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Home My WebLink About198-108 RECEIVED • • STATE OF ALASKA 0 MAR 3 0 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AC la.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned E Suspended❑ 1 b.Well Class: 20PAC 25.105 20PAC 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. . Aband.: 3/6/2016 198-108/315-594 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 6/22/1998 50-029-22889-00 , 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 301'FNL, 599'FEL, Sec.23,T11N, R10E, UM 6/26/1998 KRU 1D-126 Top of Productive Interval: 9. Ref Elevations: KB: 70' 17. Field/Pool(s): 2351'FNL,707'FWL,Sec. 23,T11N, R10E, UM GL: 40' BF: Kuparuk River Field/West Sak Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2438'FNL, 519'FWL, Sec.23,T11N, R10E, UM at Surface ADL 25650 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 560491 y- 5959364 Zone- 4 6716'MD/4130'TVD 468 TPI: x- 556535 y- 5957283 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 556348 y- 5957195 Zone- 4 None 2468'MD-1617'TVD 5. Directional or Inclination Survey: Yes ❑(attached) No ❑✓ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft-MSL) -- N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray,caliper, resistivity, porosity, magnetic resonance, dipmeter,formation tester,temperature,cement evaluation, casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary N/A MAY 0 9 'Low sONSED 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surface 121' Surface 121' 24" 260 sx AS II 7.625" 29.7# L-80 Surface 6691' Surface 4106' 9.875 190 sx ASlll LW;330 sx Class G & 475 sx ASI II LW;60 sx AS I 24.Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5"+ESP 5129'-6009' none Perforations plugged 3.5" 2410'-surface none .RtA>J____ 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. DAA TE GOtOrl Was hydraulic fracturing used during completion? Yes ElNo El 361 WO Per 20 AAC 25.283(i)(2)attach electronic and printed information VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LU Cement plug-5560'to 6400'MD 48 bbls 14.6ppg RFC Cement retainer @ 5070'MD Plug 4839'-5071'w/11.4 bbls of Class G Neat Cement plug-2660'MD to 4839'MD 100 bbls ArcticSet I in 7-5/8"csg Cement 2660'MD to Surface 136 bbls 15.7ppg ArcticSet 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Plugged Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate .- qC Form 10-407 Revised 11/2015 (�L 573//‘ A /��CONTI/CONTINUED Q`yE 2 RBDMS j.li MAR 3 O 2016 Submit ORIGINIAL onl /^ 28.CORE DATA Conventional Core(s): Yes ❑ No ESidewall Cores�es ❑ No ❑✓ If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. None 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 2468' 1617' 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 at total depth: N/A N/A 31. List of Attachments: Daily Operations Summary, Schematic, P&A photos Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. / Contact: Jill Simek @ 263-4131 Email: Jill.Simek@conocophillips.com 3124I2o1b Printed Name: G.L.Alvord Title: Alaska Drilling Manager lJ Signature: e_L_ Phone: 265-6120 Date: 312-1 ILO i(41 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 la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 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 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection, Gas Injection, Shut-in, or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form:well schematic diagram, summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • SUNDRY NOTICE 10-407 ConocoPhillips Well 1D-126 Plug and Abandonment March 15, 2016 ConocoPhillips Alaska, Inc.performed Plug and Abandonment operations on 1D-126, commencing operations on October 22, 2015 and completing the Plug and Abandonment on March 6, 2016. Operations involved pumping 136 bbls of 15.7 ppg AS 1 cement down the 3.5" killstring and up the 3.5"x 7-5/8" annulus. Top of cement in the annulus was measured at 41'3" and 2 bbls of cement were pumped into the annulus to bring cement to surface. The tree and wellhead were removed at 4 ft. below tundra level and the remaining well casings were topped off with 1 gallon of cement. The State Inspector determined that cement was in good condition and the well was capped. Pictures below show cement to surface in all annuli, marker plate installed, and final site condition after backfill. The field Well Service Report is attached. 1D-126 PTD 198-108 �` "Copyright 2016 All rights reserved. This " photograph is provided to the AOGCC with � permission to copy for its own se. Y Copying for any other purpose or by any �� `` . r = .ther party is 15rohibited without thexpre � r,-41-.-*.'" �"*` �•a. " of ConocoPhill ps Alaska, Inc." ' -11 4 ,�y t -,,„,;,..,„.- 4,„ a " .�. rxr �+x6 AR �tEF ,,-,. ';',.....-.1',.-‘4,,-).1.- ..1. R ^ .y.F . Nit ar _it_ ;1 ,,z ? 1!1, „� .'tam6Y -14 �yro � s_ ,, ,, .,. ,^ ler ,„ ... ..,,, , . Vir ^-• v ..., gy'1 ' ;1Y- ,i)/ �jX' yv j ip yl., • • ',!,47:::!'''',:',''„i,,,', 5+ Y.�y, t,,,*,::;',7';: ::;,,.,*'#:',i'''44.544*37;47/4'', ..'4's° �ra? �g'a. �„* k...Q' S-110-.'„7' a`''icy , �4 sitt • !r x,te:,Go o�� 'y ),', ,;' ,t sx , ' :1,-2: -,-•:-0!"..,,,,-,4,::.,..4.,x,gt, s'''. ,,,,,:,,,i;44,;,,,,,,,,,,,f,: ,;:°,.:::,i,i,,„--- --;,,,,,,,..„,i„_„ ' ,''. 4';',,,:t.:; ;,:''Y', ' ' ',:/,:r2f' ' '40014. :'...,, ,. ':--,',!..., 4 lilt.FIC;;, 4r,,,,,,:4, . ' 08 198- • fop r •�h o All rigs resp d poo aper provided to A. Frith ",,, posior� o fear i own use. Copying .4,,,,,,,..,,,,,,,,— Efor ani other purpose or by any other pares fro . iced rioute express �p of ,. t t l i iip� las a, Inc." • • • ti `, ..,p'z " rmi;st a Ea Capt/ C� an"r other t�urtrasa o,t5y ony other'pafitf . t.ratt visuueprxe�sc pf' C rnocot'h€h46ez.at;csz€atkat2fe,tn ". • • 1D-126 WELL WORK SUMMARY TO P&A DATE SUMMARY 10/5/2015 Received approved 10-403 to P&A 315-594. Requires-MITT, Witness Cement to surface,Witness cutoff prior to welding pate,And site clearance approval. 10/22/2015 PERFORMED FULLBORE CEMENT JOB TO SURFACE.PUMPED 136 BBLS OF 15.7 PPG AS1 CEMENT DOWN 3.5"KILL STRING UP IA TAKING RETURNS TO OPEN TOP TANK.SAMPLE TAKEN AT RETURN TANK WAS MEASURED @ 15.6 HEAVY.SURFACE LINES WERE FLUSHED.WOC FOR 48 HOURS PRIOR TO TESTING.***NOTE:RETURNS FROM DRUM APPEARED TO BE DIESEL BUT HAD VERY LIGHT MILKY RETURNS AT THE END OF PUMPING**** ***NOTE:WATER WAS USED TO PUSH CEMENT FROM TREE.TREE IS WATER PACKED&TO REMAIN WRAPPED&HEATED 10/25/2015 Initial T/I=Vac/Vac Check all wellhead valves post fullbore cement job and have vac truck on hand to suck water from wellhead-all valves work. Tubing&left side IA on vac for about 10 sec when opended. Jewelry on all other annulus full of cement. Final T/1=0/0 10/28/2015 Initial T/I=Vac/Vac Stage equipment&RU to MITT,PT Pressure T up to 1600 psi 15 min=1350 psi Repressure T to 1580 psi 15 min=1380 psi MITT failing Bleed to 0 psi(called off for rig job) 10/28/2015 (AC EVAL)MITT-FAILED(DUE TO PRESSURE LOSS)MITIA-FAILED,ESTABLISHED A IA LLR @ 2.47 GPM.ESTABLISHED A RETURNS LLR ON CONDUCTOR @ 3.21 GPM.TOP OF CEMENT IN IA @ 41'3". Initial T/I=SI 40/VAC.no fluid in catch drum. Rigged up to IA and began pumping diesel and IA casing valve flange started to leak.Shut down pump and torqued flange bolts. Continued to pump diesel down IA and noticed fluid in catch drum,shut down and bled IA to 0 psi. Stung into T PO(upper)with 0 psi.and monitored with no increase during LLR tests. Stung into T PO(lower)with 0 psi.and monitored with no increase during LLR tests. Established a IA LLR @ 2.47 GPM @—1500 psi. While pumping down IA,established a returns LLR from conductor to catch drum of 3.21 GPM.@—1500 psi. Allowed IA to naturally bleed to 0 psi.T/I=40/0. Pressurized T with an immeasurable amount of diesel T/1=1520/0. 15 min.reading T/I=1420/0.(-100) Re-pressurized T with an immeasurable amount of diesel.T/1=1550/0. 15 min.reading T/I=1450/0.(-100) Re-pressurized T with an immeasurable amount of diesel.T/1=1510/0. 15 min.reading T/I=1420/0.(-90) 30 min.reading T/I=1360/0.(-60)Bled to 0 psi. Rigged up to IA and purged N2(80 psi.)a few times until only getting N2 returns.2.65 gallons of diesel returns in conductor drum. Allowed IA to bleed to 0 psi.naturally through conductor down spout,all N2.T/I=0/0. 15 min.reading T/I=0/0. 30 min.reading T/I=0/0. Removed bull plug on IA and strapped IA,top of cement 41'3"below bottom of IA valve. Final T/I=51 0/0. 10/29/2015 Vac'd out approx 5-10 gallons of fluid.Cleaned up remaining debris(mud,rocks&dust)in cellar.Normalized grating and covered grating with existing boards to prevent debris/snow from falling into cellar due to no shelter over wellhead. 11/2/2015 Attempted TOC measurement Initial T/1/0=0+/40/0 Bled a small amount of diesel from T into bleed tank.Then attempted to remove tree cap to no avail from ladder.Will have scaffolding built to avoid working from a ladder to remove cap.Will re-attempt TOC measurement at that time. Final T/1/0=0+/40/0 11/4/2015 Initial T/I/0=0+/0/0 T-TOC measurement 14'6"from tree cap Final T/1/0=0+/0/0 • • 1/4/2016 Initial T/I=0/0+ IA bled for 5 seconds to 0 psi Functioned IA valve to ensure it was clear of cement Final T/1=/0/0 1/13/2016 Initial T/I=0/0 Pumped 2 BBLS of 15.3 lb cement into IA.Did not receive returns from downspout.Opened opposing IA valve for returns.Pumped cemen at 100 PSI until clean cement returns were observed.After pumping cement,flushed IA valves with water to prevent cementing off IA valves and returned well to conditions prior to beginning work. Final T/1=0/0 1/14/2016 Initial T/1=0/0(vac truck on location)MITIA FAILED RU N2 and start pressureing up IA Pressure IA to 100 psi 15 min T/I=0/90 Pressure to 200 psi 15 min T/I=0/200 Pressure to 300 psi 15 min T/1=0/300 Pressure to 400 psi 15 min T/I=0/400 Pressure to 500 psi 15 min T/I=0/500 Pressure to 1000 psi 10 min T/1=0/900 and started getting N2 from down spout on conductor Pressure to 1100 psi 15 min T/1=0/850 30 min T/1=0/650 45 min T/1=0/500 60 min T/1=0/480 Continue to rec N2 from conductor during test Bleed to 0 psi and RD N2 Rermove bull plug and strap TOC @ 4"below IA valve,reinstall plug Final T/1=0/0 1/15/2016 Initial T/I=0/0+MITIA FAILED RU N2 and pressure up IA to 500 psi 40 min T/I=0/500 Pressure up to 725 psi-start getting N2 from down spout Bleed to 0 psi and RD N2 Final T/I=0/0 1/16/2016 (AC EVAL)MITIA(FAILED)MITT 1500 PSI(PASS)T DDT(PASS)IA DDT(PASS) Initial T/I=0/0 Removed wood,grating and wrapped conductor Attempt to pressure IA to 500 psi rapidly drops to approx 150 psi repeat with same results 4 gallons pumped,getting deisel returns from downspout Bled to 0 psi continue to receive fluid from downspuot approx 1 gallon in catch drum.Discuss with WI Supervisor on location. Rig up to tree cap.Pressured T to 1500 psi with immeasuable amount of diesel 15 min monitor T/I=1125/0(-375 psi)repressured to 1500 psi 15 min monitor T/I=1140/0(-360 psi)repressured to 1500 psi 15 min monitor T/I=1450/0(-50 psi) 30 min monitor T/I=1425/0(-25 psi)bled to 0 psi Pressured IA to 500 psi with N2 let diesel purge through downspout. Repressured with N2 densowrap swelled and slug of diesel purged from downspout. Continue to purge N2 through downspout to 0 psi.Purged 2.25 gallons diesel total from downspout T&IA DDT T/I=0/0 15 min 0 psi 30 min 0 psi Have catch drum vac'd clean Final T/I=0/0 1/28/2016 T/I=0/0 • • 1/29/2016 (SW)Jeff Jones GMITIA Failed to 800 psi. Initial T/I=SI 0/0,02 @ 20.9,LEL @ 0 @ conductor. Pressured IA with N2 to T/I=0/800 5 min monitor:0/600(-200 psi),02 @ 18,LEL @ 0 @ conductor. Bled IA to T/I=0/0 **note**N2 in conductor. Final T/I=SI 0/0 Per Victoria Loepp via Jeff Jones with the AOGCC,MITT,DDT Tubing and DDT IA are not required. 2/1/2016 Initial T/I=0/0 Removed fluid from wellhead tubing using air hog to approximately 1ft.above tubing casing hanger Removed 1st and 2nd Swab Valves Installed 41/6 flange to top of tubing hanger Removed gages and installed needle valves for future excavation and P&A job. Final T/I=0/0 2/6/2016 Initial T/l=0/0 Removed flange and vac'd out remaining diesel in T.TOC=8'.Installed flange before leaving location. Final T/I=0/0 2/25/2016 Excavate well to—5 feet,remove standing plate.Excavation is still in progress 2/26/2016 Initial T/I=0/0 Rigged up and set shoring box and stairs.Excavation worked on setting proper slope and egress. Final T/I=0/0 2/27/2016 Initial T/I=0/0 Vac'd out 70 BBLS of H2O from excavation throughout the day and had scaffolding set up. Final T/I=0/0 2/28/2016 Initial T/I=0/0 Vac'd out 40 BBLS of H2O from excavation.Unable to proceed with job due to weather conditions. Final T/I=0/0 2/29/2016 P&A WELL WORK Initial T/O=0/0 Removed 80 BBLS of water from excavation water run in. Installed weld-o-lets and ball valve onto conductor Drilled through weld-o-let and open ball valve assembly and verified 0 PSI Found diesel in conductor,welded an additional weld-o-let below window area to drain diesel. Cut window into conductor. Chipped cement 360 degrees around conductor. Installed weld-o-lets and ball valve onto inner casing. Drilled through weld-o-let and open ball valve assembly and verified 0 PSI. Cut window into inner casing. Chipped cement 360 degrees around inner casing. Installed weld-o-lets and ball valve onto tubing.Verified 0 PSI.Cut and removed section of tubing.Finished cutting remaining casings and removed the conductor,inner casing and tubing with a crane.Notified the DTH to come and NORM test before removing from pad. Cut off well head 4 Ft.below tundra level. Topped off remaining well casings with 1 gal of type 1 cement. Final T/O=0/0 2/29/2016 Notified AOGCC for opportunity to inspect casing cut,cement top,and welded P&A Plate. 3/1/2016 P&A Well Work Small amount of diesel still weeping from the conductor stub,Called Victoria Leopp with the AOGCC and described casing cut and weeping diesel.She approved to continue with the inspection and welding the plate State Inspector,Johnny Hill,inspected and approved casing cement. GBR welder welded marker plate onto the conductor. State Inspector Johnny Hill,inspected and photographed P&A marker welded in place. (Too windy to remove shoring box,will return another day). 