506969.84 272 F~L 183 FNL LAT- '/0-15-23.1409 LONG- 149-55- :39.028 243 FNL LAT- 70-15-22.5500 LO:,~G- 149-55- 39.032 ~0: FNL LOCA'IED IN StSCTIOI4 6,TION,RgE,U.M- 13. Y-5943255.1S tAT- 70=15-22.5542 X- 50S60~.92 LONG-149-55-49.504 88 ~ 303 ~ 14. Y-59433~5.15 LAT- 70-15-23.1441 X-50~609.90 LON~I49-55-49.502 88 ~ 243 ~ 15. Y-5943405.25 LiT- 70-15-23.7353 X- 505609.9~ LONG-149-55-4%4~ 88 ~ 183~ ::~ ~_ ~ , ~/ :_ 16. Y-5943465.22 ~T- 70-15-24.32~2 X- 508~09.93 LON~I49-55-49.497 JUN i <: :~ 87 ~ 123 ~ Illllllll osl t&ll SllflVllll ~' .:s~or~ ARCO Alaska, Inc. Kuparuk Project North Slope Drilling D.S. 2-G CONDUCTORS 5-16 AS - BUILT date' 6.2.84 scale' None drawn by' D Filucci dWg. no.: 9.05~c'07dl ,. June 6, 1984 Mr. J. B. Kewin. Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 ~chorage, Alaska 99510 Re: Kuparuk River Unit 2G-6 ARCO Alaska, Inc. Permit No. 84-82 iur. Loc. 547'FSL, 236'FWL, Sec. 32, TllN, RgE, UM. Btmhole Loc. I154'FNL, 1139'FLrL, Sec. 32, TllN, RgE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud lo§ are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs ~or copying except experimental logs, velocity surveys and dipmeter surveys. Mmny rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the re~ulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacte~ by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to eo.mmencing installation of the blowout prevention Jeffrey Kuparuk River Unit -2- Stme 6, 1984 equipment so chat a representative of the Commission may be present to witness testing of the equipment before the surface castns shoe is drilled~ Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing beffore drilling below the shoe of the conductor pipe. in the event of suspensidn or abandonment., please give this office adequate advance notlficat~on so that we may have a w:Ltness present. Very t~ly you~?, Lonnle C. C~issioner of -I/'! ORD~.R ~ IH~ COMMt~SIO~ Alaska Oil and ~as Conoe~ation Comtssion Enclosure cc: Depar~nt of Fish & Oame, Habitat Section w/o encl. Department of Environmental Conservation w/o enel. ARCO Alaska, Inc. ~ Post Office B,,~. 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 May 29, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2G-6 Dear Mr. Chatterton: Enclosed are: ° An application for Permit to Drill Kuparuk 2G-6, along with a $100 application fee ° Diagrams showing the proposed horizontal and vertical projections of the .wellbore ° A proximity plat ° A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment Since we estimate spudding this well on June 12, 1984, your earliest approval would be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Area Drilling Engineer JBK/JG:tw GRU7/L73 Encl osures RECE VED MAY 1 1984 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldC'ompany STATE OF ALASKA ALASKA O~L AND GAS~CONSERVATION CO,,,MISSlON PERMIT TO DRILL la. Type of work. DR ILL I-~]X REDRILL [] lb. Type of well 20 AAC 25.005 SERVICE [] S~.RATIGRAPH I~ SINGLE ZONE ~ MULTIPLE ZONE DEEPEN [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 EXPLORATORY [] DEVELOPMENT OIL ~X DEVELOPMENT GAS [] 4. Location of well at surface 547' FSL, 236' FWL, Sec. 32, T11N, RgE, UM At top of proposed producing interval 1388' FNL, 1394' FEL, See. 32, TllN, RgE, UM At total depth 1154' FNL, 1139' FEL, See. 32, TllN, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 140', PAD 104' 6. Lease designation and serial no. ADL 25656 ALK 2582 9. Unit or lease name ~ip, Kuparuk River Unit'~._. 10. Well number 2G-6 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Federal Insurance Company #8088-26-27 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or number 13. Distance and- direction from nearest town 14. Distance to nearest property or lease line 30 mi, NW of Deadhorse miles 547 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8464' MD, 6249' TVD feet 2491 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures HOLE ANGLE 47'1° l (see 20 AAC 25'035 (c) (2) Amount $500,000 15. Distance to nearest drilling or completed 2G-Swell 60' ~ surface feet 18. Approximate spud date 06/12/84 psig@ 80OF Surface KICK OFF POINT 500 feet. MAXIMUM ~psig@ 6!!3 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE Hole Casing Weight 24" [ 16" 65.5# 12'1/4"' 9-5/8"i 36.0# 8-1/2" 7" 26.0# 22. Describe proposed program: CASING AND LINER Grade I Couplin! Length H-40 / Wel 80 J-55 HFIERW BT(: 3286 J-55 HF-~ERW BT( 8431 MD TOP TVD 36' I 36' 35' I I 35' I 33' I 33' M D BOTTOM TVD 1161 116' 33211 2750' I 8464'1 6249' I I (include stage data) ± 200 cf 985 sx Permafrost E & 250 sx Permafrost C 305 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8464' MD (6249' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2726 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli'through the permafrost interval. 26-6 will be 60' away from 26-5 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. The well will be completed by the (see attached sheet) -23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space below f~/fCom~i~ion uy TITLE Area Dri 1 1 ing Engineer DATE CONDITIONS OF APPROVAL Samples required F-lYES [~0 Permit number APPROVED BY Mud log required Approval date [~]YES ~0 Directional Survey required I APl number ~kYES r-]NO [ 50- (3 l.. t' SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE .Tune 6, 198/+ by order of the Commission Form 10-401 GRU7/PD12 Submit in triplicate Permit Dri 11 2G-6 the workover rig using 3-1/2", 9.2#/ft, J-55, BTC tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. RECEIVED MAY ~ 1 1984 Alaska Oil & Gas Cons. Commission Anchorage ~ II ANNUl. AR PIPE BLIND , 5 ED 2 DIAGRAM ~1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head ll" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer s~ool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - SO00 psi drilling spool w/choke and kill .lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams g. i3-5/8" °.5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. I3-$/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEN~. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND V~LL¥]~S UPS~ 01~ C~r~O~S. DON~T TEST AGAINST CLOSED CHOKES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 8. ~~'P~SSUR~ ~O~NST~ OF C~O~ ZSO~ATTON VAL.V~S~ TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. g. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF P I PE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE P~AMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16 PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- R E C E IV E D MAY 11984 Alaska Oil & Gas Cons. Commission Anchorage 7 Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool w/10" side outlets. 5. 10" ball valves~ hydraulically actuated~ w/lO" lines to reserve pit. Valves to open automatically upon closure of annul ar preventer. 6. 20" 2000 psi-annular preventer. 7. 20" bell nipple. -- II Maintenance & Operation 1. Upon initial installation close annular preventer and verify Ehat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessar¥~ manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor RECEIVED UA¥ 1 ]984 Alaska Oil & Gas Cons. Commission Anchorage CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc (2 thru 8) (3) Admin<~hr~ 11> (4) Cass (12 thru 20) (21 thru 24) (6) Add: YES NO 1. Is the permit fee attached .......................................... 2. Is well to be.located in a defined pool ............................. 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 well bore plat included ...... 7. Is operator the only affected party ............................ 8. Can permit be approved before ten-day wait ......................... 9. Does operator have a bond in force .................................. ~l- 10. Is a conservation order needed ...................................... ~ ~-~.- 11. Is administrative apprOval needed ................................. .. ~ 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. REMARKS Is conductor string provided ........................................ 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 surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............... Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... //z~ Are necessary diagrams of diverter and BOP equipment attached ....... ~y~ Does BOPE have sufficient pressure rating - Test to.~ psig ..~'~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. //~ Additional Remarks: ~z Geology:,_~.Engin~ring: WVA~ J~HJH rev: 12/08/83 6.CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. .. No special 'effort has been made to chronologically organize this category of information. :Lb = ~MLD - l~PARUK I' .:6 GtC3 42 35 i 0 : 0 c. IC3 44: 0 0 : 0 4:2: 0 J, 6. ~U 4~ 0 1 68 U 4 0 1 68. CPS 42 34 92 0 0 4 0 1 68 CPS 42 34 93 0 0 4 0 I 68 ~ D ~LI tA'I' :PT ) ~L,I : NL ~LI 8508 -12 -999 2 2554 999, ?. 554, 8400. -16. 9. .0(~00 .0859 2500 '9805 · .6000 oo00 6172 2500 SFLO 2,675~ ILD 1,5322 ILM 2 ~137 GR 131,o000 GR -999.2500 GR -999:500 CALl -999,25OO RHOb 2,5580 DRHO ~ 1074 PNRA 3.25]9 NPHI -990.2500 NPHI -gg. '2500 FCNb 784.5000 SFLO 2,0675~ I6D 2.5781 I6~ 2 ~137 CR 131.. 0OO GR -qgq,2500 GR -999; 500 CALl -999,2500 RdOg 2,5586 DRHU 0,1074 Rt~RA 3.2539 NPHI -999,~500 NPHi -999.2500 FC~L 784. 5000 SFLU 2,966~ IbD 2 4785 I6~< 2 5840 Ca !07.6875 CR 1.07~6875 GR 107:6875 CALf 9.140b ~HOb 2,4375 DHHO O' 1064 ,AT ; 3 87~1 R{~RA !~!I., 172:9 ~',00:0' F'CNL 7900 3 ;PT 7800. 000o SFLU 2. ' -11,4~53 GR 280, ,LI -099,~5~0 CALl -999. :AT 3.8730 R,~RA 4. ~ML 2050,0000 ~CNb 49 ~ -23 0156 GR ~86, ,LI -q90:PSnO CALl -999. ~A~ 3,2157 R~'~RA :NL 1~09.00~0 FC~L 56R. ]PT 7600.0000 ) 99~25~0 CAI.. I -99g~ ]PT 7500.00¢)0 RFLU 5. ~ -17,4531 G~ 99. ~LI -09g.