3/2/2016 P&A Well Work Rigged up lower stair case to crane and removed from excavation. Rigged up upper stair case to crane and removed from excavation. Rigged up shoring box to crane and removed from excavation. Rigged down shoring box and crane. 3/4/2016 P&A Well Work R&P finished back filling. 3/6/2016 Notified AOGCC(Brian Bixby waived)for opportunity to witness final burial of P&A. KUP OD 1D-126 ConocoPhilbps s i, Well Attribt Max Ang•D TD Ohl Wellbore API/UWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) • Alaska,If-K;. ''ConocoPhd500292288900 WEST SAK PROD 66.19 4,217.98 6,716.0 . , ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 10-126,312412016 1 1 52 37 AM SSSV:NONE 10 8/14/2012 Last WO: 6/20/2010 47.00 12/10/1998 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 5,139.0 5/30/2010 Rev Reason:P&A,SEE NOTES pproven 3/16/2016 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 55.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(...Grade Top Thread CONDUCTOR;55.0-121 0 ^PRODUCTION 7 5/8 6.750 55.0 6,690.8 4,105.8 29.70 L-80 ABM-BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING Kill String 31/2 2.992 55.0 2,407.4 1,592.0 9.30 L-80 EUE 8rd Tubing Description I String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING Abandoned 31/2 2.992 5,890.9 6,011.4 3,461.0 9.30 L-80 EUE8rdABMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 5,940.7 3,394.6 20.11 SENSOR Guardian Sensor @ 5,936'-5,938' 2.992 f1= y 5,982.5 3,433.9 19.92 INTAKE ESP-Intake, 2.992 CMT Retainer 5.0700 5,9872 3,438.3 19.90 TANDEM Upper and Lower Seal, SEALS 6,001.0 3,451.2 19.83 GEARBOX GRU,525,9:1 6,002.0 3,452.2 19.83 MOTOR ESP-Motor 57 hp,1315v,KMHG 0.000 FISH,5,0890 6,008.8 3,458.6 19.80 Centralizer ESP Motor Centralizer 1.995 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) IRKS) C) Des Corn Run Date ID(in) 5,070.0 2,732.5 6329 CMT Retainer Cement Retainer 6/18/2010 5,089.0 2,741.1 6260 FISH E-Line Logging Tool String 606/2010 0.000 ESP MANDREL;5,856 9 Perforations&Slots Shot I Dens Top(ND) Min(ND) (shots/ Top(ftKB) Min(ftKB) (RKB) (ftKB) Zone Date ft) Type Com 6,060.0 6,090.0 3,506.8 3,535.1 WS D,1 D- 9/22/1998 4.0 IPERF 0 deg phase,down I 126 6,122.0 6,142.0 3,565.3 3,584.2 WS B,1D- 9070998 4.0 IPERF 9 deg phased,orient 126 down 6,222.0 6234.0 3,659.8 3,671.1 WS A3,1D- 9/13/1998 4.0 IPERF 0 deg,phsing,0 deg 126 orient down I 6,239.0 6,256.0 3,675.8 3,691.9 WS A3,1D- 9/13/1998 4.0 IPERF 0 deg phasing,0 deg _ 9 126 orient down INTAKE.5.982.5 i®i !iY 6,288.0 6,318.0 3,722.2 3,750.6 WS A2,1D- 8/25/1998 4.0 IPERF 0 Deg phase,down 126 TANDEM SEALS,5.987 2 illi, Cement Squeezes Top(ND) Btm(ND) GEARBOX;6,001.0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn 5,560.0 6,400.0 3,054.6 3,828.4 Cement Plug 3/29/2010 Pumped 48 bbls of 14.6 ppg RFC cement across MOTOR;6,002.0 _ perforations.Displaced cement with 42 bbls of 10.1 ppg CaCI brine 8 1.5 bbls of diesel.Estimate TOC @ etii -5560'MD Centralizer,0.0088 $� 4,839.0 5,071.0 2,630.3 2,732.9 Cement Plug 6/19/2010 Pumped 11.4 bbls of Class G Neat cmt and lay balanced plug f/5,071'to 4,820' 2,660.0 4,839.0 1,697.9 2,630.3 Cement Plug 9/11/2014 Pumped 100 bbls of 15.7 ppg Arcticset I Cement in 7- 5/8"casing from 4804'to 2625' MNPVVS 0.0 2,660.0 0.0 1,697.9 Cement Plug 10/22/201 PUMPED 136 BBLS OF 15.7 PPG AS1 CEMENT 5 DOWN 3.5"KILL STRING UP IA Mandrel Inserts St ati N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD lin) Sery Type Type (in) (psi) Run Date Com .. 1 5,896.9 3,353.5 CAMCO KBMG 1 GAS LIFT SOV BK-5 0.000 0.0 1/7/2010 IPERF,6,060.06,090.0 NoSevN Notes:General&Safety End Date Annotation 6/18/2008 NOTE:VIEW w/9.0 SCHEMATIC \."..,..., 7/20/2010 NOTE:WELL P&A'd,KILL STRING IN PLACE IPERF,6.122.06.142.0 `1, 1.1.11\ 10/22/2015 NOTE:PUMPED 136 BBLS OF 15.7 PPG AS1 CEMENT DOWN 3.5"KILL STRING UP IA TAKING RETURNS /y\", TO OPEN TOP 2/29/2016 NOTE:REMOVED WELLHEAD AND CASING 4'BELOW TUNDRA GRADE 30/2016 NOTE:WELDED P&A MARKER ON CASING STUB IPERF;6,222.06,234.0f Wet IPERF;6,239.0-6,256.0 L~ IPERF;6,288.06,318.D V• PRODUCTION;550-6,690.8 [- • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 3/1/2016 P. I. Supervisor FROM: Johnnie Hill SUBJECT: Surface P&A Petroleum Inspector KRU 1D-126 ConocoPhillips Alaska Inc. PTD 1981080 3/1/2016: I went over to Kuparuk 1D-126 to witness the surface P&A of the well. When I showed up I was told the well had a slow weep of diesel coming up through the cement. Conoco rep MJ Loveland and I called Victoria Loepp (AOGCC Engineer) and received approval to go ahead with the surface abandonment. The cut off was below the required depth. I took a five-foot frost bar and dropped it on the cement to make sure the surface plug was completely set up. I witnessed the contract ASRC personnel weld the cap on the casing stub — a '/-inch steel cap with full weld around it. Summary: The job went well everything was in order as far as paperwork. The ASRC hands were well-informed about the job. Attachments: Photos (2) SGA14tiED SEP 2 1/016 2016-0301_Surface_Abandon KRU_1D-126,jh.docx Page 1 of 2 • • ,/,-.....--.47, •" .4t..4. , .1 '.1 .411011w . '. ' Ar*ijii 'i-' . :. /11111r: :di . ..__ s4 i, f`tB ,1. �^ .n 1 1-,,..- _ii 111� i i o o xl O ��r,�� O N bOA czt a ..* I O ct .,(' ,-a oM6" co o co r , d — i �» N = , ( • • Et QD!: CI, f , � �. ! • ` .° • c 0 ! a� �. �� al Q a y Cr) o V W. MLS , N 0_ C • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg e1( DATE: 2/3/2016 P. I. Supervisor FROM: Jeff Jones SUBJECT: P&A— Pressure Test Petroleum Inspector KRU 1D-126 CPA! PTD 1981080; Sundry 315-594 ' January 29, 2016: I witnessed a pressure test of the Inner Annulus on monobore production well KRU 1D-126. Visual inspection of the IA indicates that the top of cement is just above the conductor downspout. The annulus pressure test was performed with - nitrogen. The operator attempted to pressure the IA to 1500psi but at 800psi, gas returns were observed up the IA by conductor annulus — no methane gas was detected. - The nitrogen pump was shut off to monitor IA— pressure decreased from 800psi to 600psi in 2 minutes. The IA test was determined to be a failure. - Summary: I witnessed a failed pressure test of the IA on suspended well KRU 1D- 126. This test was part of the surface abandonment sundry. Attachments: none s , ;WE '; 3, 9 E. 2016-0129_We11_Integrity_KRU_1 D-126_j j.docx Page 1 of 1 • P709 l 4if _10 V Loepp, Victoria T (DOA) From: Simek,Jill <Jill.Simek@conocophillips.com> Sent: Thursday,January 21, 2016 4:22 PM To: Loepp, Victoria T (DOA) Subject: RE: 1D-126 P&A (PTD: 198-108, Sundry 315-594) P&A Follow Up Flag: Follow up Flag Status: Flagged scWe MAY 1 9 2016 Will do. Thank you for clarification. From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, January 21, 2016 1:42 PM To: Simek, Jill Subject: [EXTERNAL]RE: 1D-126 P&A (PTD: 198-108, Sundry 315-594) P&A From: Simek, Jill [rnailto:Jill.Simek@conocophillips.com] Sent: Thursday, January 21, 2016 1:39 PM To: Loepp, Victoria T(DOA) Cc: Winter, Roger(ASRC Energy Services) Subject: RE: 1D-126 P&A (PTD: 198-108, Sundry 315-594) P&A Yes,we pressured with nitrogen until diesel stopped and only nitrogen was coming out of downspout. In the procedure,State Witnessed MITs and DDTs are required. Testing to date has not been witnessed. Would you like us to arrange to test again with State Representative, before we proceed with the excavation? Thanks, Jill From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, January 21, 2016 11:32 AM To: Simek, Jill Subject: [EXTERNAL]RE: 1D-126 P&A (PTD: 198-108, Sundry 315-594) P&A Have you pressured with nitrogen until the diesel flow dissipated or stopped? From: Simek, Jill [mailto:Jill.Simek@conocophillips.com] Sent: Thursday, January 21, 2016 11:29 AM To: Loepp, Victoria T(DOA) Cc: Winter, Roger(ASRC Energy Services); NSK Well Integrity Proj; Senden, R. Tyler Subject: RE: 1D-126 P&A (PTD: 198-108, Sundry 315-594) P&A Thanks, Victoria. Yes,we have pressured the IA with nitrogen, purging a total of 2.25 gallons of diesel through the downspout. I will advise Field Supervisor to proceed with the excavation and removal of the wellhead. Plans are to recommence 2/9/16. 1 • • From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, January 21, 2016 9:26 AM To: Simek, Jill Subject: [EXTERNAL]RE: 1D-126 P&A (PTD: 198-108, Sundry 315-594) P&A Jill, Is the diesel from previous PTs with diesel and if so can you pressure the IA with nitrogen until the diesel through the downspout dissipates? If so, please try this. Approval is granted to proceed with the excavation and removal of the wellhead. 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.Loeppt 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 From: Simek, Jill [mailto:Jill.Simek@conocophillips.com] Sent: Wednesday, January 20, 2016 4:14 PM To: Loepp, Victoria T(DOA) Subject: RE: 1D-126 P&A (PTD: 198-108) Victoria, Attached is cement bond log from 6/17/2010. The TOC between conductor and 7-5/8" is 2". Jill From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, January 20, 2016 8:19 AM To: Simek, Jill Subject: [EXTERNAL]RE: 1D-126 P&A (PTD: 198-108) Has a cement evaluation log ever been run on the 7-5/8"?Where is TOC between the conductor and the 7-5/8"? From: Simek, Jill [mailto:Jill.Simek@conocophillips.com] Sent: Tuesday, January 19, 2016 4:49 PM To: Loepp, Victoria T(DOA) Subject: RE: 1D-126 P&A (PTD: 198-108) Hi Victoria, 2 Cement report below, showing full cement returns to surface. I can get more information from the well file tomorrow if you need it. 6/27/1998: DOWELL PUMP 40 BBLS WATER AHEAD, 7.9 BPM, 200 PSI. MIX AND PUMP 10.5 PPG AS III LW LEAD CMT UNTIL GETTING GOOD 10.5 PPG CMT RETURNS TO SURFACE, 7.5 BPM, 220 PSI. CONTAMINATED 7.4 PPG WATER RETURNS AT 250 BBLS LEAD PUMPED, CONTAMINATED 10.0 PPG CMT RETURNS AT 330 BBLS, CLEAN 10.4+ PPG CMT RETURNS AT 255 BBLS PUMPED, SWITCHED TO TAIL AT 374 BBLS, 475 SX LEAD PUMPED. MIX AND PUMP 10 BBLS, 15.7 PPG AS I TAIL CMT, 4 BPM, 250 PSI. DROP CLOSING PLUG AND CHASE W/25 BBLS WASH-UP WATER, 6 BPM, 280 PSI. SWITCH TO RIG PUMP AND DISPLACE W/MUD, 5.8 BPM, 500 PSI. BUMPED PLUG AT 111 BBLS MUD PUMPED, SLOWED TO 3.5 BPM TO BUMP. BUMPED UP TO 2000 PSI, SAW STAGE TOOL CLOSE AT 1300 PSI. ALSO HAD A SECOND SHEAR JUST BEFORE STOPPING PUMP AT " 1950 PSI (STAGE TOOL SLEEVE LOCKING IN??). HELD 2000 PSI OK. CHECKED FLOATS, OK. SECOND STAGE CIP @ 1905 HRS. FULL RETURNS, GOOD 10.5+ PPG, 11.7 PH CMT RETURNS TO SURFACE. PU ON PIPE TO 190K# TO CENTER TO SET SLIPS. Thanks, Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1854, Anchorage, AK 99501 Phone: 907-263-4131 I Cell: 907-980-7503 From: Loepp, Victoria T(DOA) [rnailto:victoria.Ioepp@alaska.gov] Sent: Tuesday, January 19, 2016 2:59 PM To: Simek, Jill Subject: [EXTERNAL]RE: 1D-126 P&A (PTD: 198-108) What is the cement record for the 7-5/8" production casing? From: Simek, Jill [mailto:Jill.Simek@conocophillips.com] Sent: Tuesday, January 19, 2016 11:54 AM To: Loepp, Victoria T(DOA) Subject: 1D-126 P&A (PTD: 198-108) Victoria, As discussed, ConocoPhillips is performing P&A operations on 1D-126, per Sundry Approval received October 5, 2015 (Sundry Number 315-594). Summary of P&A Operations to Date: 10/22/2015 Fullbore cement job was performed to place 136 bbls of ArcticSet 1 cement in the tubing(kill string) and IA. 10/28/2015 MITs failed;TOC in IA was measured at 41ft and 3 inches. 1/13/2016 An additional 2 bbls of cement was pumped into the IA. 1/16/2016 MIT-T passed to 1500psi,Tubing and IA drawdown tests passed. MIT-IA failed,with diesel returns observed from the downspout installed on the conductor. Pressured IA to 500psi with Nitrogen and received 2.25 gallons of diesel through the downspout. Cement top in IA at 4" below the IA valve. 3 • The failed MIT-IA suggests that a very shallow leak still exists in the production casing,allowing communication from surface,through production casing to conductor. However,the passing drawdown tests indicate that the wellbore is completely isolated from formation. ConocoPhillips thereby requests to continue with the P&A operation,the next step being excavation and removal of wellhead where, if a leak is present above cement top, it will be cut off during the casing cutting/wellhead removal operation. Please advise if you agree with this path forward. Wellbore schematic is attached for your reference. Thank you, Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1854, Anchorage, AK 99501 Phone: 907-263-4131 I Cell: 907-980-7503 4 • 1D-126 Plug and Abandon PTD #: 198-108 Cement Plug#4 TOC @ Surface 16"62.5#H-40 Conductor @ 121'KB ti \\\ \\:\ k\\\\\\\\:,:\ili.„\\:\\\..\\.\ 3-W 9.3#L-80 Tubing Kill String @ 2,410.0'KB Cement Plug#3 TOC @ 2,660.0'KB(tagged) \\S\\"\\\\''N\ Cement Plug#2 TOC @ 4,839.0'KB(tagged) Inflatable Bridge Plug @ 5,070.0'KB Fish @ 5,089.0'KB Cement Plug#1 TOC @ 5,560.0'KB(estimated) Abandoned 3-'/z"Tubing with ESP Assembly 5,890.9'—6,011.4'KB Perfs: 1 !I 0 —6,090.0'KB \\\\\\\\\\N. 1 —6,142.0'KB 2 -6,256.0'KB—6,318.0'KB 7-5/8"29.7#L-80 Production Casing @ 6,690.8'KB -4411 JS 1-19-16 • OF Tye yw THE STATE Alaska Oil and Gas �� of/\ 4S}(i\ Conservation Commission 1 1 ':if sft = STATE OF ALASKA . RECEIVEL IDASKA OIL AND GAS CONSERVATION COMMISSION SEP 2 3 2015 APPLICATION FOR SUNDRY APPROVALS 07-S /0 l s` ic- 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations (` Fracture Stimulate r Pull Tubing r Operations Shutdown 1 Suspend I_ Perforate 1_ Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool I Repair Well r Re-enter Susp Well r Other: I- 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory I— Development i✓ . 198-108 3.Address: 6.API Number: Stratigraphic L_ Service I— P. O. Box 100360,Anchorage,Alaska 99510 50-029-22889-00 ' 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes 1_ No rt KRU 1D-126 , 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25650 ' Kuparuk River Field/West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 6716 4130 5070' 2733' 2625,4820,5070,5560 5089' Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121' 121' PRODUCTION 6650 7.625 6691' 4106' Perforation Depth MD( 6060-6090, Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6122-6142,6222-6234,6239-6256,6288-6318 3507-3535,3565-3584,3660-3671,3677-3692,3722-3751 kill string 3.5 L-80 2410 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no packer no SSSV 12.Attachments: Description Summary of Proposal r7 13. Well Class after proposed work: Detailed Operations Program (" BOP Sketch (' Exploratory P Stratigraphic I Development I ., Service L._ 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/15/2015 OIL I WINJ i— WDSPL I- Suspended 1- 16.Verbal Approval: Date: GAS p. WAG p GSTOR I— SPLUG p Commission Representative: GINJ p Op Shutdown I— Abandoned r3 - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Simek @ 263-4131 Email: Jill.Simek(u)conocophillips.com Printed Name Jill SiTek Title: Staff Well Integrity Engineer Signature 5)A., /( Phone:263-4131 Date i� )iOt/5 \ Commission Use Only Sundry Number: Conditions of approval: •Notify Commission so that a representative may witness 3(5- 15 9 l Plug Integrity /BOP Test r Mechanical Integrity Test r Location Clearance !-- No tiJFti ite6GC 1nsrr�td,- I phof-a 4ocfr .o e -if- '-Gi-c Co <lvw,� Other: /• WI to tSS r'e�t l' -ed fo re n F/i- .-� c' c"r, e� t' S�rfac c � 2• Witi'►t55 dv¢ off /'JP"ior' to weld i i pLQ•tt 3, iitz CIra re-at vicz GtDprorc4 /. Spacing Exception Required? Yes ❑ No E( Subsequent Form Required: /d - 1 t 7 / APPROVED BY Approved by: �� COMMISSIONER THE COMMISSION Date: l�—S-is / Ap�yoi �pG citpr�lAL for 12 months m the date of approval. U K \vi $ _— Form 10-403 Revised 5 2015 RBDMSLrrlrbinalitScate R �Yr�7 J tJL( LtJ IJ • RECEIVEL ConocoPhillips SEP 2 3 2015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 21 September 2015 Commissioner, State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to plug and abandon West Sak well 1D-126(PTD#: 198-108). The 1D-126 well was drilled and completed as a single casing ESP producer in December 1998. In December 2009, it was shut-in due to ESP failure with plans for rig workover to replace the pump in Q3 2010. On 26 March 2010, a leak was discovered in the production casing which resulted in produced fluids to surface. Kill Weight Fluid was pumped followed by cementing operations to place 48 bbls of cement across the perforations. In June 2010, a rig workover was performed to continue with the suspend operations. The 3-1/2" tubing was cut and pulled above the cement plug. An Inflatable Bridge Plug(IBP)was set at 5,070.0 ftKB and a balanced cement plug was placed from the IBP to approximately 4,820.0 ftB. On 11 September 2014, additional cement was placed to 2,660.0ft KB in an attempt to cover a suspected leaking stage collar at 2,930 ftKB. During this cement job, fluids were observed dripping from the down spout on the conductor, indicating a flow path from the production casing to atmosphere. A subsequent MIT-T failed, confirming that the cement plug was unsuccessful in plugging the casing leak and/or another shallower leak was present. Memory Magnetic Thickness Tool (MTT) logging on 1 July 2010 shows possible metal losses on 7-5/8" Csg at 42 to 48' RKB, so a shallow casing leak may source the conductor leak from 7-5/8"casing. Per this procedure, a P&A will be performed by pumping 133.6 bbls of ARCTICSET 1 (AS1) cement fullbore to place a cement plug from approximately 2,660 ftKB (existing Top of Cement)to surface in the kill string and production casing, thus eliminating the fluid communication path from production casing to conductor. Surface excavation for removal of wellhead and final P&A operations will follow. If you have any questions or require any further information,please contact me at 263-4131. Sincerely, 0 Simek ell Integrity Engineer CPAI Drilling and Wells • ConocoPIIips 1D-126 P&A Permit to Drill #: 198-108 The objective of the proposed 1D-126 P&A is to pump a fullbore cement plug from approximately 2,660 ftKB (existing Top of Cement) to surface in the kill string and production casing, thus eliminating the fluid communication path from production casing to conductor. Surface excavation for removal of wellhead and final P&A operations will follow. Proposed P&A: Schlumberger Cementing: Objective: Place a cement plug from 2,660 ftKB to surface. We will be circulating cement down the 3-1/2" kill string and up the 3-1/2" x 7-5/8" annulus. Cement Volume Calculations: • Volume in 3-1/2" kill string = (2660 ft)*( 0.00869627 bbl/ft) = 23.1 bbl • Volume in 3-1/2" x 7-5/8" annulus = (2660 ft) * (0.0340151 bbl/ft) = 90.5 bbl • Excess: 20 bbl • Total volume = 23.1 + 90.5 + 20 = 133.6 bbl 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU SLB Cement Equipment, ensuring that hardline is rigged up to pump down the tubing and take returns to a tank from the 3-1/2" x 7-5/8" annulus. 3. Tie in cement wash up lines, and isolation valves that will allow for surface lines to be flushed when cement is seen at surface. 4. PT surface equipment as required. 5. Circulate well to seawater/brine. 6. Pump 10 bbls fresh water spacer. 7. Pump 133.6 bbls of 15.7 ppg ARCTICSET* 1 (AS1) Cement. a. This calculation assumes 20 bbl of excess cement to ensure good cement to surface. 8. Monitor returns on surface, taking samples and checking pH/density. 9. Once good cement returns are verified on surface (use mud scale for cement density measurement), shut down and open up the surface bypass line to flush all lines with water. 10. Wash up SLB cement pumps. 11. RDMO Little Red: 1. WOC 48 hrs. Notify the AOGCC Inspector of the timing of the cement plug pressure testing (24 hour minimum notice). AOGCC Witness Required. 2. RU LRS and PT Equipment. 3. MIT-T 4. MIT-IA 5. Perform drawdown test on tubing and IA. JS • • Wellhead Excavation / Final P&A: 1. Remove the Well House (if still installed). 2. Bleed off T/I/O to ensure all pressure is bled off the system. 3. Remove the production tree, in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. 6. Perform Top Job and verify that cement is at surface in all strings. AOGCC witness and photo document required. 7. Send the casing head w/ stub to materials shop. Photo document. 8. Weld 1/4" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips KRU 1D-126 PTD #: 198-108 API #: 50-029-22889-00 9. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo document final location condition after all work is completed. JS • 0 • Wellbore Schematic: KUP PROD 1D-126 ConocoPhillips Well Attributes Max Angle&MD TD 11) Alaska,kic We tbo a AP11PM Field Name Wellbore Status snot I') MD 171316) Aet Bien(5X6( :aC 3L88923 WEST OAK PRW Sb"i 4211.98 6,716.0 ... Comment N2S(ppm) Date Mnotalian End Date KBGrd(R) Iirp ketease bate 40025,320.2011134149$Pea SSSV.NONE 11) 894.2012 Last WO. 6)20,2012 4/.W 121)0(938 verve.swine.lams, Mn eatian + Depth(SKS) End Date Mrwtanon Lan Mod ey End Date Lust leg:SLM 5.139 0 5/30/2010 Rev Reawrt PARTIAL PEA CEMENT ttp:Fkf 21112014 r evaugeR:ors- -'C - Casing Strings Casing Desonptton OD tin) 10 On) Top IRKS) Set Depth 011681 Sot Depth(iW)...Wel II.Grade Top Thread COND CIOR It 15-062 42.0 210 121.0 62 0011-40 WELDED 'Casing Des !porn -VU lin) It)On) op IR108) set Dep'F 646t Set 3.eptht VU)...WeL II. rade top thread I ICN 158 8.1SL4'.I ::;z 4105 0 7JL90 A6f .1 DI(Tubing Strings I-8114 ]ag 2 1:2 2 - �^ TCUMomBpDeleonDetaiSstr B Ma ID 1 Top(RK8) seOpt{ SeDepth(TVD)(.Wt(IbIR) 'Grade Top Connector) •'J 4. 1 J V.L(i L L S d M DNo-nmni COibCTCR:e201]c ,.•..., ,,..,r-- Top(M(B) Top(I7 RK6t Top Inc•1) h CVs C n) 312 4103 0:Lt aNtaEF Vel:n(ray 11'.412 CWCT Hanger Tutting Desarpt 'String Ma I ID 1 Top 0231 .eDepth t.I Set Depth(n9)(.Wt(M) ITod. I Tap C 1n95D`- I UDIv:r 00.0...'02 s-2 212 -I 0�n 6,0'14 3,4)10I '35)--25 LE A) S0 Completion Details Top frtel Tap(IVO)til Top e,Pl(( Item Des cont 21 5.940./ 3.394.6 20.11 SENSOR 0uerduen Sensory 5 936'.5,939' _70- 5282.5 3.433,9 1992 INTAKE ESP-Intakte, __I 5.9812 3 438.3 1990 TANDEM Uppor end Lower-vim - CxeTReraner 5610.0----- ""' SEALS 6,001.0 3451.2 19.83 GEARBOX CiHLI525 9.1 6.W2.0 3452.2 '983 W31-0H ESP-h1c'4::r Sl tip.12)6v,KM'ILI 02',','.6 non,604s t D6,008.8 ?450 2 " P t-c _s0 Can IdIttUr LSI- )e.,.,l.,:, t_P' Other in Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top MIDI Top Ind Top(et54) (10118) ('T Des Com R:n Da. ID Int 5130 2,732.5 62.2`3 CMI Reta;rea CurtnintRetainer E'.F2110 / ,230 2,741-; 5268 FISH ELrne Loggasj 16, ,.,r.g 5'.0.11.3 0330 Perforations&Slots ISP MANDRIL 5.35.3 I shot Dens Top fr/D) Bon(ND) Ishotsit Top(K6) him IRKB) MKS) Zone Pate ii Type Can 6060.0 0.0900 3,506.8 3536.1 WO O.10-126 9,221'1998 4.0 IPERF 0Wtgphase.down ,iiill 6.122.0 6,142.0 75653 3.5842 WS 13 1D-126 9717/1998 4.0(PERF 9doO pleased anent awn 6.2226 6,234.0 342.8 56701 WS A3,107- 5113/1498 4U!PERI- '0 dog.phs,g,0 deg 126 anent down 6,239 0 6256 0 3,6/5 8 3.661.9 WS A3,10- 4113,1998 4 0 IPERF '0 dug phasing,O deg INTAKE.5.952.3 ri1"f{ 126 ainmdown ri6iiE`., 6.2880 6.318.0 3.7222 3.750.6 WS A2.14 8'1511_38 4.0 1PERF 0 Deg phrase.down 26 TAMEN,SEA4g.5.291.2 , Cement Squeezes GEARBOX;6.031.• Top IND) Ban 11040) +, Top)5561 Bon MKS) (SKI) (SKR) Des Start Date Corn 5,5641.0 6.409 G 3,054.5 3.8284 Cement PIuy 3'262010 Pumped 48 Otos o)14.6 ppg RFC caner'I across- MOTOR:5.102.. =' W iera6als.Drsplaart Penton(with 42086 of 101 post Coll brine&1.5 tblx of diesel.Eputrate Te2C 0.y0 CenoaVer,5.:d5. 0' 'e 5660'MD aA 4,820.0 6.0/1.0 2,112'10 2.172.9 Cement Plug 0202010 Pumped 17.4 Gbh of Crate O Neat cat rend lay tutrkanced plug S'5.071"10 4.820 2,6250 4.804.0 1.6832 2,615.1 Cement Plug 91112014 Pumped 10018711 al 15.7 ppg Ar6csel 1 Comer!eti 7- 5,5/8'liming from 4804'le 2620' oNeseNsut Mandrel Inserts St a1 NToTop(TVD) Van Latch Pat Sue 1RO Run Top Imo) Make. Model OD(in) Sm Type Type (in) (psi) Ru10te Com 5,0/9�0�.�9�� 3,353.5 CAW() 3166500 1 (10,5 LIFT SCA" 13K.5 0.01+0 „!,2Cr,3 meAF:5,25004,030.0- Notes:General&Se.ty End Dae Annotation 6;16161`0 NC:E.'vII w190 SCHEMA)IC 7'201'0'.0 1131E%NEL_P&A'd KILL STR7NCi IN PLACE Pelee,.5,122.04,142.0 1_ .000..,0..- .. I 1 t4 0000__. 1 : Js • • P&A Diagram: 1D-126 Plug and Abandon PTD#: 198-108 Current Completion Proposed Suspension ` Cement Plug#4 TOC @ Surface Ai 1 > 82.5 H 4+ ,'ow-Lc-tor`J 121'KB . �`±. ' 15.74 ARCTICSET 1 \ \ * \ 1111414 3-1'279.34 L-80 Tubing Kill String @ 2,410.0'KB " Cement Plug#3 TOC @ 2,660 0'KB(tagged) i�\ \\:\\\\\.\\\*. 2-.9 30 ' V 51-1 evircLA \\ ., Cement Plug#2 TOC @ 4,839.0'KB(tagged) _.„." inflatable Bridge Plug @ 5,070 0'KB Fish @ 5,089.0'KB 3if. `\`\\,, Cement Plug#1 TOC @ 5,560.0'KB(estimated) \. \114111 Abandoned 3-7:"Tubing wdh ESP Assembly 5,890.9'-6.011.4'KB � . \ iiiiN ‘ \ ; Perfs: \ 6,060.0—6,090.0'KB s� \ '• 6,122.0—6, .0'KB \\\ 6,239.0—6,256256.0'KB 6,288.0-6,318-0'KB ...ai. , -.. 7-518"29.74 1-80 Production Casing c@'1i 6,690.8'KB ...111111 JS 5.22_15 .IS STATE OF ALASKA AL,-,0KA OIL AND GAS CONSERVATION COMIvuISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdow n r Performed Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Suspended well inspect J 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 198-108 3.Address: 6.API Number: P 0 Box 100360, Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-22889-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25650 KRU West Sak 1 D-126 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s) NA Kuparuk River Field/West Sak Oil Pool 11 Present Well Condition Summary Total Depth measured 6716 feet Plugs(measured) 5070 true vertical 4130 feet Junk(measured) 5089 Effective Depth measured 2410 feet Packer(measured) None true vertical 1593 feet (true vertical) None Casing Length Size MD ND Burst Collapse CONDUCTOR 79 16 121 121 1640 630 PRODUCTION 6650 7.625 6691 4106 6890 4790 SCkNNCD S L 1 `1 %u Perforation depth: Measured depth. 6060-6318-cemented RECEIVED True Vertical Depth: 3507-3751 -cemented JUN 3 0 2015 Tubing(size,grade,MD,and TVD) 3.5, L-80, 5983 MD,3434 TVD AOGCC Packers&SSSV(type,MD,and TVD) NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14.Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C O.Exempt NA Contact MJ Loveland/Martin Walters Email N1878@conocophiIIips.com Printed Name MJ Loveland / Title WI project Supervisor Signature .�/ Phone:659- ! 3 Date / V/c...