~bO0 CAI)i -ggg, 4: 4,26 0547 NPH~t : 49. 1699 NB:Bi 49.1699 ~'2 500 500? GR ~45 00~0 GR 145.0000 GR ~:562 CALl :9 ~:']'562 RHOG ~. 3905 DRHO 6565 R~RA 3.93,75 f<;PH I ~5.0(~84 NPHi 0000 FCML 498;'0000 3.0117 :,03:27 45.0684 3828 ILD 2.3262 IbM 50o Gk -999.2500 GR ~500 ~HOB 2.2930 DRHO ~562 ~PHI -999.2500 NPHI 0o0o 2.3965 -999,2500 0.0210 -999,2500 3633 I~D 3.0469 ILM 0000 CR -999 2500 Gk ~500 FH.~S 2:4004 DRHO 359~ NPH] -999.2500 NPHi 3,1699 -999,2500 0.0332 -9~9.2500 08?0 ]I,D 2.9535 Ib~ 875 Ck -999 2500 GR .500 PHOB 2:351~ DRHO 2871 ~:P~I -999.2500 NPHi 500(3 2.8867 .0103 -999.2500. 5i~7 TI,D 4.35i, 6 6875 Ok -999,2500 GR 2500 ~HO~ 2.~570 D~NO 4.3672 -999.2500 0,0000 130 . 2:. t44 I' 7 O00 ) ~0 ~L I - 999 ~AT ~ :NL 270 'PT 6900.0000 SFI.U ) -30.4~44 GI~ ~LI -c)99 7,500 CALl tAT 3i0137 RNRA ~ ~ i., 2656 0000 FCNL 'PT 6800 ~ -37 ~LI -999 ~AT 3 ;NL 2228 . o00o SFI,U . '2500 CALl 390b R~'~RA 'nO00. FC'N b 232.:4 ~ P H I 000:0 6600 -20 3750 GR -99~ 2500 GR ~500 :~'~0~ ~i.~i,~45:3 DR~O 5059 NPHI =999,2500 NeVI 0000 4, I6:80 ~9,250O -999.2500 3.1758 ~bn 3:.1797 98,5~25 GR -q9~ 2500 -999~2500 RHOB "~i~3457 DRHO 3,2070 NPHI -999,2500 828,0000 3.2441 -999.2500 0,0132 -999,2500 ,0000 SFbU .71~ GR ,~500 CALl 3,7179 -999,2500 0,04~8 -999,2500 3,3047 )LD 3.3008 Ib~ 137,6250 GR -999,2500 Ga -999.25o0 RHflB ~.4277 DRHO 4,0000 ~PHI -999,2500 NPH~ 4.96.7500 3,3262 -999,2500 O.050B -999.2500 '999~"2500 PH05 2~ 3105 DR)40 2,3320 -999,2500 o,0117 ;PT :PT .AT 'N , ,L :PT :AT :N L ! ~ A']L' :PT 6100 o000 SFI,U 6000. 0000 SFLU 3 ;27 734~i GR .118 -_ 99:2500 CA[,I 99H 63 :'2695 RNRA ~ 245 0000 FCNL 72 5qO0.OOOO SFLU t -21.50flu GR 118 -999.2500 CALl -999 3.7715 RNRA 4 2166.n000 FCNL 541 5~00.0000 SFI.,U 2 -25,6875 GR 139 -999.~500 CALl -ggq 3,2559 R~RA 3 2144.0000 FCNL 560 5700.n00~3 SFI.,U 2 -23.484.t GA 104 =999,7500 CALl -ggg ,3750 GR -999,2500 Gf ,4863 t~P :ii -999.2500 NPHI ;5000 ,8672 TLD 3.8418 ,4375 GR -99~ 2500 ,9500 RHOB ~ :3359 DRHO ,3770 NPH. 1 -999.2500 NPHI ,0000 .95aI TGD ~.6406 8125 GH -999,2~00 GR :2500 .HOB 2.33nl DRHO .0000 NPHi -999.250u NPHi .5000 .2422 TLD 2.5293 Ib~ ,OUO0 GR -999,2500 GR .2500 RHOB 2.3633 DRHU ,8242 NPHI -999.2500 NPHI .5000 ,2183 TLD ~.6934 IL~ 375 GR -999.250~ GR 509 RH~B ~.2871 DRHO 2 9-199 .0161 -999,2500 3,9355 -999,2500 0.0386 -999,2500 2,515~ 999,2500 0,0796 999,2500 2.4824 -999,2500 0,0376 -999,2b00 2.6543 -999 250o 0:0547 PT 5300 L-i ' A' ~b 2:226 P' 5.~00 · '~ L! ' 099 AT 3 NL 240~ 2181 GR .,1~ ~:~ ,..000 O G.R -.:99~ ,25:00 GR 9 2500 ~:::C'~'L~I .. ~304:7:<~'~:DRHO 2~69 R~R A 7500 NPHI '999.~2500 N~HI 00:00 :~CN:B 5:9 ]';~ 50 O0 -.999 0000 '8FLU 2:. 7. 344 .G .190.9, 2500 CaLI 4531 RNRA 3, DO00 FCNL 672 ;: PT 5100.00OOSFLU 2. ~25.2187 GR .106, bi -..99.25OO CAI, I 999. AT 3 1816 R~RA 3, NL 2268:00o0 FCN~ 653. .0000 SFLU 3, .0000 GR 103, .2500 CALl -999, .2i09 RNRA 3, .0000 ~CNL 721. .OOOO SFLO 2. 9 6 8 '7 G ii 99 : 5oo can 21 RNRA 3. :~00. FCNL 589. :PT 5000 -31 LI -099 AT 3 NL 2392 'PT 4000 LI ~26 - 9g AT 3 'NL 2306 ;P~' 4800.o000 SFI,U 2. ' -30 2344 gk I09, ,Li -990:2500 CAI,I -990. 