- ii%L 7-11/1 RBDMS JUL - 1 2015 02- 1/4M Form 10-404 Revi ed 5/2015 Submit Original Only lov ConocoPhillips RECEIVED Alaska P.O. BOX 100360 1 U N 3 0 2015 ANCHORAGE,ALASKA 99510-0360 AOGCC June 29, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Kuparuk River Unit West Sak 1D-126 (PTD 198-108) Dear Commissioner Foerster: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit West Sak well 1D-126 (PTD 198-108). The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs The well is being held as a suspended well until a formal P&A can be completed. Please call Martin Walters or me at 659-7043 if you have any questions. Sincerely, //e4--7 MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: KUPARUK RIV UNIT WSAK 1D-126 Field/Pool: KUPARUK RIVER/WEST SAK Permit#(PTD): 198-108 Sundry 310-163 API Number: 50-029-22889-00-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 6/19/2010 Surface Location: 301' FNL, 599' FEL Section: 23 Township: 11N Range: 10E Nearest active pad or road: KRU DS1 D Meridian: UMIAT Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good _ Location cleanup needed: None Pits condition: Backfilled Surrounding area condition: Good Water/fluids on pad: none Discoloration, Sheens on pad, pits or water: none Samples taken: none Access road condition: good Photographs taken (#and description): 3 photos of well and area Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Good Cellar description, condition, fluids: Lined with a small amout of water _ Rat Hole: NA Wellhouse or protective barriers: wellhouse Well identification sign: yes Tubing Pressure (or casing if no tubing): 0 psi Annulus pressures: IA 0 pis Wellhead Photos taken (#and description): 3 of well and area Work Required: none Operator Rep (name and signature): Perry Greenwood AOGCC Inspector: Johnnie Hill Other Observers: Cody Warfield Inspection Date: 6/27/2015 AOGCC Notice Date: 6/25/2015 Time of arrival: 1450 Time of Departure: 1455 Site access method: Truck • z KUP PROD 1 D-1 26 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl 0) MD MB) Act Btm(ftKB) crxxnndhpa 500292288900 WEST SAK PROD 66.19 4217.98 6,716.0 ••- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1D-126,10/7/20143:47.04 PM SSSV:NONE 10 8/14/2012 Last WO: 620/2010 47.00 12/10/1998 Vertical schematic(actual) Annotation Depth(MB) End Date Annotation Last Mod By End Date Last Tag:SLM 5,139.0 5/30/2010 Rev Reason:PARTIAL P&A CEMENT hipshkf 9/11/2014 .......................................................... WINGER;36.3-Wil Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 420 121.0 121.0 62.58 H-40 WELDED -Casing Description OD(in) 'ID(in) 'Top(RKB) Set Depth(ftKB) Set Depth(ND)...'WILen(I...Grade Top Thread PRODUCTION 75/8 6.750 41.1 6,690.8 4,105.8 29.70 L-80 ABM-BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Mt) Grade Top Connection TUBING Kill String 3 1/2 2.992 36.3 2,410.0 1,593.1 9.30 L-80 EUE 8rd ,. . , . , . . toot.Completion Details -A-A" Nominal ID -A-A"CONDUCTOR;42.0721.0 11111 IP , Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 36.3 36.3• 0.00 HANGER Vetco Gray 11"x 4 1/2 CWCT Hanger 2.950 Tubing Description String Ma...ID(in) -Top(RKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING Abandoned 3 12 2.992 5,890.9_ 6,011.4 3,461.0 930 L-80 EUE8rdABMOD Completion Details I Nominal ID iii Top(RKB) Top(ND)(ftKB) Top Ind(*) Item Des Corn (in) 5,940.7 3,394.6 20.11 SENSOR Guardian Sensor @ 5,936'-5,938' 2.992 5,982.5 3,433.9 19.92 INTAKE ESP-Intake, 2.992 _ 5,987.2 3,438.3 19.90 TANDEM Upper and Lower Seal, CMT Retainer;5,070.0 -- SEALS 11 6,001.0 3,451.2 I. 19.83 bEARBOX GRU,525,9:1 6,002.0 3,452.2 19.83 MOTOR ESP-Motor 57 hp,1315v,KMHG 0.000 FISH 5089 o 6,008.8 3,458.6 19.80 Centralizer ESP Motor Centralizer 1.995 ID(in) Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) _ (ftKe) (°) Des Com Run Date 5,070.0 2,732.5- 63.29 CMT Retainer Cement Retainer 6/18/2010 A .ti 5,089.0 2,741.1 6260 FISH ,E-Line Logging Tool String 6/16/2010 0.000 -v Perforations&Slots ESP MANDREL.5,896.9 C]s Shot V Dens re. V Top(ftKB) BM)(ftKe) Top(RK(B)) Bt(RK(B)) Zone Date (shtt) Type Com 6,060.0 6,090.0 3,506.8 3,535.1 WS D,1D-126 9/22/1998 4.0 IPERF 0 deg phase,down - 6,122.0 6,142.0 3,565.3 3,584.2 WS B,1D-126 9/17/1998 4.0 IPERF 9 deg phased,orient I down 6,222.0 6,234.0 3,659.8 3,671.1 WS A3,10. 9/13/1998 4.0 IPERF '0 deg.phsing,0 deg I126 orient down '7" 6,239.0 6,256.0 3,675.8 3,691.9 WS A3,10- 9/13/1998 4.0 IPERF 0 deg phasing,0 deg INTAKE;5,982.5 )))))(. 126 Orient down • 6,288.0 6,318.0 3,7222 3,750.6 WS A2,1D- 825/1998 4.0 IPERF 0 Deg phase,down TANDEM SEALS;5,987.2 126 Cement Squeezes GEARBOX;6,001.0 Top(ND) Bim(ND) Top(ftKB)_Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 5,560.0 6,400.0 3,054.6 3,828.4 Cement Plug 3/29/2010 Pumped 48 bbls of 14.6 ppg RFC cement across MOTOR;6,002.0 t"--t perforations.Displaced cement with 42 bbls of 10.1 ppg CaCI brine&1.5 bbls of diesel.Estimate TOC @ Centralizer;6008.8 t 4 `5560'MD F 4,820.0 5,071.0 2,622.0 2,732.9 Cement Plug 6/19/2010 Pumped 11.4 bbls of Class G Neat cmt and lay balanced plug t/5,071'to 4,820' 2,625.0 4,804.0 1,683.2 2,615.1 Cement Plug 9/11/2014 Pumped 100 bbls of 15.7 ppg Arcticset I Cement in 7- 5/8"casing from 4804'to 2625' Mandrel Inserts ISt ti N Top(TVD) Valve Latch Port Size TRO Run Top(RKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 5,896.9 3,353.5 CAMCO KBMG t 1 GAS LIFT SOV BK-5 0.000 0.0 1/7/2010 s Notes:General&Safety IPERF;6,060.0-6,090.0 WV End Date Annotation :.; 6/18/2008 NOTE:VIEW w/9.0 SCHEMATIC M 7/20/2010 NOTE:WELL P8A'd,KILL STRING IN PLACE IPERF;8,122.0-6,142.0 iiW 1TN IPERF;6.222.0-6234.0 .•W IPERF;6,239.0-6.256.0 .ineiro IPERF;8,2880.8,318.0 r PRODUCTION,41.1-6 690 8 a• P III s 6 Z 00+0 N+ r- z 651 J �e e1 J "e Fp _ Lu,` A eRr' ¢ OJ me - � -y Z d _'e i., I' 0 '�[ 2 O /Z N+ _ese 0 ro-- I 0_ / 1 es°3 'ems N1,1: Z M in �s x (� W J N o ie-11° W 0 ,' Re n i J Q— z F a i j i-`_i -< am 0 X No- n e °! �� b 7,...„, ReipH 1 / 0 zo // U mo o I 9eHie 74 m e- !Kp O 1 .- ' V ! 1 11 0 22 ope-- e :' y e- 00+9 N+ Q r,jilfi I y I- + 00 I I Z 'mdn , --I- 0_ J O Z O J e w 0 m z o° ow v voW l nW W I— ,.'° I�Y 4� j <0O 0 I I o ...2 a .,1 U II .-r- ` U] .,a—r , 7 • j Z O 00+9 N+ + J ...=-;:::::111I — + 0 o nd o S aeea o x II w O 6 ci 6e Se' II Q"•._ , os-ids,, 4 g 6e 7- a w o ovNe -eg ! oe 'IT o a .1e11 s 00+01, N--I- 00+81. 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((f N O a }r, = U ..0 ' .1t Y i • , • :.....,,,I.:1-',- , �ski 7 ,Y I�� v, VI V/ f fl i Q YN 0 -.-' -0 � 4 ) d i0 O (/) Ci.IO QN fi ' '...r..,,'',.'; ', ' ' re,,4 4 © I0 , a_ a.) (.) , . 1 1-* 111P4‘11111itit`hi ' • , — 0 2 c all I- .i, ' , r•-t,,,K, 4,,,,,,,,o)# O 4) a) C CU a � O - C O 0,-1: k: '40 40,..,. aim • . ...., ... ` .,� .i V o rn o a;O co M ti ic. C s_ 217. 1.- �� .1111111111111. 3 ..cc a : 44 Y y . .fir ylitik , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: _ 06/27/15 Inspector: Johnnie Hill Operator: ConocoPhillips Alaska Inc Well Name: 1D-126 Oper.Rep: Perry Greenwood PTD No.: 198-108 Oper.Phone: Location Verified? Yes Oper.Email: If Verified,How? LAT/LONG Onshore/Offshore: Onshore Suspension Date: 06/19/10 Date AOGCC Notified: 06/25/15 Sundry No.: 310-163 Type of Inspection: Subsequent Wellbore Diagram Avail.? No Well Pressures(psi): Tubing 0 • Photos Taken? Yes IA 0 OA 0 SWAB AUG 192015 Condition of Wellhead: good and clean-wellhouse good shape Condition of Surrounding Surface - Location: good clean gravel/celler was lined with a liner Follow Up Actions Needed: none Comments: none Attachments: Photos(4) REVIEWED BY: Insp.Supry jn 1/,'j'i. Comm PLB 06/2014 2015-0627_Suspend_KRU_1D-126jh.xlsx • i A., „ + + f £ F P II 1 q F i * ., s:,,, .,,s It ey vD 1...1 .1v v V NI t::) tib; {,•• g f w. "4 O C g' p i rim ii t ir A A I 44 cn 04 cn �� ,.,.. 3cz) 0 /� $ + 3 f f s.. tog C/1 r:1-4 P-, tut ,A.,....,,,,,,, u" N O. ‘4%-'''''''''''1111 -tilt.. ' -:-4144. --Att.----, ' ,- „, ,,,. , ,.. , ..,,, - . ,,,,, • . ., . ., ,,,,,...... -.,, ,o, . , g' _ ._ , .►..,1., /t y ., +►`, �! , r Mie \ti ,`► a dam, .:;,--:;,:.,_, .,, „1/4k,k.L .• 4%. --..N- 41kW. 1 1\44 4A174.4&S, 4%0 4 ti.o. ' • v **710,, ,, , - ,. ri -s+ est. ts 404.. a. .'. � kirt‘k \NN ...4. '. , isti* � . * k‘ \ St*. V"' y ,,,tte.A.. A. ,,,- r''if ., ,,, ,,,k . 410i ' x U , b R, - .-'4:',":,.' ' for, 1 N .gyp, G.,- :. .. , b Vis* '` ~i fik sN N W , oO N ,. by O � N a Pages NOT Scanned in this Well History File XHVZE This Page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~ ~--//~ ~' File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: ~ Poor Quality Original - Pages: Other- Pages: DIGITAL DATA Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds [] Other COMMENTS: Scanned by~ildred Damtha Nathan Lowelt [] TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Dareth~well • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/28/10 Inspector: Bob Noble Operator: CPA Well Name: KRU 1D-126 Oper. Rep: Ian Ives PTD No.: 198 -108 Oper. Phone: 659 -7043 Location Verified? Yes Oper. Email: If Verified, How? rer (specify in commei Onshore / Offshore: Onshore Suspension Date: 06/19/10 - Date AOGCC Notified: 08/27/10 Sundry No.: 310 -163 Type of Inspection: Initial Wellbore Diagram Avail.? Yes • Well Pressures (psi): Tubing 100 Photos Taken? Yes IA 0 OA none Condition of Wellhead: Location verified with a plot plan. Wellhouse was removed for ongoing dirt work. All lines blinded with gauges. Lined cellar with a Iittk , Cellar also had a half drum that was in place to catch any fluid that might come from the open conductor. Mono -bore well. Condition of Surrounding Surface The pad looked good, they are in the process of doing gravel work. Location: Follow Up Actions None Needed: Attachments: Photos (2) REVIEWED BY: Insp. Supry U4(4 -(1 Comm PLB 08/2010 2010- 0828_Suspend_KRU_1 D- 126_bn.xls it Suspended Well Inspection — KRU 1D -126 PTD 1981080 Photos by AOGCC Inspector B. Noble 8 -28 -2010 I i %1 >� 6 10 4 , 1i .., i t `' � . ,. • ° : ' 7 4 Vv7r NO ""- 426 y s '; ' , .. , 114. �:. • +7 KRU 1D -126 Suspended Well Inspection 8 -28 -10 bn 1 I I �. d SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION C011I0IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 I Erik Q. Nelson Wells Engineer ConocoPhillips Alaska, Inc. 0 Nov 1 8 Zulu PO Box 100360 Anchorage, AK 99510 Re: Ku aruk River Field West Sak Oil Pool 1 D -126 P > Sundry Number: 310 -378 Dear Mr. Nelson: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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. Sj,e , o r a m sioner DATED this day of November, 2010. Encl. M � Conoc oPhillips Alaska 4 P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 N 1 2 2 010 i� & Gds Com C r u z �$h41l� c�;rraUV 11 November 2010 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner e Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to complete the partial P &A of Kuparuk Well 1 D -126 (PTD 1981080). -----> c a # 4 n — 3 . S 4j u i 4c . 1 D -126 was originally completed on 10 December 1998. The well was an ESP producer who was shut -in due to ESP failure on 07 December 2009. The well was due for a RWO to replace the pump in Q3 2010. On 26 March 2010 AOGCC was notified that this well had a leak in the production casing. The well was then loaded with 10.1 CaCI brine followed by a request to the AOGCC to pump cement shortly thereafter. This request was granted and cement was pumped into the perforations and up into the inner annulus and tubing. On 02 June 2010 ConocoPhillips received an approval on our Application for Sundry Approval and moved Nordic #3 onto the well on 14 June 2010 in order to execute the Partial P &A. During the RWO the rig tested the casing with a test packer in order to confirm integrity of the 7 -5/8" production casing. Those tests indicated we have a problem at the stage collar located at 2930' ✓ MD. We were able to hold pressure above this area but not after we moved the test packer below this point. In order to fulfill our commitment to suspend the well we need to confirm integrity of the 7 -5/8" production casing. On 20 July 2010 these events were communicated to Mr. Guy Schwartz. His response on 29 July 2010 confirmed the need for integrity in the 7 -5/8" - production casing and the need for a separate Sundry Approval. Our plan forward is to rig up a CT unit on the well in order to lay in a cement plug from the current - top of cement to — 50 ft above the suspected leak point at 2930' MD. We will then test the 7 -5/8" production casing to confirm integrity, The well is to remain in this condition as we evaluate future options such as slot replacement. If you have any questions or require any further information, please contact me at 263 -4693 or 903 - 7407. Sincerely, t ''. EnK Q.NelsorT °Y�y'r Wells Engineer CPAI Drilling and Wells - STATE OF ALASKA ALASIOIL AND GAS CONSERVATION COMMISA j V APPLICATION FOR SUNDRY APPROVALS f is lv 20 AAC 25.280 1. Type of Request: Abandon Rug for Redrill Perforate New Pool j" Repair well Change Approved Program C i'X� Suspend Rug Perforations Perforate Pull Tubing Time Extension Operational Shutdown Re -enter Susp. Well Stimulate After casing Other: t �.�.�� t-P ^X Sus. [.a• ".> 2. Operator Name: 4. Current Well Class: 5. Permit to Drifl Number: ConocoPhillips Alaska, Inc. Development r Exploratory 198-108. 3. Address: 6. API Number: Stratigraphic "" Service F P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 22889 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No fv- 1D -126 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25650 Kuparuk River Field /West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6716 4130 5560' 3055' 5070' 5089' Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121' 121' PRODUCTION 6650 7.625 6691' 4106' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): perforations plugged 3.5 L - 80 6011 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) no packer no SSSV 12. Attachments: Description Sunmary of Proposal ;✓ 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Development Service �l �D 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/22/2010 Oil Gas WDSPL Suspended 16. Verbal Approval: Date: WINJ GINJ WAG F Abandoned r Commission Representative: GSTOR SPLUG 17. 1 hereby certify that the foregoing e and correct to the best of my knowledge. Contact: Erik Q. Nelson @ 263 -4693 Printed Name Xrik Qf Wsor) Title: Wells Engineer f 'A Signature Phone: 263 -4693 Date Commission nl Sundry Number ,] ?/� Q Conditions of approval: Notify Commission so that a representative may witness r / V 1 Plug Integrity BOP Test Mechanical Integrity Test Location Clearance RECE Other: '' C)\ 2 0 10 Subsequent Form Required: 10-416 aka O il & Gas Cons. Copp& mot, Rtib�tQi��I� APPROVED BY Apfr1'D7� K(� =/ 4i COMWSIONER THE COMMISSION Date: r Form 10 -403 Revised 1/2010 O Submit in Duplicate • • 1 D -126 Temporary Abandonment Current Status: The well is currently shut in and secured with cement across the perforations and up into both the IA and tbg. The tubing was removed above this point and an IBP was set in the 7 -5/8" csg with — 50 ft of cement on top of it. A 3 -' /2 " kill string was run to 2410' MD. Scope of Work: Lay in a — 1940 ft cmt plug and PT 7 -5/8" csg to 2500 psi. General Well info: MASP: 1460 psi Reservoir pressure/TVD: 1823 psi / 3629' TVD Wellhead type /pressure rating: Vetco Gen I producer / 11" 5M CT Unit BOP configuration: Blind /Shear Combi — Blind /Shear Combi — Slip — Pipe Rams CMIT and MIT -OA results: Unable to MIT -OA due to csg leak Well Type: Shut -In ESP Producer Estimated Start Date: 22 November 2010 Production Engineer: Melissa Gangl RWO Engineer: Erik Q. Nelson Work: 263 — 4693 Cell: 903 —7407 E -Mail: Erik.Nelson @conocophiIlips.com Pre -Rig Work Request N/A Proposed Procedure: 1. MIRU SLB CT Unit 2. MU BOPE 3. MU CT connector, (x2) GLMBT, and full -bore wash nozzle 4. Stab injector head and lubricator onto BOPs. Function test BOPs and PT to 250/2500 psi 5. RIH circulating heated seawater at min. rate to — 4700' MD performing weight checks as needed. 