50 2.5 0 0 5~20 PHi 999,,2500 NPHI O0 O0 - ' 2,.7246 -9 ,2500 ,:0234 -999,2500 6328ILD 3,0078 Ib~ 12~ G -999,2500 G~ 2500 ~HOB 2'3125 DRHO 4'12'1 NPHI -999,2500 NPH! o0oo 2.9434 999,2500 0~0273 999.2500 3438 TLD 3'.3086 6875 GR -99~ 2500 GR 2500 ~HOB ~3281 DRHO 3164 NFttl -999,2500 NPHI 0000 3.4883 :99~,2500 ,0469 999.2500 5078 IGD 2.8535 IbM 6250 GR -99~ 2500 GR 2500 RHOB ~!:2676 DRNO 14l NPHI -999.2500 NPHI 000 2.7695 -999,2500 0.0166 -999.2500 6250 IbD 3.0234 Ib~ 2500 GR -999 2500 GR 2500 RHOB 2:2988 DRHO 2.9297 -999 2500 0~0459 'i L I 4:400.00...0 $~L:U 3 " 50~ Ga 114 -29,7' c .... ":'99:g;~:500 ..... 3,,3340 ,R~a 5837 2062,0000 FCN:L 32'81 Ib::'D 3 .:8i 25:: :::lb~ 3,6973 ~:3.7:5 -99 ,250.0 Ga -99 ,2500 ;~:~50:'O"::'::~':~OS ;:~2051 .... 'DR HO . 0063 5t17 NPttI 999.2500 NPHI -999,2500 0000 :PT ,L1 :AT ~NL 4300. 0000 $FLU 2 · ,25, t.i~a Gti 99 '999:, 2500 CALl -999 3,5~8.4 RNRA .4 2 134.0000 ~CNL 491 .8945:' ILO ~26o0: :~HO~ ~PtI ,5000 3,:2969 Ib~ '999.2500 GR 2-3145DRMO -999.2500 NPHI 3 0'-586. -999 2500 :PT :AT ~Nb 4700.0000 SFLU 3 -25,5O00 G~ 9~ 9.5791 CALI 9 3 4570 RNRA 3 2194:o000 WCNL 570 .9375 lbo ,3750 GR ,5781 RHO~ .8477 NPHI .0000 4.0508 Ib~ 94,3750 GR 2.1719 DRHO 40.7715 NPHi 3.9453 94 o:o 75° 059 40,7715 :PT ~I,I 4100.0000 SFLU g -25.234a GR 74 9,14~a CALI 9 2.~711 RNRA 3 2134.00n0 FCNb 660 .0000 ILO ,0525 GR .1484 RHOB ,2324 NPHI .00oo 13.28!3 IL,~ 74,0625 GR ~.3242 DRHO 31.1523 NPHI 13.4531 74,~625 O, 928 31.1523 3PT ~I,I 4000.0U00 SFLU 2 -22.734q GH 107 11.1875 CALl 11 3.3945 Ri'~RA 3 2132.000~ FCNL 557 .718~ ,0000 Gk .1875 RHCIB 3.4707 TL~ 107.0000 GR 2.3379 DRHO 37.7t41 NPH! 3.2598- 107,0000 0,0479 37.744i 3~00.0000 SFLU -27.9687 GR -099.2500 CALl 4.7109 121.502b -99o.2500 5,8047 IL~ -999.2500 GR 2.~305 DRMO 5.2227 -999.2500 0,0259 ]PT 3PT ) 3400 -35 -999 3 2000 330n -36 -q99 3 1034 3200 -27 -g99 3 1902 3100 -28 -999 4 139~ 3086 -27 -q9g 0000 SFt, U 4'691 ~ I bD 5:,7.7:3.4:-' :~L~i 5,2656 9375 GR: 72,50:00 G,R -99~,~25Q0 GE -999,2500 9500.~ CAUl :' '99'9.~500 RH'OB ~:~.~895 DRHO . 020024 ,8~09 R,~RA ~,2383 5IPHI -999.2500 NPHI 999,2500 O00O FCNL 47 ~'5000 ' . O00C, SF!,U '2500 CAI, I , 2 070 R N R A .0000 WCN[, OOnO SFLO 2500 .6055 RNRA .0000 FCNL .0000 SFI, U .953i .267 ~ ,OOnO FCNb .5000 SFLU ,qbJl . ~500 CAI, I 9.0000 ILO 9.9062 Ih~ 9,2891 90,8750 G~ -999,2500 GR -999'2500 -999.~500 RHOb 2~-1836 DR~O 0,0215 3 4707 NPHI -999.2500 NPHi -999°2500 557~0000 3 2773 ILD 4,2539 Ib~ 3.7617 76i4375 GR -999,2500 GR -9990:2500 -g9q 2500 RHOB 2, l 934 DRHD 0088 533,54496,5000 N. PHI -999.250u NPtil -999.2500 4.5000 ILD 9.8281 Ib~ 2000,0000 53,4688 GR -999.2500 GR -999,2500 -q99.2500 RHO~ 2.0742 DR~O -0.3760 4 8242 NPHi -999~2500 NPHI -999.2500 ~89~7500 3.8223 ILD 9.3984 IL, 2(100.0000 ~*2 6563 GR -999.2500 GR -999 2506 -090:9.500 RHOB 2.0547 DRHO -0:4419 ~ECORD TYPE 137 EOF P OlO,H02 V~RI~ICA~IO:~ LISTING AGE ~ tMMENT$ :LIBRARY TAPE :EDIT TE :84/06/23 IGIN :0000 ,PE NAME ~:9302 ~NTINUATION # ~EVI ]US ~ · T APE ~ i ~M~ENTS :LIBRARY TAPE ** RECORD TYPE I37 ,00I ~TE : ~XIMUM LENGTH : 1024 ~LE T¥'PE [EVIOU$ FILE : INFOR~ATION RECORDS )EM CONTENTM ARCO ALASKA INC 2G-6 KUPARLIK ~IVER 9E 32 N,SLOPE ALASKA USA COMMENTS 000 O00 000 00 o 000 000 000 000 000 CATE 000 000 000 000 000 000 000 00o 000 0lb 004 013 002 004 002 008 OOb 004 COD~ 065 065 065 065 0~5 065 065 