6. Shutdown pumps and RIH to dry tag estimated TOC at — 4820' M D. PU to establish weight and RIH to re- confirm TOC. PU to pipe weight + 2 ft and begin pumping 15.8 lb/gal Class G cmt (— 86 bbls) while POOH to — 2880' MD. 7. After reaching 2880' MD pinch in choke to maintain — 150 psi on CT x csg annulus while pumping biozan contaminant down CT. Once biozan contaminant pill is out of nozzle chase it out of the hole w/ the CT to surface still maintaining — 150 psi on backside. Wash BOPs thoroughly before bumping up and moving on to next step. 8. WOC until lab suggests sample is at 500 psi compressive strength. 9. PT csg to 250/2500 psi and hold for 30 minutes. Chart and record test. -- Na eW-, 10. If csg passes move on to step #11. If csg does not pass, contact town engineer tediscuss. 11. Displace CT and surface lines to diesel 12. RDMO SLB CT Unit. Post -Rig Work: N/A S KUP 1 D -126 Cbl10 {?ill t W ell Attri butes ___ [Max Angle 8 MD TD "�"� , Wellbore APIIUWI Field Name Well Status Incl I') MD (ftKB) Act Btin (ftKB) A1c1;>ka.inC' 500292288900 [WESTSAK (PROD j 66.1914,217.98 6,7160 Last Conerran SLM� 5,139 0 [� 5 /30/ 0 ) 0 Rev Reason: V7� no tation End Date KB-Crd () Rig E D e Date lk rg 1q.1 7,yJ 1979930 AM -�� ORKOVE &A Imosbor 2/10/1998 wec SSSV NONE 10 8/7/2009 Last WO _ 6/20/2010 47.0 - _, Scheme9e Aelual , -, Annefatron D ftKB End Date Annotation Last Mod [End Date g: 711112010 P RODUCTION sin Strip s HANGER. 38 ` ing Descnption Strmg O . Stri g ID .. Top (ftKB) Set D pth (f... Set D pth (TVD) ... Str g Wt... String ... String Top Third » NDUCTOR 16 15062 4 2.0 121121.0 6258 H-00 WELDE in cnpt'on g Des String 0... Strmg ID .. Top (HKB) Set Depth (f... SetDepth (TVD) ... Str ng Wt... String String Top 75/8 6.750 41.1 6,6908 4105.8 29.70 L ABM - BTC Tubing Strings Tubing Description string 0... String ID Top (ft(B) Set Depth (f Set Depth (TVD) ... String Wt.. String g iString Top Th TUBING Kill Stnng 3 12 2 992 363 2,4100 1 592.8 930 L-80 EUE 8rd Completion Details Top Depth CONDUCrOR, � P p N n a2 -121 7 36.3 (WD) To Inc1 o ftKB' Commont ID (in) - (ft () Item Deacr tion 36.3 -0 40 HANGER Vetco Gray 11 4 112 CWCT Hanger 2 950 Tubing Description Str g O .. Stri ri g ID Top (HKB) Set Depth (f. Set Depth (TVD) _. String Wt... String ... St ring Top ThM TUBING Abandoned_[ 31/2_ [_ 15,890.9 1 6,.0114_ 3,4611_] 930 L80 1 EUE8rdABMOD C lletio_n Details I Top Depth _ -- - (TVD) Top Incl Nom To ftKB (ftKB) (°) Itwn Den sption � Comme _ -_ ID (111) 5,940.7 3,394.6 20.11 SENSOR Guardian Sensor @ 5,936' - 5,938' - 2.992 _ _ _._ 5,982 -5 3 433.9 19.92 INTAKE InFake, 2.992 5,987.2 3,438.3 19.90 TANDEM Upper and Lower Seal, Cement Plug, SEALS 4.820 ...____., _ - -. CMT Retainer, 6,001.0 3 451.3 19.83 GEARBOX - GRU, 52S, 9:1 5,070 6,002.0 3452.3 19.83 MOTOR ESP - Motor S7 hp, 1315V, KMHG 0.000 ___- 6,008.8, 3,458.7. 19.80!CENTRALIZER ESP Motor Centralizer 1.995 Other In Hole reline retrievable plugs, valves pumps, fish, etc) FISH. 5.089 - je� -. __ - TO De th - P P (rVD) Top Incl T fftK6) (ftKB ( Description Comment Run - D to ID (in) 5,070 2 732.5 63.29 CMT Retainer Cement Retainer 6/18/2010 5,089 2,742.8 60 55 FISH E -Line Logging Tool Stnng 6/16/2010 0 000 Pe tions & Slo shot ESP Top(rVD) Btm(TVD) Dens MAN SREL� T ftKB) Btrn ftKB) (flK8) (ftKB) Zone Date (sh° T e Comment 6,060 6,090 3,506.9 3,535.1 WS D, 1 D -126 9/22/1998 4.0 IPERF 0 deg phase, down :+ 6,122 6,142 3,566.1 3,584.8 WS B, 1D- 126 9/17/1998 4.0 IPERF 9 deg phased, orient down ' 6,222 6,234 3,659.9 3,6712 WS A3, 1D- 126 9/13/1998 4.0 IPERF 0 deg. phsing, 0 deg orient down SENSOR, - 6,239 6,256 3,675.9 3,692.0 WS A3, 1D-126 9/13/1998 4.0 IPERF Od e9 phasing, O deg orient down 5,961 6,288 6,318 3,722.2 3,750.6 WS A2, iD -126 8125/1998 4.0 IPERF 0 Deg phase, down Cement S ueezes JTop Depth Btm Depth (TVD) (ND) INrAKE, 5,983 -- T ftKB B1m (ftKB ("KB) (HKB) De-ri StWit Date Comment TANDEM 4.820.0 5,071.0 2,622.0 2,732- 91Cement Plug 6/19/2010 Pumped 11.4 bbls of Class G Neat cmt and lay balanced plug f/ 5,071' to 4,820' SEALS. 5.987 GEARBOi Notes: Generat & Safety 6,001 End Date Annotation 't 6 /1 812 0 0 8 NOTE: VIEW w /9.0 SCHEMATIC MOTOR, 6,002 - -- _ �_ 7/20/2010 NOTE: WELL P&A'd, KILL STRING IN PLACE CENTRALIZER, 6,009 I IPERF, 6,060 -6,090 IPERF, _ 6,122 -6,142 IPERF,_ 6,222 -6,234 IPERF _ -.. __.... -.... 6,239-6,256 IPERF, 6,288 -6,318 Cement Plug, 5,560 PRODUCTION, 41 -6,691 TD, 6,716 y Well: 1D-126 2010 PROPOSED COMPLETION API: 500292288900 Conductor: PTD: 1981080 16 ", 62.5 #, H -40 to 121' Wellhead: Vetco Gen I X -mas Tree: 3 -1/2 ", 5M Production Casina: Lift Threads: 4.909 MCA 7 -5/8 ", 29.7 #, L -80 to 6691' BPV: 3" T e'H' Proposed 3 %" Completion Perforations: • Tubing, 3'/ ", 9.3 ppf, L -80, MD Zone 6060'- 6090' D 8rd EUE 6122'- 6142' B 6222'-6234' A -3 6239'- 6256' A -3 6288'- 6318' A -2 EOT at 2410' RKB. New TOC placed by CT at - 2880' RKB 4 TOC from RWO at 4820' RKB 4 Top of IBP at 5070' RKB 4 Tubing Stub at 5891' RKB 4 ESP Mandrel at 5897' RKB ESP Mandrels: Cement pumped pre -RWO Type MD TVD KBMG (1 ") 5897' 3354' Directional: Max Incline: 66° @ 4218' Max Dogleg: 8.1 ° @ 5174' Last Updated: 11- Nov -10 TD: 6,716' RKB Updated by: EQN • • Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, July 27, 2010 4:28 PM To: 'Nelson, Erik Q' Subject: RE: 1 D-126 Continued Partial P&A -PTD# 1981080 Eric, Your proposal to place an additional cement plug as stated below is acceptable to the commission. This scope of work can be covered by the original sundry 310-163. Since you have submitted a 10-404 report for the Rig operations already another 10-404 (report of operations} will need to be submitted for the additional cement plug being laid in by Coil tubing. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) ~ T~ ~ ~~~~" 444-3433 (cell) ";~~~, ;''~~°~~"' .~~i From: Nelson, Erik Q [mailto:Erik.Nelson@conocophillips.com] Sent: Monday, July 19, 2010 4:34 PM To: Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; Gober, Howard Subject: 1D-126 Continued Partial P&A -PTD# 1981080 Guy, I'm sure you will see the 10-407 from the Partial P8~A RWO on 1 D-126 this afternoon or tomorrow morning. With regards to the status of the well we have performed a couple more diagnostics on the well and have monitored the tubing and IA pressures following the RWO which finished up on 19 June 2010. The well was left with the ESP completion and some 3-1/2" tubing from 6009' to 5129' MD then a E-line junk basket/gauge ring assembly on top of that. The rig then placed an IBP with it's top at 5070' MD. There is 250' of cement on top of the IBP and a 3-1/2" kill string was hung off at 2410' MD. During the RWO the rig tested the casing with a test packer and those tests indicate that our problem is at the stage collar at 2930' MD. We were able to hold pressure above this area but not after we moved the test packer below this point. Our plan forward on this well, in order to get a good pressure test on the casing, is to lay in ~ 2000 ft of cement with CT in order to cover up the stage collar and put a little squeeze to it. We'll then get a pressure test to satisfy the Partial P&A of this well. If you have any questions and/or comments please let me know. Q Erik Q. Nelson Workover/Wells Engineer ConocoPhillips Alaska, Inc. Office #I590 700 G. Street Anchorage, AK 9950I Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 7/27/2010 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ^ Gas ^ SPLUG ^ Other ^ OAAC 25.105^ 20AAC 25.110^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ No. of Completions: Developments. ^ Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: June 19, 2010 12. Permit to Drill Number: 198-108 / 310-163 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: June 22, 1998 13. API Number: 50-029-22889-00 4a. Location of Well (Governmental Section): Surface: 301' FNL, 599' FEL, Sec. 23, T11 N, R10E, UM 7. Date TD Reached: June 26, 1998 14. Well Name and Number: 1 D-126 Top of Productive Horizon: 2351' FNL, 707' FWL, Sec. 23, T11 N, R10E, UM 8. KB (ft above MSL): 70' RKB GL (ft above MSL): 40' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 2438' FNL, 519' FWL, Sec. 23, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): 2410' MD / 1593' ND West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 560491 y- 5959364 Zone- 4 10. Total Depth (MD + ND): 6716' MD / 4130' TVD 16. Property Designation: ADL 25650 TPI: x- 556535 y- 5957283 Zone- 4 Total Depth: x- 556348 - 5957195 Zone- 4 11. SSSV Depth (MD + ND): no SSSV 17. Land Use Permit: 468 18. Directional Survey: Yes ^ NoQ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost MDlTVD: 2468' MD / 1617' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): not applicable 22. Re-drill/Lateral Top Window MDlTVD not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE CEMENTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 121' Surf. 121' 24" 260 sx AS II 7.625" 29.7# L-80 Surf. 6691' Surf. 4106' 9.875" 190 sx ASIA LW, 330 sx Class G and 475 sx ASIA LW, 60 sx AS I 24. Open to production or injection? Yes ^ No a If Yes, list each 25. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/ND) 3.5" + ESP 5129'-6009' none perforations plugged ~;, 3.5" 2410'-surface none 5 ~+~+ ' `'' ~ ~~ `t) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF IJIATERIAL USED inflatable bridge plug @ 5070' MD cement plug from 4820' MD- 5071' MD 11.4 bbls of Class G 27, PRODUCTION TEST Date First Production not applicable Method of Operation (Flowing, gas lift, etc.) plugged Date of Test Hours Tested Production for Test Period -> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 28. CORE DATA Conventional Core(s) Acquired? Yes ^ No Q Sidewall Cores Acquired? Yes ^ No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. DECEIVED NONE RBDMS JUL 2 0,~~ ~.~11(_ ~ 2010 k Form 10-407 Revised 12/2009 CONTINUED ON REVERSE aQfIG~riginal only ?-z8-ro ~ ~ 28. GEOLOGIC MARKERS (List all formations and markers untered): 29. FORMATION TESTS Nf~ME MD TVD Well tested? ^ Yes ^~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 2468' 1617' needed, and submit detailed test information per 20 AAC 25.071. Top West Sak sand 6053' 3500' Base West Sak sand 6507' 3930' N/A Formation at total depth: West Sak 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Erik Nelson 263-4693 ~ i Printed Nam L. Alvord Title: Alaska Drilling Manaoer ~ f ~C~Y/2a/O ~ ~~ ~ phone 265-6120 Date Signature /8r INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 ~~, • KU P • 1 D-126 C~r1tKt3~1!{~1 $ '/ '~ ~, Well Attributes _ Max Angle & MD TD ~ :iw.3~ ~ Welltwre APWWI Field Name Well Status Inc! (°) MD (ftK6) Act Btm (kK8) _ _ // 500292288900 WEST SAK (PROD 66 19 I 4,217.98 6,716.0 Comment H2S (ppm) Date !Annotation End Date KB-Grd (ft) Rig R I ase Date w,a11p t~ tD-~zf nnufiw 7a~1 6AM SSSV. NONE 10 I 8/7/2009 Last WO: 6/20/2010 47.00 12/1017998 §d,e _eUC A51~iaL A noGbon Depth (HK81 End Date AnnoU[ion Last MOd ... E dDate Last Tag: SLM 5,139.0 5130/2010 Rev Reason: WORKOVER/P&A Imosbor _ 7/17/201.0 Casco Strin s _ HANGER. 36 - -- ! ^ ~"~ ~Cas~ng Description String 0... Sring ID ... Top (HKB) Set Depth (f_. Set Depth (ND) .. String Wt... Str rig ... String Top Thrd 'CONDU('l OR 16 15.062 42.0 121.0 ~ 121.0 6258 H-00 WELDED '~ I n .. String W[... Str rig '. String Top Thrd 9 9 9 P( P ( P PRODUCTIONou Str75/8 'S 6.750 ~~~ Tn 411) Se6,690h8f... Set D~ 1058D) 29.70 i L80 ~. ABM-BTC ail Tubing Strings Tubing Description Stang O._ 'Str rig ID ... Top (kK8) Set Depth (f... Set Depth (ND) ... String W[... Str rig ., ~. String Top Thrd ~~~ I UBING Kill String ~ 3 1!2 I 2.992 I 36.3 I. 2,470.0 ~ 7,592.8 9.30 I L-80 I EUE Srd Completion Details Top Depth (ND) T p l 1' N CONDUCTOR, _.. To kK8 (ftK8) () Ill Descnt C ent ID(n) 42-t2t P1 1 Plon 3fi 3 36 3 0 40'~ HANGER Vetco Gra 11' x 4 12 CWCT Han er ~~~ Tubin Des lion Strm 0... Strm ID ... T (ftK6) Set De th (i... Set De th ND Strin Wt... Srmg ._ Strin To Thrd TUBING Abandoned. 31/2 _ 2 992. _ I. n5,890.9 y 6,011.4 I 3 4617 ) ~ 9 30 _ L-80 ~ EUESrdAI 2.950 BMOD Completion Details __ __ _ Top Depth' - - -_--- (ND) I Top Intl Nomi... Top (ftK8) ~ (kK8) (°) Item Description Comment ID (in) _- - _- 5,940.71 3,394.6 20.11 SENSOR Guardian Sensor oQ 5,936' - 5,938' 2.992 ~ 5,982.5 3,433.9 79 92 INTAKE ESP -Intake, 2.992 5,987.2 3,438.3 19.90 TANDEM Upper and Lower Seal, cement Pmg, SEALS 4'820 6,001.0 3,451.3 19 83 GEARBOX GRU, 525, 97 CMT Retainer. _ s,mo ,_ 6,002.0 3452.3 19.83 MOTOR IESP-Motor 57 hp. 131Sv, KMHG 0.000 6,008.8 3458.7 19.80~CENTRALIZER ESP Motor Centralizer 1.995 .. _-_- /' Other In Hole (Wireline retrievable plugs, valves, Pumps, fish, etc.)_ _ FISH, 5.085 ~~. Top Depth (TVD) Top Inc! Top{ftK8) (kK8) (°) Description Comment ___ Run Date iID (in) 5,070 2,732.5 63.291,CMT Retainer Cement Retainer 6/18/2010 ~. 5 089 2,74281 GO.55'i FISH E-Line Logging Tool String 6/16!2010 0.000 Perforations 8 Slots __ - - MANDREL, Top (TVD) Btm (ND) D ^ s 5,89] Top (ftK8) Btm (kK6) (ftK6) (kK8) Iona Date (s Type Comment - 6,060 6,090 3,506.9 3,535.1 WS D, 1 D-126 9/22/1998 4.0 IPERF 0 deg phase, down _~~ 6,122 6,142 3,566.1 3, 584.8 WS B, 1D-126 9!17/1998 4.0 IPERF i9 deg phased, orient down r~`?- 6,222 6 234 3,659.9 3,671.2 WS A3, 1 D-126 9/1311998 4.0 IPERF '0 deg. phsing, 0 deg orient down SENSOR. - ~~ I s 947 6,239 6,256 3,675.9 3,692.0 WS A3, 1 D-126 9/73/1998 4.0 IPERF IO deg phasing, 0 deg orient tlown ~~~ I. 6,288' 6,318; 3,722.2 3,750.6 WS A2, 7D-126 8/25/1998 4.OIIPERF 0 Deg phase, down `` I Cem~ent Squeezes - TO kK8 Btm ftKg ITOp Depth Bon Depth I, INTAKE. 5,583 ,',; ., kK8 ftK8 I Description Start Date Com ent _ TANDEM n = ( i ( 1 Cement Plug 6/19/2010 Pumped 11 4 bbls of Class G Neat cmt and lay sEras, 5.567 4.820.0 5,071 0 2,622 0 2,732.9, balanced plug f/ 5,071' to 4 820' GEAReox, _ Notes: General & Safety _ ---- 6,001 ~' End Date Annotat on _ .__. _. '~' r 18,'2008 NOTE: VIEW w19.0 SCHEMATIC MOTOR. 6,002- 6 , - - - - -- --- I i 2012010 ~ NOTE: WELL P&A'd, KILL ST RING IN PLACE 6,009 U•;3.'~~: _.' IPERF, 6,060-6,090 IPERF, 6.122-6.162 IPERF. 6 222-6.234 IPERF, 6235-6 256 IPERF, 6,288-6,318 Cement Pluq, 5,560 PRODUCTION,- 41-6,691 TD, 6,71 fi ~onocoPhi[lips Time Log & Summary WeUvlew Web ReAORing Report -- - _ _ - __ Well Name: 1 D-126 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 6!14/2010 12:00:00 PM Rig Release: 6/19/2010 12:00:00 AM -- - - -- -- Time Logs Date From To Dur S. De th E. De th Phase Coe Subcode T Comment 6/14/2010 2a hr Summary MIRU. Kill Well. ND Tree. NU BOPE 11:00 14:00 3.00 MIRU MOVE MOB P Move Nordic Rig off of 1 D-03 and transfer rig mats to 1 D-126 Accept Nordic Rig 3 @ 12:00 hrs on 6-14-10 14:00 15:30 1.50 COMPZ MOVE RURD P Move rig over 1 D-126 and set down and berm up, Set auxilary equipment and tanks. Load pits with 10.5 ppg KWF 15:30 16:30 1.00 COMPZ WELCTL MPSP P PU and MU Lubricator and Lub out BPV and lay down Lubricator. TP = 190 si. IA = 0 si. 16:30 18:30 2.00 COMPZ WELCTL OTHR P RU hoses and Hard line from well to Kill tank. 18:30 20:30 2.00 COMPZ WELCTL CIRC P Circulate Well with 10.5 Ib/gal Brine at 3.0 bpm/300 psi. Pumped a total of 220 bbls. Monitor Well, dead. Blow down and ri down lines. 20:30 22:30 2.00 COMPZ WELCTL NUND P Se "BPV. Ni le down Tree. Inspect Tubing Hanger Threads. Install Blankin Plu . 22:30 00:00 1.50 COMPZ WELCTL NUND P Npple up BOPE. 6/15/2010 Complete BOPE Test. Pulled 5,073 ft of 3 1/2" Tubing w/ Heat Trace & ESP Cable. 00:00 03:00 3.00 COMPZ WELCTL NUND P Change Blind Rams. Complete NU BOPE. 03:00 08:00 5.00 COMPZ WELCTL PRTS P Perfo ini i I B PE test at 250/2,500 psi. The State's right to witness test was waived b J. Jones. 08:00 09:00 1.00 COMPZ WELCTL MPSP P Pull blanking plug and install Isolation sleeve. 09:00 09:30 0.50 COMPZ RPEOPI SFTY P Held PJSM with crane operator and rigger, along with rig crew on loading heat traces ooler and ESP s ooler. 09:30 10:30 1.00 COMPZ RPEOPI OTHR P Load ESP spooler and Heat Trace s ooler on ri floor with crane. 10:30 12:30 2.00 COMPZ RPEQPI CIRC P RU pump hoses to landing jt and MU landin 't. CBU 3 b m 300 si. 12:30 13:00 0.50 COMPZ RPEOPI THGR P BOLDS, Unland hanger @ 150k, pull to 150k and parted ESP cable and pull hanger to rig floor @ 75k up wt and 50k do wt. 13:00 15:00 2.00 COMPZ RPEOPI OTHR P Hang Sheave in derrick. Lay down landin 't. Page 1 of 6 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 15:00 18:00 3.00 COMPZ RPEQPI TRIP P POOH and string lines over sheaves. Removing Cannon clamps from cable. 18:00 23:00 5.00 5,073 0 COMPZ RPEQPI TRIP P CrewChange.PJSM,TestAlarm System. Continue POOH S/B 3.5" tbg w/heat trace & ESP Cable. 75k u wt / 50k Down Wt. 23:00 00:00 1.00 0 0 COMPZ RPEQPI SVRG P Secure ESP Cable & Heat Trace Cable on Spool. Clean Rlg Floor, SLip & Cut Drilling Line. Recover All Cannon Clamps. 35 -single cross cplg clamps 403 - 5' dual channel clamps 5 - 4' dual channel clamps 6 - 3' dual channel clamps 4 - 2' dual channel clamps 84 -dual cross cplg clamps 1 -heat trace shoe 1 - SS band 6/16/2010 MU & RIH w/ Bit and Scraper down to 5065'. MU 4AA CIBP on E-Line and RIH and set down w/CIBP @ 1,110'. POOH and layed down CIBP. MU and RIH w/ 6.75" OD gauge ring junk basket and set down @ 2,550', not able to worked passed. Recovered metal particles and small cmt rocks. Made 2nd run and made it down to 5100'. POOH and hung up on cement staging collar @ 2930' and pulled out of ropesocket and lost tool strin . 00:00 00:30 0.50 0 COMPZ RPEQPI PULD P Load tools f/ Scraper Run 00:30 02:30 2.00 COMPZ RIGMNT SLPC P Slip & Cut Drilling Line. Change Out One Brake Pad On Drum. 02:30 03:00 0.50 COMPZ RISER PULD P Attempt to set Wear Ring. Incorrect Wear Rin 03:00 03:30 0.50 COMPZ RPEQPI PULD P Make Up Bit & Scraper BHA. 03:30 05:00 1.50 0 5,065 COMPZ RPEOPI TRIP P Tripping in Hole W/ Bit & Scraper. 60k u wt, 50k do wt. 05:00 07:30 2.50 5,065 0 COMPZ RPEQPI TRIP P POOH w/ Bit & Scraper. 07:30 08:00 0.50 0 0 COMPZ RPEQPI OTHR P Load E line bops on rig floor 08:00 08:30 0.50 0 0 COMPZ RPEQPI SFTY P Held PJSM with HES, Baker and Rig crew 08:30 17:30 9.00 0 5,100 COMPZ RPEQPI ELNE P RU and MU Baker 4AA CIBP to # 20 _ setting tool and RIH to 1,110' set down. Continue to attempt to work down, couldn't get past 1,300'. POOH - No damage to plug. MU and RIH with 6.75" OD guage ring junk basket to 2,550' set down -not able to work past. POOH and recovered small .25" metal particles and small .375" cmt rocks. Make 2nd run with same, set down and hung up @ 2,900' -not able to pull out as of 15:20 hrs. Continue to work, able to work down to 3,150' as of 17:30hrs. Work Tools down to 5100' Page 2`of 6 r~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 17:30 20:30 3.00 5,100 5,090 COMPZ RPEQPI ELNE T Started POOH and tools hung up on the cement staging collar @ 2930'. Continue to work out of ropesocket. Worked out of rope socket and RDMO E-line. 20:30 21:00 0.50 5,090 5,090 COMPZ RPEQPI PULD T Started Rigging up Bit & Scraper to Push Lost tools to bottom. Receive call from town Engineer on New Plan Forward. Rlg down Bit & Scraper to let HES Slickline try and fish lost tool strin . 21:00 21:30 0.50 5,090 5,090 COMPZ RPEQPI SLKL T Hes Slickline on Location. PJSM with HES and Ri Crew. 21:30 22:00 0.50 5,090 5,090 COMPZ RPEQPI SLKL T MIRU Slickline Unit & Load Tool on ri floor. 22:00 00:00 2.00 5,090 2,890 COMPZ RPEQPI SLKL T RIH w/Slickline down to 5090' and Latched E-Line tools.PUH to tight spot @ 2890' and worked tool.Lost Tools after working several times.POOH and Check Overshot. 6/17/2010 Made several attempts to fish E-Line tools with no success. MU & RIH w/ Cement Retainer and set down @ 2920'. POOH and made up 6.75" Bit & Scraper and run thru area @ 2920' 3 times pumping @ 3 bpm, trip in to 5092' with no roblem.MU and RIH with HES E-Line and Lo ed w/ Cast-F from 5092' to surface. 00:00 03:00 3.00 2,890 5,090 COMPZ RPEQPI SLKL T RIH w/ 2.75" bell guide, 2.20 bell guide, and 1 3/8" JD. Sat down and latched tool string @ 5090' slm. Dragged up hole @ 80 fpm @ 1050 lbs. Hung up @ 2880' slm. Worked tools for 1/2 hour and fish fell off. Chase back down hole and relatch. Drag back up hole and hung up again @ 2880' slmd. Continue working tools, fish fell off again. POOH and RDMO Slickline. 03:00 03:30 0.50 0 0 COMPZ RPEQPI PULD P PJSM on Plan forward. MU 4AA " K-1"Cement Retainer. 03:30 04:30 1.00 12 2,920 COMPZ RPEQPI TRIP P Start Tripping in Hole w/ CIBP. 04:30 06:30 2.00 2,920 0 COMPZ RPEQPI TRIP P Set down w/ Cement Retainer @ 2920'. Discuss option with Town Engineer. Plan Forward is to POOH and Pick up 6 3/4" bit & scraper and Work Problem area. 06:30 11:00 4.50 0 5,092 COMPZ RPEQPI TRIP P PU and MU 6.75" Bit on 7 5/8 csg scraper assy and RIH to 2,920' and wash thru @ 3 bpm @ 70 psi with no rotation to 2,950', numerous times seen no drag. Continue to trip into 5,092' and seen li ht to . 11:00 13:00 2.00 5,092 0 COMPZ RPEQPI TRIP P POOH f/ 5,092' and lay down BHA. 13:00 13:30 0.50 COMPZ EVALWE SFTY P Held PJSM with HES E line and rig crew on Fast Cast to . 13:30 15:15 1.75 0 2,500 COMPZ EVALWE ELOG P RU E line sheaves and shooting nipple. RIH w/ faast cast logging tools .Page 3 of 6 i ~~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 15:15 18:15 3.00 2,500 0 COMPZ EVALWE ELOG T Lost Communication w/tool string. POOH. Trouble shoot. Rehead rope socket. 18:15 19:15 1.00 0 5,100 COMPZ EVALWE ELOG P RIH w/Cast -F tool string 19:15 23:00 3.75 5,100 0 COMPZ EVALWE ELOG P Log Repeat sectionand POOH while to in w/ CAST-F 23:00 00:00 1.00 0 0 COMPZ EVALWE ELOG P Rig down tool string, BOPE,Packoff, sheaves and surface a ui ment. 6/18/2010 MU & RIH w/ 3.375' IBP down to 5082', made several attempt to set IBP w/ no success. POOH and P/U another IBP and was to set IBP 5082'. POOH and P/U Test Packer and started testin Tubin & Annular. 00:00 02:30 2.50 20 5,082 COMPZ RPEQPI TRIP P MU And RIH w/IBP 02:30 04:00 1.50 5,082 5,082 COMPZ RPEQPI CIRC P On Depth with IBP (a2 5082'. Up Wt=60k Down Wt=50k.Drop 1/2" ball and let free fall for 20 mins. On line with rig pump @ 1 bpm @ 110 psi. Seen small pressure bump @ 30 bbls away @ 520 psi. come off line with pump and lost all psi. Let set for 5 mins. Back on line @ 1.25 bpm @ 180 psi. Pump entire tubing volume and still not building any pressure. Surge pump a few times, still not seein an ressure build u . 04:00 07:00 3.00 5,082 0 COMPZ RPEQPI TRIP T Start POOH. Seen overpulls off bottom with IBP.UP 62K Found ball on seat and inflate valve was shifted closed. IBP in sheared /released position. Send to Dead horse for evaluation and PU re lacement. 07:00 11:30 4.50 0 0 COMPZ RPEQPI OTHR T Removed ESP cable spool and heat trace spool while waiting for offsite equipment. Replacement -arrived @ 10:00 hrs. Continue crane o erations. 11:30 14:00 2.50 0 5,082 COMPZ RPEQPI TRIP T PU a_nd_MU 3.375" OD IBP with H_ydrualic release running tool. RIH to 5,082' on 3 1/2 EUE 8rd TBG. . 14:00 16:00 2.00 5,082 5,082 COMPZ RPEQPI PACK T drop ball and let fall. RU and pump ball into place @ 1 bpm @ 70 psi. Seen ball seat and pressure up to set inflatable plug. Increase pressure and release HRRT. RD circulating equipment. To of IBP 5,070'. 16:00 18:00 2.00 5,070 0 COMPZ RPEQPI TRIP P POOH with HRRT on 3 1/2 EUE 8rd TBG from 5,070' 18:00 18:30 0.50 0 0 COMPZ RPEQPI PULD P OOH. PJSM. UD Baker Setting Tool. Clean Ri Floor 18:30 20:00 1.50 0 200 COMPZ RPEQPI PULD P P/U Test Packer to rig floor & Rih to 200' 20:00 21:00 1.00 200 200 COMPZ RPEQPI PRTS P R/U Test Equipment. Set Test Packer & Test Tubing to 2500 psi.Tubing Failed, Lost 200 psi in 10 mins. Annular Passed 2500 si. Page 4 of 6 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 21:00 21:30 0.50 200 413 COMPZ RPEQPI PRTS P Release Test Packer & RIH to 413', Set Test Packer and RU Test Equipment. Pressure Up tubing to 2500 psi.Lost 200 psi in 8 mins.Annular Passed 2500 si. 21:30 00:00 2.50 2,907 2,907 COMPZ RPEQPI PRTS P Release Test Packer & RIH to 2907', Re-Set test packer. Ru test equipment and Pressure up to tubing to 2500 psi. Failed again, lost 200 psi in 10 mins. PT annular again to 2500 psi. Passed. Discuss Next o tions With En ineer. 6/19/2010 Complete ND BOPE. NU Tree and test at 5K. Pull Check Valve. Freeze Prote6t Well. Install BPV. Secure Cellar. Release Nordic Ri 3 00:00 hrs. RDMO. 00:00 01:00 1.00 2,907 3,000 COMPZ RPEQPI PRTS P Release Test Tool and Trip In Hole to 3000', R/U Test Equipment and pressure on Tubing to 2500 psi. Lost 100 psi in 10 mins. Pressure on Annular to 2500 psi and Pressure Fail off. Both Test Failed. 01:00 01:15 0.25 3,000 3,094 COMPZ RPEQPI PRTS P Consult W/ Engineer about last test depth. Release Test Packer and Dr'O~down passed Cement Stageing Collar to 3094'.Set testpacker and pressure up tubing to 2500 psi. Lost 130 psi in 10 min. Tested Annular to 2500 si. Both test Failed. 01:15 03:00 1.75 3,094 4,029 COMPZ RPEQPI PRTS P Release Test Packer and Trip in hole to 4029'. Set Test Packer and pressure up on tubing to 2500 psi. Only lost 20 psi in 15 min. Pressure up on Annular to 2500 psi. Pressure bleed off steady. Call it a good test on tubing and fail test on Annular @ 4029'. 03:00 04:30 1.50 4,029 0 COMPZ RPEQPI TRIP P Release Test Packer & POOH. No problem pulling test packer thru Sta a Collar. 04:30 05:15 0.75 0 0 COMPZ RPEQPI PULD P Lay down Test Packer.Pull Wear Rin . 05:15 06:45 1.50 0 5,071 COMPZ RPEQPI TRIP P RIH w/ 3 1/2" EUE 8rd TBG w/ cplg_. _. on bottom to 5,071'. 06:45 07:30 0.75 5,071 5,071 COMPZ RPEQPI OTHR P Spot cement equipment. 07:30 08:00 0.50 5,071 5,071 COMPZ RPEQPI SFTY P Held PJSM with ASRC, SLB and Nordic rig crew on pumping the 250' balanced lu . Page. 5 of 6 r~ F Time Lo s Date Fram To Dur S. De th E. De th Phase Code Subcode T Comment 08:00 10:30 2.50 5,071 4,813 COMPZ RPEOPI CMNT P RU cement equipment. Pump 13 bbl of fresh H2O, PT @ 250/2,500 psi. Mix and pump 11.5 bbls of 15.8 ppg Class G neat cement @ 2.7 bpm @ 250 psi ICP and 173 psi FCP. Displace with 3 bbls of fresh H2O. Swap over to rig pumps and displace with 34 bbls of 10.5 ppg Naar \ NaCI @ 3 bpm @ 110 psi. Monitor well - slightvac. Break off and POOH w/ 1jt, 2-4' pup jts and 7 jts to 4,813'. RU and reverse circulate @ 3 bpm @ 160 psi, seen less than 1 bbl cmt return @ first 41 bbl TBG vol and um ed another 41 bbls. 10:30 13:00 2.50 4,813 2,378 COMPZ RPEQPI PULD P POOH laying down 78 jts to 2,378' 13:00 13:30 0.50 2,378 2,378 COMPZ RPCOM THGR P PU landing jt w/ ISO sleeve, MU to Vetco Gray TBG hanger. MU to TBG strin . 13:30 14:30 1.00 2,378 37 COMPZ RPCOM HOSO P Drain stack, and land TBG hanger, RILDS. Back out landing jt w/ISO sleeve. Set BPV. 14:30 15:00 0.50 37 37 COMPZ RPCOM SFTY P Held PJSM on ND BOPE and Chan in rams with ri crew 15:00 17:30 2.50 37 37 COMPZ RPCOM NUND P ND BOPE, change Upper pipe rams to 2 7/8 x 5" VBR's, and Lower pipe rams to 5 1/2" Solid rams. Set Back BOP. 17:30 18:30 1.00 37 37 COMPZ RPCOM NUND P Install test plug, NU Tree. 18:30 20:00 1.50 37 0 COMPZ RISER PRTS P PT void & Tree to 5000 psi. Pull TWC 20:00 20:30 0.50 0 0 COMPZ STIM PULD P R/U LRS & Lines. 