06,5 Ot~5 = 2G'6 NORT'H SLOP~ =:ALA~'KA N PC HALSTEAD 1984 SING = 9~625" 8:313:3: : PE FLUID = X:C POL~ .ac3 ~TRIX SANDSTONE BIT R~ AT' BHT P Ol.O,b02 V~<IFICATit)f~ LA,STInG SCHLU~BE[((;ER bOGS I[i'CLUDED ~IT[I T~I~ MAGNETIC TAPE: [)UAL INDUCTIO~ SPHE~ICAI,,LY FCCUSED bOG rD,IL.) CO~PE~AIED NEUTRON bOG (BEN) DATA FORMAT RECORD TRY T~PE SIZE 4 1, 66 0 t 6b 0 TUM ~PECIflCATION MUOUK& E~ 6EPVICE SERVICE U~{IT API A[~I AP1 API FILE SIZE PRUCES8 SAMPLE REPR ID [~DEH ~ LO~, IYPE CLASS MOD NO PT FT 0 0 0 0 0 4 LU DIb O~M~ 7 0 0 0 0 ~ D Dib DH~ 7 !2 46 0 0 ~ M DIb OHNM 7 0 0 0 0 4 DIL MV 7 1 0 0 0 4 DIL GAP1 7 31 32 0 0 4 FDN GAPI 42 31 ~2 0 0 4 FD~ GAPI 42 3i 32 0 0 4 LI FD~ IN 42 28 3 0 0 4 L1 FDN I~ 42 28 $ 0 0 4 Ob FD~ G/C3 42 35 I 0 0 4 HO F!.)N GtC3 42 44 0 0 0 4 ! I 68 0 ! 6B 0 I 68 0 ! 6B 0 ! 68 0 I bB 0 I 65 0 i 68 0 1 6B P 010.~02 YERIFICAltO~ LIS:IIN~ PAGE4 · 'HI FDN 'HI FDN PU CPS 4..2 42 I 0 0 4 4:2 0 0 0 0 4 42 68 2 0 0 4 2 '34 9 1 68 DATA ~LI :AT 8508.0000 &FLU 12, '999,2500 CALl 2 98~5 RNRA 2554,0000 FCNL 2,6758 ILD 13:1,0000 -99 '999.250Q RHOB 78 .2539 NPMI '99 .5000 ;PT BSO0.OOOO SFLU -999"~500 (]ALI 2554,0..00 PCNL 2 ,, 6758 ;5000 2.5781 Ib~4 2,5137 ,,gg:~,: ~:500 : -99~, 25.00 55:8. '6 DR H/3 O i 074 ,,' 2' :PT :AT ~400 lB61 AL l 0699 RNNA 0000 2,9668 ILD 10~,bBTb ~ 1406 RHOB 430'0000 2,4'7~5 iba 2,5840 2;4375 ~RHO ~ ~'I064 . ~ ..,. :PT ~L I 4.4414 ILD 9~,2500 GR ,8828 RHOB 70~2383 NPHI ;oo0o 3,50'59 lbI~ 9 :2soo 416 0 DRHO 34,277,3 NPHI :PT ! 8200.0000 SFL(~ -45.25U0 GR 8.b875 CALl 2730.0000 FCNL 8.0313 ILD 87.8125 GR 8.6875 ~HOB 3,0684 NPH1 889.5000 7.6406 IbM 87,~125 GR 2.4277 DRHD 30.2246 NPHI /.4922 '?,~125 ~0,0073 30,2246 :PT ~100.0000 ~15'~009 GR 8'9609 CALl 2.8223 NNHA 30'12,0000 FCNL 7.1797 1LD 73,9375 GR 8.9609 RHOB 3.0293 NPHI 1013,5000 6.9297 73,9375 2.4219 DRHO 30.b641 NPHi 7,0430 7~,9~75 0.0142 3V,bb41 :PT ~LI :AT 8000.0000 SFLU '29.0009 G~ 9.0313 CAbI 1729,O000 FCNL 4,6445 270.7500 GR 9,0313 RHUB 4.0547 NPH! 42§.2500 3.4375 ILN 270.7500 GR 2.3301 DRHO 49,1699 NPHI 3,3945 ~70,"7500 O,O171 49,1699 7900. UO00 SFLU -18.~0o0 G~ 3,32~1 iLD 1~5,0000 GR 2,9180 ILM 145.000U GR 3.0117 14~,0000 PT 7,~00,0000 SFI.,U 2 ,,iI;;~45:~ GR 280 LI -999 ~ 2500 CALI -999 Nb 2050 lO000 FCN.h 493 PT 7700,0000 .. .... 23,0166 GR LI 999.2500 (]ALI AT 3,21~7 NL 1909.0000 FCNL 568' PT ~600o000i SFLU ~ 4. LI 999~250 CAbi'~ - AT 3,107~ RNRA NL 2044~0000 FCNL 62i PT 7400.0000 SFL0 3 1,5527 Ge 147 .LI '999.2500 CALl -999 :AT 3,23Ub RNRA '3 · . ~'N 60 'NL 2282 0000 ~C L ;PT 7300 0000 S~LL 3 ~LI -999.2500 CALk -999 :AT 3,2"154 RN~A INL 2144,o0u0 FCNL 58 3 ;PT 7200,0000 SFLU 12 ' '2~,0000 GR 79 ~LI -999.2500 CALI -999 :AT 1,9209 ~NRA 2 INb 3252.0000 FCNL 1603 ;PT 7100.0000 SFL~i 4 ~ -40,500~ Gbt 124 ~bI -999.2500 CAbI -999 ~AT 3,1 ! 13 ~NRA 3 ,. b 2.t22. OOO~ FCNb 749 2PT 7000,0000 SFbU } -40,0000 GR ,,562 R}OB 2,3906 'DRHO ,9375 NPMI 45,0684 NP~I .0000 - 0,0327 4~ ,06~4 ,3B2S ILO 2'~262 ibm 2,3965 ~/,:bO0 GR .250~ t~HOB 2;:'2930DRHO 0;0210 1562 NPHI -999~2500 0000 3633 lbo . 3,0469 3594 NPHI: 999,2500 ooo0 3. 