20:30 22:00 1.50 0 0 COMPZ STIM CIRC P PJSM W/LRS, Pump 103 bbls of Diesel down IA, R/D + Set BPV 22:00 23:00 1.00 0 0 COMPZ MOVE DMOB P Prep Rig To Move. 23:00 00:00 1.00 0 COMPZ MOVE DMOB P Clean up Well & Surrounding Area. Release Nordic three @ Midni ht.6/19/2010 Page 6 of 6 1 D-126 Well Events Summary DATE SUMMARY 5/30/10 PERFORM TUBING CUT USING .70" OD, HMX JET CUTTER. TAG TOC~5139'. FIRST COLLAR ABOVE TOC WAS 5109'. MADE TUBING CUT (c7 5129' (10' ABOVE TOC). PRESSURE FROM IA AND TUBING EQUALIZED AFTER CUT INDICATING TUBING CUT. 6/6/10 SET CATCHER.SET 1" DV @ 2422' RKB.PULL EMPTY CATCHER. ATTEMPTED TO BLED TBG AND IA TO 0 PSI. PUMPED 20 BBLS DOWN TBG, CONTINUED TO GET ENERGIZED FLUID UP IA. WILL RETURN IN A.M. TO BLEED GAS AND CONFIRM CIRCULATION. 6/14/10 ELINE UNIT 3030 PREP DAY: CHECK OUT TOOLS AND EQUIPMENT FOR UPCOMING NORDIC 3 RIG JOB. 6/16/10 ATTEMPTED TO SET CIBP IN 7.625" CASING AT 5100' BUT COULD NOT PASS 1400'. RAN JUNK BASKET WITH 6.75" GAUGE RING TO 2500', FOUND METAL AND CEMENT DEBRIS IN BASKET. MADE SECOND JUNK BASKET RUN TO 5100' AND GOT STUCK AT CEMENT STAGING COLLAR AT 2930' WHILE PULLING OUT OF HOLE. PULLED OUT OF ROPESOCKET PER COMPANY REP INSTRUCTION LEAVING TOO,LSTRING DOWNHOLE. 6/16/10 '**RIG JOB*** ATTEMPTED FISH E-LINE TOOLS. LATCHED FISH @ 5090' SLM, PULLED FISH TO TIGHT SPOT @ 2880' SLM, EST. 2930' RKB. UNABLE TO WORK TOOLS FURTHER. LEFT FISH @ 5090' SLM. S/L FISHING SUSPENDED. 6/17/10 PERFORMED CAST-F ACCOUSTIC IMAGING LOG FROM A DEPTH OF 5050' TO SURFACE TO INSPECT CASING INTEGRITY ELL LOG TRANSMITTAL • To: Alaska Oil and Gas Conservation Comm. Attn.:. Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Casing Inspection (CASE) /Advanced Cement Evaluation (ACE): Run Date: 6/17/2010 July 2, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1D-126 Data in LAS format, Digital Log Image files 1 CD Rom 50-029-22889-00 5" CASE Log (1:240) 1 Color Log 50-029-22889-00 ~ g 5" ACE Log (1:240) 1 Color Lo 50-029-22889-00 ""`E.~.~~''~ `~°`""` .H `` N 'y PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.ba .. ~ -~ ,; '~- ~ 7~~' Date: :~ ~~~~ /~~ ~ °~S3 Signed: r~~~~ ~~ '~;, - 1 PROACTIVE DIAfjNOSTIC 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 / MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road ~., ~~ , ~ r'~`ti~, ~ 4; ~,[~ t( Suite C `~~ ~ ~`~'~ Anchorage, AK 99518 Fax: (907j 245-8952 1 j MTT Report O1,Ju1-10 - 1 C-126 1 Report ----~ 50-029-22889-00 2J MTTReport O1,1u1-10 1C-131 1 Report 50-029-22891-00 19`6- ~ !A~- (~ 0 .~ ' ~: I ~ r~_ j ~~ ~ ~ ~r Signed : ~.. e ~.a. Print Name: ~``' .. - ~"''~ ,: ~: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : Odsanc~ocaae(a7sTaeITIOr+/log.~:ssres WEBSITE : www.l^nera®c4~Iotl.cCroT C:`SJocwnenLc and Settings\Diane Williams\D~ktop\Transmit_Conoco.docx • • Memory Magnetic Thickness. Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1 D-126 Log Date: July 1, 2010 Field: West Sak Log No.: 7425 State: Alaska Run No.: 2 API No.: 50-029-22889-00 Pipet Desc.: 3.5" 8rd Kill String 9.3 Ib L-80 EUE 8rd Top Log Intvl.: Surtace Pipet Use: Tubing Bot. Log Intvl.: 222 Ft. (MD) Pipet Desc.: 7.625" 29.7 Ib L-80 ABM-BTC Top Log Intvl.: Surtace Pipet Use: Production Casing Bot. Log Intvl.: 222 Ft. (MD) Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Log Intvi.: Surtace Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the second time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT}. The MTT responds to the total metal thickness of the 3.5" tubing, 7.625" casing, and 16" conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 20 fpm. COMPARISON TO PREVIOUS MTT LOG RESULTS A comparison of the current to the previous log run on this well (April 17, 2010) show similar intervals of significant metal loss feature over the interval 42' - 48'. A tubing string change indicated in the well bore schematic makes a direct comparison of the current and previous log impractical. INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval 0' - 222'. Changes in metal volume are relative to the calibration points at 58' and 112', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 3.5" tubing, 7.625" casing and 16" conductor pipe. A log plot overlay of the average overall metal thickness recorded by the 5Hz, 8Hz and 10Hz passes is included in this report. This plot indicates an area of up to 9% relative metal loss over the interval (42' - 48') for the 5Hz pass, and no relative metal loss is indicated in the 8Hz and 10Hz passes. Since the lower frequency magnetic signals are more capable of permeating metal further from the tool than the higher frequency signals, the response from the 5Hz pass is considered to be more representative of the relative overall metal loss from the outer concentric string(s) in this interval. A log plot of the entire 5Hz pass and an expanded log plot of ~ top 30' of the 5Hz pass are included in this report. Indications of general isolated metal loss are recorded throughout the majority of the interval logged in the 5Hz pass. A maximum 9% circumferential metal loss is recorded in the interval between 42' - 48' in the 5Hz pass. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 3.5", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. ' Field Engineer: Wm. McCrossan Analyst: HY. Yang & M. Lawrence Witness: P. eessette ProActive Diagnostic Serrices, Ine. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or {884) 565-9G45 Fax: (281) 565-1369 E-mail: P(>Sa~memor~log.com Prudhoe Bay Field Office Phone: ,907) 659-23G7 Fay: (907) >59-2314 1 ~ q~l- to`6 o~~~,wErrsA~ 5Hz, ~z and 10Hz Delta Metal Thi~iess Passes Overlay Q~ n~9 _ ~,. s ~ ~- -- ~.~~"' 1 D-126 July 1, 2010 PnoAcTivE Diny!vasric SEnviccs Database File: d:lwarriorldatalld-126 Quly 1, 2010}\overlay.db Dataset Pathname: overlay Presentation Format: overlay Dataset Creation: Fri Jul 02 23:16:40 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2010 (10Hz) (%) -50 Delta Metal Thickness 2010 (8Hz} (%) -50 Delta Metal Thickness 2010 (5Hz) (%) 0 -NUp ~omt _~_ ~ ~ i 5Hz Delta Metal Thickness Delta Metal 20 1 DHz Delta Metal Thickness Inverted Casing Collar {8Hz and 1 }--r-~ 4U ~-I--F-t 60 80 Bottom of 16" Conductor 50 50 50 100 t O 1~~ nEl[ Spin c~ ,s R~rded Magnetic Thickness L~Data - 5Hz Pass s 1D-126 July 1, 2010 P11°ACTIYE DIM1y NOSTIC SEAVICFS Database File: d:\warrior\data\1d-126 Quly 1, 2010)15hzpass.db Dataset Pathname: filt5hz Presentation Format: 18 Dataset Creation: Tue Jul 06 10:52:07 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (%) 50 1.8 MTTP01 11.8 0 Line Speed (ftlmin) -200 -7 MTTP12 3 i I i p -~ Pu 5" Collar a---~ Metal Thickness Tubing Jt. 1 20 3.5" Collar ~ .625" Collar 40 Metal Tubing Jt. 2 60 5' Tubing Jt. 3 80 625" Collard I Bottom of 16" ' Coilar~k;;~:..~; I~ ~ ~ ~ 100 • Tubing Jt. 4 120 r .625" Collar °~ 3.5" Collar 140 Tubing Jt. 5 5" Col 625" Collar Jt. 6 180 'Collar 2D0 625" Collar Tubing Jt. 7 Metal Thickness 220 -50 Delta Metal Thickness (%) 50 1.8 MTTP01 11.8 0 Line Speed (ft/min) -200 -7 MTTP12 3 o`~"'wE"s Funded 5Hz Pass Magnetic T~kness Log Data Q4 A~c7 H ~ s 1 D-126 July 1, 2010 Pn°Acrivc ~inynosric SFrtviccs Database File: d:lwarriorldatal1d-126 {July 1, 2010}lexpanded 5hzpass.db Dataset Pathname: SHzPass Presentation Format: 18 Dataset Creation: Tue Jul 06 11:57:39 2010 Charted by: Depth in Feet scaled 1:60 -50 Delta Metal Thickness (%) 50 1.8 MTTP01 11.8 0 Line Speed (ft/min) ~ -200 -7 MTTP12 3 I I I I _Hanger_ I _ I I I li 'li `I t I ! ! I I I I Pup --~ _ ~ - - i ~ - «J ,. 1 . ~ -a 3.5" Col lar ~ ' - ~: ~~ ~ _ _ _ D elta Met _ al T hickness l I ~ 5 ~ I ~ ~' -- 10 .~~~ `f Li S d n e pee .~> Tubing Jt. 1 ~ I - I 20 : r ~ -- , . ~ I t ~ - ~ 30 ~ f .~ i ~~ 3.5 " Collar ~~ -50 D elta Me tal Thick nes s (% ) 50 1.8 MTTP01 1 1.8 0 Line Speed (ft /mi n) - 200 -7 MTTP12 3 ~-~.s KUP r 1 D-126 ConocoPhiflips i II Attribtrtes Angle & MD TD i j 'J~e1lDOnr AR['U\M'I Heltl Hama 'Jde113 W+ hcl i°1 MDitt4'. B'I ;r•~m AC fttP: rftit 500292288900 'NEST SAK PROD 66.19 4,217.9 6,716. Comment ..qn H13 fppmY Cate is l rt Annohllon Bitl pb :.;. HBtrtl f, ) Rlg Releae6 I.tlft SS6V: NONE 1U 8A2U_._ Last WO: 520200 4700 12110lI9 ., Annotatlon Gp ~ f K BI Brtl De g .t Pnno on ~ La r Mod B/ Btd Cate ! Pltt Last Tag: BLM Rev Reasan: 5,139.0 5130 TAG TOC, GLV CIO, TBG CUT Imosbor 6!1120 Gasotg Strings ~~+Ing CU+snpnnn s ng rjO._ s ng lB _. Top( P:BI Se Dap4l it.. Set Cipih fTr 01... song l/vY.. String... String TOpT:~,~SaY CONDUCTOR 16 15.062 42A 121.0 121.0 62 ~8 H-00 WELDE ~ ,7 Ca dug CS+cnptlon 8 ng 04.. String lD... TopittP. B;r se Gep i(t.. Set 6rptl+fTl61... 541ng Jv .. sting ... sting TOpn:-~.flES PRODUCTION 7516 6.750 41.1 6,690.8 4,105.8 29.70 L-80 ABM-B Tubing Strings Tubing Ca coup on s ng cD._ stung lD... Top( 1<.Bi set Geptll (t... Set upm irrC!i... stung -vYY.. s ng ... string Tap Tt; ~;,;~ 1D-126312 Srtl N'll $[rin 312 2.992 -0.5 2,410A 1,592.8 9.30 L-S4 EUEBr Catnpletion Deta ils ~i1ai Top Tap [aptll ir:%Gi T~~p ncl tleml... I ttt B~ ittI~B7 Item Ca rcn bu n Comment ID Inl -0.S -0.5 0.00 Other Ht Hale reline retrievable Irlugs, va Mes, pum ps, fish, etc.) Edit coYPacTO P, ;~ rp repni ti r.l _ Tod, in<ol Tcp nel i ttt 9i rtt1~Bi [e lcn bon ~~omment Run Cab ID'In' 5,070 2,732.5 63.29 Cement 67182010 Retainer 5,089 2,742.8 60.55 E-Une Logging 6!762010 0.000 Toal 8[ring Rertorations 8 Slots Ada anm mp rr.;ni aim rn:n', I snot r~o, To ittP.61 Ittb:Bi ittb El ,ft6B ~. .one Oita i+n... T e =omment 6,060 6,09G 3,SG6.9 3,535.1 W S D, 1D-126 9Ye211998 4.0 IPERF Odeg phase, down 6,122 6,142 3,566.1 3,584.5 1k 'S 6, 1 D-126 9117/1998 4.0 IPERF 9 deg phased, orient down \\ 6,222 6,234 3,659.9 3,571.2 Y 4S A3, 1G-126 9/1311998 4.0 IPERF Odeg. phsing,Odeg arient down ~.\\~ 6,239 6,256 3,675.9 3,692.0 W 9.43, 1 D-126 9!1311998 4.0 IPERF O deg phasing, O deg orient down eemenl Plw. .~r+ 6,288 6,318 3,722.2 3,750.fi W SA2,iD-126 82SJ199S 4.0 IPERF GDeg phase down m ` ° F~~ Pc uR~: s o -. o Celnelrt Squeez es Tap C6p91 BEe Cgpal Btln iniDl fTJGi r: un LOeerro Ta 'ttP BI ittl~. Bi ittl~B~ ittl~: Ei ca+cn tlon Sort Cato ~-omment T°°I ~„~ 4,820.0 5,071.0 2,622.0 2,732.9 C ement Rug 6!192070 tamped 11.4bbls of Class G Neat cmt and lay balanced lu f/5,071'ta 4,820' 5,560.0 6,400.0 3,054.7 3,828.6 C ement Rug 3292010 Rxnped 48 bbL of 14.6 ppg P.FC cement across reG cut. erfwa[fons. Displaced cement with 42 bbls of 10.1 s•'=9 = g CaCI brine 8 1.5 bbls of diesel. Estimate TO C C~ "5560' M D tes: General 8 Safety I rtt7 Bid [a ~ cnna tlon 6!782008 NO TE: MEW wf9.0 SCHEMATIC ~P at1Yp P~ f~ ~ .^.EY~?1 P, 53e1 IYT!.F E, a.B3 T!.P9Ba CE1W^,5~ GE1PROk, 61101 WTOP,b~ ~ CEYTR!.LCEP, 61D9 ~~~c\rrY~ \• \\_ .`\ \` ` \\\\ \\~ ~ 6pEDfi,09a \Y ~ ~~,lJ ~ IP EP F, `~~~` ~ 6,I~v,ra .. .~~\~ .~~.~~. ` ~ IP EP r, ~~~~ ~~\\~\\~ IP EPr. \, ..~.,,,~, ~ ~ 6:.396 "35 ` \\`i ~ ~ IP EPf \ ~ . 6396,318 ;~, ~~~ aemenl Plea, 5,550 P eC16,G9: Te, 6,' Ib • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Jet Cutter Record: 1 D-126 Run Date: 5/30/2010 s June 10, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1D-126 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22889-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto halliburton com ~ ~ = <,~ ~ x:~ Date: ~~ ~~~ !~?~°~1~~ l9~s3~- Signed: a ~ ~, :~ e Page 1 of 1 f~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, June 18, 2010 10:28 AM To: 'Nelson, Erik Q' Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: 1 D-126 RWO: PTD# 198-108 and Sundry #310-163 Eric, You have captured our conversation. Sorry I did not get this message back to you sooner. I also got a call from Perry at Problem Wells regarding 1 D-126. Did you loose the EL toolstring in the well? This should not affect the ultimate plans so long as the tool string is on top of the completion equipment being abandoned in the well. Tom Maunder, PE AOGCC From: Nelson, Erik Q [mailto:Erik.Nelson@conocophillips.com] Sent: Thursday, June 17, 2010 3:01 PM To: Maunder, Thomas E (DOA) Subject: 1D-126 RWO: PTD# 198-108 and Sundry #310-163 Mr. Maunder, As requested per our phone conversation I am communicating the details of our situation and our plan forward for the continuation of our partial plug and abandonment of 1 D-126 (PTD# 198-108). As stated in the Application for Sundry Approval we stated our intent was to place a cast iron bridge plug (CIBP) in the well on top of the remaining lower completion which will remain in the well.. We have had some difficulty in getting the CIBP past a stage collar which was set in the 7-5/8" casing string to facilitate atwo-stage cement job on the original completion. It is our intention to run and seta 3-3/8" inflatable bridge plug (IBP) in place of the CIBP. We will test this IBP to the same 2500 psi that we stated we would test the CIBP to. In addition we will also be increasing the volume of cement placed on top of the plug to 250 ft instead of the stated 150 ft. If you concur that this adequately captures our discussion or if you have any questions and/or comments please let me know. Thank you for your time. Q Erik Q Nelson Workover~Wells Engineer ConocoPhillips Alaska, Inc. Office #I590 700 G. Street Anchorage, AK 9950I OfFce (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 k ~ ( i~ i. li `~~ ~,~ i~ 6/18/2010 • L~ Erik Q. Nelson Wells Engineer ConocoPhillips Alaska, Inc. ~~ ~ `l ~ ~~s f~ P.O. Box 100360 ;.%,, r.~~-~~ `~ ty~ ~ V V ~ ~ Q ZJ Anchorage, AK 99510 ' ~~ F Re: Kuparuk River Field, West Sak Oil Pool, 1D-126 Sundry Number: 310-163 Dear Mr. Nelson: 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair n.1 DATED this 2 day of June, 2010. Encl. STATE OF ALASKA • /'O (~ , ~~ ALAS~IL AND GAS CONSERVATION COMMISSS ~,~ (o~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED MAY 2 6 2010 1. Type of Request: Abandon -~ .