1699 · ~0,25:0:0 -99 :, 0332 0820 IRD 2,8535 Ibm :2500 PMI 2,8867 -~:9~, 25-00 '0,0:103 ~B::75 2578 NPHI 0000 .2949 IbP ,3750 6R .2500 RHOB ,7617 NPH1 ,5000 .8047 IIoD :~O00 GR 500 RHOB ,6738 NPHI .5000 .4844 ILD ,0000 GR ,2500 RHOB .0273 NPH! .0000 .u078 IbD 18'15 GR ' 2500 RHOB .232~i NPHI .0000 5,2344 IbD 91,3750 GR 4.3516 IbM '999,2500 NPMI 3,2031 IbM ,2bO0 GR '99~,~336 ORHO -999.2500 NPM1 4.0B98 -999 2500 2:4492 -999.2500 5,6328 IbM -999.2500 6R 2,5684 DRHO -999,2500 NPHI 3,8770 IbM -999 2500 GR 2:45~2 OReO -999,2500 3,849~ IbM -999.2500 GR 3 672 ,2500 2500 . 3,0977 ~99~,~500 .0352 -999,2500 ~.0898 -99~,2500 - 0,0464 -99~,2500 b,3633 '999,2500 0,0332 -99~,2500 ~,9121 '99~,~500 " 0,0342 "999,2500 4.1680 -99~.2500 bi -999.2500 CAbI AT : 2,~70'1 ~N~A NE 2708.0()00 ~ CNL "999.25C0 RHO~ 2 i080~ 50.59 ~PHI .o0o0 2,4453 DR'HO 0,0459 -~99,2~00: NP~i : ,99~,~500 3 -999 I758 IbO 3,i797 IbM 3,2441 2070 NPHI ...999,2500 NPHI -99~,2500 0000 - ~ PT 6800.0000 MFI..,U bi -999.2b00 CALf AT ~,JgOb NL 2228,0000 FC'NL 3 - 9 9 ~ 7656ILD 3,67'19 ILM 2500RHOB 2,&395 DRHO 52~.~ NPHI: '-999,250.0 N~HI 0000 -9,2500 PT 6700 LI -999 AT Nb 0 0 8FLu 3.3047 iLD '999;'2500 R~O:~ 496,7500 PT 6600.0000 3FI.,U -20,71~ Ga bi '999,2500 CAb! · . ~ NL 1955' ,0000 FCNL 2 1.72 -999 7402 2500 i,~PHl 2,2090 IbM '999,.2500 ~R'. 2';'3105 OReO -999;2500 NPHI 2,3320 -~9~, 2500 · : ,0117 :PT 6500,0000 SFLO bi -999.2500 CALI AT 3,7891 RNRA 'NL 2150.0000 1 13~ -999 .5596 iLO ,1250 GR ,2500 R'HOB ,3984 NPHI .750o 2.1836 "99 ,250 ,3262 '999.2500 NPHI 2,1270 -99~'2500 ~ 0'0137 -999,2500 'PT 6400.0000 8FbU ;18,1'/1~ .LI - 99,2500 .AT iNL 2096.0000 FCNL 1.3262 I. LD 111,7500 GH -999.2500 RHOB 3.b137 NPHI 596,5000 1.4902 IbM '999,2500 GR 2.3047 ORHO -999.2500 NPHI 1,4922 " 0215 -999,2500 :PT 6300.0000 ! -. 99.2500 CALl :AT 3.099~ IHL 2682.0000 FCNL 3.3691 lbo 81,b250 GR -999.2500 3,2500 NPH! 825.00O0 3.3672 Ib~ '999,2500 GR 2.2402 ORHO -999.2500 NPHI 3,3398 O, -999,2500 6200,0000 '3!,2500 G~ '999,2500 CALl 2,9512 RNRA 2868,0000 4,b367 ILD 88,4375 OR '999.2500 ~HUB 2,8867 NPHI 993.50Q0 4,1016 IbM '999,2500 GR 2,3281 ORHO '999.2500 NPHI ~.1836 -99W,2500 0.0225 '999,2500 :PT 6100.0000 SFLU -22,40~8 GE 2,3770 ILD 93,3750 GR 3.0313 ib~ -999.2500 GR 2,9199 -~9~,2500 , -999. 2500 CALI 250o, 0000 VCNL 5700,0000 5FLU 3 2221 2194 0000 FCNL 5600.0000 SFbU -999'2500 CALl ~,~09~ RNHA 200~.00~0 FCNi, 5500.0000 SFLU -24,93'15 G~ -999.25o0 CALX 3,2569 RNRA 2274.QOUO FCNL 5400.0000 SFLU -2b 00o0 GH '999~2500 C~LI ~,5215 RNRA 2200,0000 FCND 5300.0000 MFLLi '10,218'7 G~ '999.2bU~ CALl 3.29~9 RN~A 2226,00U0 FCNL 5200,0000 SFbU -2b,1344 G~ 3.8672 IbD 3,8418 ' ILS '~ " ~'z ~ 9 1:18,.4315 99· 999;2500 RHO5 ~2; - . .... 3359 ORHO ~,3'170 NPHI -999,:2500 NPMI : -999 727;0000 - 9355 25OO 038'6 ,~500 .25:00 RHOB ",330i VRHO ' ,0796 t,O000 NPHi -999~:2500 NP~:I ..999~2500 5411.5000 ~ ' ~ 2 2422 I~D NPHI .4824 ,2:500 · 0376 2,2:383ILO 2 104,~375 (;:R 2500: GR -99g,2500 '999. 2500 Ri'IDB 287! 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VERIFICATIOns. ~iSTIN~ ~AG~ 8.. b! -999.2500 CALl T 3,4531 ~A L 240B. 9000 FCNI, 0 00 0 S Y L U PT 5100,, B" ' 425,21 / GR hi -999.2500 CALl L 2268.0000 FCNL PT 5000.0000 SFLU -~1,0000 GR LI -g99.2500 GAL£ AT 3,2109 RNHA NL 2392;0000 FCNL PT 4900.0000 SFLO 2500 C AL I hIAT 999'412~$, RNRA NL 306,0000 FCNL BI '999.2500 CALl AT 3,~2~ RN~A NL 21~2.0000 FCNL PT ~'?00,0000 SFLU ~28,~0'~1 aR Nh 228 ' OU6 . 0oo FChL PT 4600.9000 SFbU -32,21B7 GA bi -999.2500 CALl AT 3.22~5 R~HA NL 2290,0000 FCNL .PT 4500.0000 SFLU -29.0000 GR hi -999.2500 CALi AT 3.~492 RNRA 'Nh 2344.0000 FCNL PT 4~00.0000 SFLO ' '29,7500 GR bi '999.2500 CALl ~NL 2062.0000 FCNb iPT 4300.0000 SFLU ' '25,71~8 GH -999,2500 RHOB 2'3164 ~'DRHO 0,0234 3,5820 NFHI 999-2500 NP~I -99~,~500 672~0000 ~:- 2.0328 ILD 3.p, 078 lI~ 2,~434 10'6, ~:125 GR -999,2500 ~G:R::: -99~ ~2500 -999,2500 RHOB ' 2,3125 DR~O ~'~ 0;0273 6y3'472753 NPH1999'2500 NPHI . 999,25'00 ,0000 -= 3.343E ILD 3.3086 ,2500 li03,6875 GR: : -99~ -999,2500 RHOB ;~28-i: DRHO '~ ,0469 NPHI -999;2500 NPMI 72i;0000 2 99 -ggg 5078 ILD 2,~535 1L~ 2 :2:50: GR -99 ~5'i00 2500 RHOB ;26:76: DRHO - 9.141 NPHI -.999~2500 NPMI -999 0000 ..... .7695 O0 6250 laD 3.0234 lhM 2 2500 -999'2500 :GR -99~ 2500 RHOB 2;29'88 DRHO 0 7422 NPHI ~999,2500NPMI -999 0000 .... .9297 ,2500 ,0459 ,2500 999; 620' 3223 ILD 8262 Ih~ 3 2500 RHOB 2I 3 DRHO - 6738 NPHI 2500 NPHI -999 5000 .5156 ,2500 ,0200 ,2500 3.6582 ILD 4.0273 Ih~ ' 9 25OO GR i07,b625 GR '992,2695 DRHO -999.2500 RHOB ' '. 3,b138 NPHI -999,2500 NPHI 623.0000 ~.7754 -99~,~500 -999.2500 2,4863 lbo 3.2715 IbM 103,0625 Ga -999,2500 GR -999.2500 RHUB 2,2637 DRHO 3.91§0 NPHI -999,2500 NPH1 598'5000 ~.1465 -999,2500 0,0195 -~99,2500 3.3281 ILO 3.8125 ~14,4375 GR '999,2500 -999.2500 RMOB 2,205! DRHO 3,5117 aPHI -999.2500 NPHI 587,0000 3.~973 -99~,2500 ~-0,0063 -99~,2500 2,~945 ILO 3.2969 Ib~ 99,5000 GR -999,2b00 GR ~,0586 '999.2500 AT ~NL ;PT [AT ;PT ;Nb ~AT '.NL ~AT :NL ~AT :N L ~PT ~L~ - 999.25 O 0 C A b ,[ 21:3 ,bbB4 ..... 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NPHi ,, 5,8047 IbM ,2500 ~R 99~.2305 ORHO '999~2500 NPHI 5,5391 IbM ',,999.22~00 ' 2; 27 ORHO -999,2500 3.8281 '999,2.00 GR 2,1895 DRHO -999.2500 7,0273 Ib~ -999,2500 GR 2,2148 DRHO -999,2500 NPMJ 7.0547 -999.2500 GR 2,1738 OReO *999,2500 NPHI 5.773t '999.2500 GR -0,0073 -~99,2500 3,9453 9~,3750 ,0059 7~, 62:5 ,0928 25'98 'O000 ''0479 5,2227 "99~, 2500 ,0259 . g ,2soo b,3828 ,0249 ,,,99'.3,2500 3,5996 -999,2500 O,O000 -999,2500 b,7734 '999,2500 · 0,0122 "99~,2500 b,8398 '999,2500 'O,OOb8 '999,2500 b,2656 -999,2500 P 010,M02 VERI~ICA~IOi~ LISTING PAGE. 10 LI '-999,2500 CALl 20o0,00o0 -999,~500 RHOB 2,1895 ORHO 474~2:383i N:PHi-999, ,5000 '24 PT bi AT NL 3300 DO00 SFbU - 99 9. O0 O0 i LD 9,90'6'2 I b~ 9,2'891 90, B~ 50 6R:: -99 ~, 250.0 :~a ,'~:9~, 2500 ~ooo0 ........ - ~ PT AT Nb 3200 O00u SFLO 2500 CAbI 1902 3. 2773 ILD ~. 2539 IbM -999'2500 RHOB ORHO : ::3~ 5449 NPMI :-9:99,:,2500 NPBI 536,5000 ~,7617 PT LI AT NL PT LI AT NL 31~0,0000 SFLO -"28,95~1 999.2:500 CAbI 1398,0000 .~CNL 30~,5000 SFLU -999,2500 CALl 1597,0000 FCNL 3 -.999 5000 'IhD 9,8281IL~ 200'0,~00:0 2~00 RHOB : 2;07'4:2 ORHO ,':~0;37'60 2500 , 2500 RHOB 2'0547 DRHO .'~0,4'419- 92,19 NPMI NPHI ,,9:99,2500 2'500 FIhE TRAI~ER LE NAME :EDIT .001 RVICE NAME R$ION $ : TE : XIMi]~ LENGTH : 1024 bE TYPE XT FILE NA~E] : ** RECORD TYPE 137 ~APE TRAIb~R ** :RVICE NAME :~DIT T~ :84/06/23 IGtN ;0000 ,PE NAME :9302 ~NTImUATION # iXT TAPE NAME : ~MME~TS :LIBRARY TAPE ' REEb TRAILER ;RVICE NAME :~DIT :84/06/23 ~L . 27. -0.0133 - J 7:~ . _: -3.:' J. 30 ~9 ;,'.~.771': 0.3£L5 -.3.57 50 )