~' Rug for Redrill ]~ Perforate New Pool j° Repair well 8$ 8 ~B~LWwt~lljt~11 1 Suspend ~y" Plug Perforations Perforate ~" Pull Tubing ~"'°', A~C~~rxtension (! Operational Shutdow n Re-enter Susp. Well ("" Stimulate "' Alter casing Other: ~`°° 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~~; ~ Exploratory ~`""" 198-108 3. Address: Stratigraphic "' Service """ 6. API Number: P. O. Box 100360, Anchors e, Alaska 99510 50-029-22889-00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS No 1D-126 9. Property Designation: 10. Field/Pool(s): ADL 25650 Kuparuk River Field /West Sak Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ff): Effective Depth ND (ft): Plugs (measured): Junk (measured): 6716 4130 5560' 3055' 5560' Casing Length Size MD ND Burst Collapse CONDUCTOR 79 16 121' 121' PRODUCTION 6650 7.625 6691' 4106' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): perforations plugged 3.5 L-80 6011 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) no packer no SSSV 12. Attachments: Description Summary of Proposal ~` 13. Well Class after proposed work: Detailed Operations Program ~° BOP Sketch "" Exploratory Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/1/2010 Oil Gas WDSPL Suspended ~ 16. Verbal Approval: Date: WINJ ~""; GINJ ~"" WAG Abandoned .• Commission Representative: GSTOR SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Erik O. Nelson @ 263-4693 Printed Name Erik Q. Nelso Title: Wells Engineer . ~ ~ ~ ~ ~~7 Phone: 263-4693 Date ~~ ~~ Signature ,~ '~ C mmi i n nl Sundry Number: ~~ ~- I on so that a representative may witness Conditions of approval: Notify Commissi / Plug Integrity " BOP Test ]T/ Mechanical IntegrityTest "" Location Clearance ~- asao psi ~3oP s~ Other: \ Subsequent Form Required: ~ ~ ^ ~ O.7 / / /, S~•G~TYt..+l: r gyn. a,~.;~. S 4- 5 e•~ , APPROVED BY / /~/ Approved by: COMMISSIONER THE COMMISSION Date: (,~ .Z~ Cv Form 10-4 ~ ~ •~' /a Submit in Du licate ~„ 0~2 ORIGINAL ::`~ ~ ~ s~~,~, ~.~~ `^ ~ - KU P - 1 D-126 C~~}~Q~j~`l~ j'~ Well Attrib t s ~ ,Max An le & MD jTD ~, , e _ / ( u g _ ` ~1 n '+ III ! Wellbore APVUWI Field Name ~ Wall Status Inc! ( ) MD (ftKB) Act Btm (HKBI ~ ~ . 500292288900 WEST SAK -_ 4,217 98 6 716 0 PROD 66.19 'C ment N25 (ppm) (Date SSSV: NONE 10 8!7!2009 ' Annotat on iEnd Date KB-Grd (ft) Rig Release Date 00 12/10!1998 Last WO: 5!20/2008 47 wen cob 1D-tzs an?1201 __ ng -~ Srhem@S AGpa . o ry s9 PM 'A otation Depth (ftKB) iEntl Date Annotation (- . Last Mod ... End Date Last lag- SLM 5,110.0 ~. 4/2/2010 IRev Reason lAG TOC, GLV C/O Imosbor 4/17/2010 CasingStnn s ~__ ~ _ --. C n Descr pt on Strm O._ Str n ID ... Top (ftKB) 9 9 9 Set Depth (t .Set Depth (ND) . String Wt .Str ng .. String Top Thrd FUINGER, 37- --- - ~' '-e, ('ONDUCTOR i 16 15.062 42,0 121.0 1210 62.58 H-40 WELDED t Casing Descr pt~on Skiing 0... String ID ... Top (ftKB) Set Depth (f .. Set Depth (ND) .. String Wt .. String - - String Top Thrd PRODUC I ION I 7 518 6.750 41.1 6,690 8 4 105 8 29.70 L 80 ABM-BTC_ Tubing Strings I Tubing Descn ption String 0... String ID ... Top (ftKB) I Set Depth ((... Set Depth (ND) . String Wt... Str ng String Top Thrd ^ ^ TUBING 3 1/2 2.992 37.2 6.011.4 3.461.1 9.30 L 80 EUE8rdABMOD CONDUCTOR, 42 121 HEAT TRACE,_ 50 ESP MANDREL, 5.697 SENSOR. 5.9x1 INTAKE. 5.583 TANDEM SEALS. 5,987 GEARBO%, 6.001 MOTOR, 6,002 IPERF. 6.060-6 G90 IPERF, 6.122-6,142 IPERF, 6,222-6,234 IPERF.__. __ 6.239-6.266 IPERF,- - _. 6.288-6.318 Cement Plug, 6,560 VSOR Guardian sensor@5,936'- AKE ESP-Intake, JDEM Upper and Lower Seal, aLS ARBOR GRU, 525, 9:1 TOR ESP -Motor 57 hp, 1316v, I ncl etm TIC ON JT 95 tleg phase, down deg phased, orient down deg. phsing, 0 deg orient down deg phasing, 0 deg orient dowr Deg phase, down Top ' - - - -~- Port Inc! OD Valva Latch Size (~) Make ~ Model (in) Sarv TYPe Type (in) i5.06 CAMCOKBMG 1 ESP OPEN 0.001 20.30 CAMCOiKBMG 11 ESP SOV BK-6 0.001 PRODUCTION, _ 41-6.691 TD. 6,716 • • ConocoPhillips ~~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 26 May, 2010 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 1 D-126 (PTD 1981080). 1 D-126 was originally completed on 10 December 1998. The well was an ESP producer who was shut-in due to ESP failure on 07 December 2009. The well was due for a RWO to replace the pump in Q3 2010. On 26 March 2010 AOGCC was notified that this well had a leak in the production casing. The well was then loaded with 10.1 CaCI brine followed by a request to the AOGCC to pump cement shortly thereafter. This request was granted and cement was pumped into the perforations and up into the inner annulus and tubing. The purpose of this workover is to continue with the suspension of 1 D-126 by removing the tubing a ove t e cement lu insta lin a cast iron n e u an acm a roxi - R ~~~~ ~~ ~ , p g g g p g p g pp d landed as a kill ~~~`" _~~~ -~-~:t( ~ cement above the plug. The existing completion tubing will then be re-run an ately 150 feet of ,~_ string. ,The well is to remain in this condition as we evaluate future options. ~ w. ~. ~ ~ . , .~ ~ ~ If you have any questions or require any further information, please contact me at 263-4693 or ~ ~ ~ j 903-7407. Sincerely, ~f~~.- En Q. Nelson '' "~ Wells Engineer CPAI Drilling and Wells 1 D-126 Temporary Abandonment Current Status:. The well is currently shut in and secured with cement across the perforations and up into both the IA and tbg. Top of cement was confirmed with a slickline tag at 5110' SLMD in the tbg. Scope of Work: Cut and pull existing 3-1/2", L-80 EUE AB-MOD 8rd tbg, install CIBP, place 150' of cement on top of CIBP, re-run existing tbg as kill string. ` General Well info: MASP: . Reservoir pressure/TVD: Wellhead type/pressure rating: BOP configuration: CMIT and MIT-OA results: Well Type: 1460 psi 1823 psi / 3629' TVD Vetco Gen (producer/ 11" 5M Annular /Pipe /Blind / Flowcross /Pipe Post cement MIT-T to 1500 psi passed Unable to MIT-OA due to csg leak , ESP Producer Estimated Start Date: 12 June, 2010 Production Engineer: Melissa Gangl RWO Engineer: Erik O. Nelson Work: 263 - 4693 Cell: 903 - 7407 E-Mail: Erik.Nelson@conocophillips.com Pre-Riq Work Request: l~`(~ . Sv ~~~ ~ Fluid- ack wellbore and CMIT TxIA to 4,000 si, MIT-OA to 1,000 si Power Jet cut 3-'/" L-80 tubin at ~ 5100' MD • PT Tubin & Casin ackoffs, function test LDS's and set BPV Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure: 1. Accept Rig, take on fluids, pull BPV, ensure well is dead. 2. Install BPV & blanking plug, ND tree, NU 11" 5M BOPE, function and PT to 250/2500 psi 3. Pull blanking plug &BPV, install side iso sleeve. RU ESP pulling equip, screw in landing jt, BOLDS's and pull to the floor, cut ESP cable and LD hgr 4. TOOH w/ remaining (5100') completion, standing back 3-1/2", L-80 EUE AB-MOD 8rd tbg,and spooling up ESP cable. 5. MU and RIH w/ csg scraper (7-5/8") on used 3-1/2", L-80 EUE AB-MOD 8rd tbg s~ ~ So7S M~ 6. RU HES E-line and run oriented caliper w/ GR. MU and RIH w/CIBP on E-line R MO HES E-line. 7. MU Full Bore Tension Set pkr on 3-1/2", L-80 EUE AB-MOD 8rd tbg. TIH to 500', set pkr, and PT CIBP. Proceed to locate csg leak upon'successful test of CIBP. 8. TIH w/ 3-1/2", L-80 EUE AB-MOD 8rd tbg and lay 150' cmnt plug on top of CIBP, PU and reverse circulate to clean up any remaining cmnt. WOC 9. Space out & land tbg hgr, RILDS, PT Tbg & IA, and LD landing jt 10. Set 2-way check, ND BOP, and NU tree & PT 11. Pull 2-way check, freeze protect, set BPV, Release Rig. Post-Riq Work: 1. Pull BPV 2. No other work planned at this time. ir.~z # ~- Conoco hillips 2010 RWO PROPOSED COMPLETION API: 500292288900 PTD: 1981080 Wellhead: Vetco Gen I X-mas Tree: 3-1/2", 5M Lift Threads: 4.909 MCA BPV: 3" Type 'H' . Tubing, 3%", 9.3 ppf, L-80, 8rd EUE Tyge MD TVD KBMG (1") 5897' 3354' Well: 1 D-126 Conductor: 16", 62.5#, H-40 to 121' Production Casing: 7-5/8", 29.7#, L-80 to 6691' Perforations: MD Zone 6060' - 6090' D 6122' - 6142' B 6222' - 6234' A-3 6239' - 6256' A-3 6288' - 6318' A-2 ~- EOT at - 4850' RKB. ~ - 150' cement plug ~ CIBP at - 5075' RKB •- Tubing Stub at - 5100' RKB ~ ESP Mandrel at 5897' RKB cement Directional: Max Incline: 66° @ 4218' Max Dogleg: 8.1 ° @ 5174' TD: 6,716' RKB Last Updated: 26-May-10 Updated by: EQN WELL LOG S TRANSM/TTAL PROAGi1VE DIAGNOSTIC SERVICES INC. U 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 Anchorage, AK 99518 Fax: (907) 245-8952 1) Magnetic Thickness Tool 17 Apr-10 2) f 9~-/D~ Signed Print Name: F2E~E9~~~ Date : MAY 1 ~ 2010 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : pdsanchorage(aamemorvlog.com WEBSITE : www.memorvlog.com 1x126 1 Report 50-029-21656-01 C:\Documents and Settings\Diane Williams\Desktop\1Yansmit_Conoco.doac • • Memory Magnetic Thickness Toot Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1 D-126 Log Date: April 17, 2010 Field: West Sac Log No.: 10625 State: Alaska Run No.: 1 API No.: 50.029-22889-00 Pipet Desc.: 3.5" 9.3 Ib L-80 EUE 8rd ABMOD Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.: 213 Ft. (MD) Pipet Desc.: 7.625" 29.7 Ib L-80 ABM-BTC Top Log Intvl.: Surtace Ft. (MD) Pipet Use: Production Casing Bot. Log Intvl.: 213 Ft. (MD} Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD) Inspection Type : Corrosive 8 Mechanical Damage /nsp+ection COMMENTS This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total metal thickness of the 3.5" tubing, 7.625" casing and 16" conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 20 fpm. ~ INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval 0' - 213'. Changes in metal volume are relative to the calibration points at 58' and 112', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 3.5" tubing, 7.625" casing and 16" conductor pipe. Three log passes at 5Hz, 8Hz and 10Hz were made over the log interval. A log plot overlay of the average overall metal thickness recorded by all three passes is included in this report. All three passes indicate a significant metal loss feature over the interval 42' - 48', with the 5Hz pass indicating 12% relative metal loss, the 8Hz pass indicating 7% relative metal loss and the 10 Hz pass indicating 3% relative metal loss. Since the lower frequency magnetic signals are more capable of permeating metal further from the tool than the higher frequency signals, the comparison of the responses from the three passes suggest the metal loss over this interval is associated with the outer string(s) of the concentric pipe. As such, the response from the 5Hz pass is considered to be most representative of the relative overall metal loss from the outer concentric strings in this interval. A log plot of the entire 5Hz pass is included in this report. A relative metal loss of approximately 3% is also indicated over the interval 60' - 73' in all three passes, and may represent an additional interval with less severe overall metal loss. A maximum 12% circumferential metal loss is recorded in the interval between 42' - 48' in the 5Hz pass. A maximum 3-4°!o circumferential metal loss is recorded in the interval between 60' - 73' in the 5Hz pass. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 3.5", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed Field Engineer: G. Etherton Analyst: HY. Yang /J. Burton Witness: C. Kennedy ProActive Diagnostic Services, Inc. / P.O. Box 1359, Stafford, TX 77497 Phone: (281) or (888) 555-9085 Fax; {281} 555-1369 E-mail: PDS~ memoryiog,com Prudhoe Bay Field Office Phone: (907) 559-2307 Fax: (907) 659-2314 l`~~-lad A o`~`" ""`s SHz, ~z and 10Hz Passes Delta IV~I Thickness Overlay Q4 ~c; F 1 D-126 April 17, 2010 Pn°AeTiv[ Oinynasric Seeviecs Database File: d:lwarrior\datal1d-1261overlay.db Dataset Pathname: overlay Presentation Format: overlay Dataset Creation: Wed Apr 21 11:07:12 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metat Thickness 2010 (5Hz) (%) 50 -50 Delta Metal Thickness 2010 (8Hz) (%) 50 -50 Delta Metal Thickness 2010 (10Hz) (%) 50 i ~~.,.~. :,•_ , s - _ __ .. ~ -- _4 20 Delta Metal Thickness 2010 40 Delta Metal Thickness 2010 60 Metal Thickness 2010 80 F~Bottom of 16" • 100 120 140 160 Delta Metal Thickness 2010 Thickness 2010 (1 Metal Thickness 2010 180 200 -50 Delta Metal Thickness 2010 (5Hz) (%) -50 Delta Metal Thickness 2010 (8Hz) {°I°) -50 Delta Metal Thickness 2010 (10Hz) (%} 50 50 50 A o`~"'wE"s 1 D-12~ecorded Magnetic Thickne~Log Data - 5Hz Pass ~ ~n~sG ~ ~--- "' {Surface to 213' April 17, 2010 Pf10ACT1VE ~IA4N°STIC SFNVICFS Database File: d:lwarriorldatal1d-12615hz down pass.db Dataset Pathname: SHzDn Presentation Format: 2 scale Dataset Creation: Wed Apr 21 12:35:57 2010 Charted by: Depth in Feet scaled 1:100 -50 Delta Metal Thickness (°!°) 50 2 MTTP01 (rad) 12 0 Line Speed (ft/min) 200 i Tree I ~ ~ Han er 9 i -6.8 MTTP12 (rad) 3.2 ~. -~ - g _ __ _ -~.~ ~....- - , , ~- - - _ - - - - -' -- - _. ~ - -~ _~ ~r _ ~ _ I ~ Pup i i ~ ~ , -=~ ~ _ - ~ _ - -J Line S pee _, , J .,~. _ - '`~.~. ~~ ~. 1 ~._ t '~ T bi Jt 1 : Heat ng . u 20 5 ~ ~:> Tra c elta Me I tal Thickness _ 'r _ t ~ M l _ ~ 1 ~ Tu bing Collar ~~ i Casing Co llar 40 12% Metal Loss i Tubing Jt. 2 :. ; s ~ KUP 1 D-126 II Attributes An le & MD TD } WNlbore APINWI FlNd Name WNI Status Ind (') (RItB) Ac[ tm (RKB) ! 500292288900 WEST SAK PROD 66.19 4,217.98 6,716.0 Commem H2S (ppm) Date Amotadon Entl Date KB-Grd ~ RIg Release Dale well cone:-t a v3trzotn t2:3a o9 M SSSV: NONE 10 8/7/2009 Last WO: 5/20!2008 47.00 12/10/1995 alema[ic-Aa a Areatatlon Deptl111U®) End ate Amo on Last MOd ... EndD e Last Tag: 6.185.0 9/10/1998 Rev Reason: PUMP CEMENT PLUG, COVER PERFS Imosbor 3/30/2010 Casin Strin s MANGER, 37 - = Casng Description String 0... String ID ... Top (RKB) Se[ Depth (r... Set Depth (TVD) ... String Wt... String ... String Top mrtl - CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H-00 WELGED Casing Descripdon S[nng 0... String b ... Top IRKBI Set Depm p... Set Depth 1... String Wt... String .,. string Top b PRODUCTION 75/8 6.750 41.1 6.690.8 4,105.8 29.70 L-80 ABM-BTC Tubin Strin s lubing Desalptlon String o... string ID ... rop Imce) set Depth IL.. set Deptn IrvDI ... snug wn... snng ... stung rop mm TUBING 31/2 2.992 37.2 6.011.4 3,461.1 9.30 L~0 EUEBrdABMOD Com letion Details Top Depth (TVD) lop lnd Noml._ Top (feCB) 1~8) (°) Item Description Canmert ID (in) 37.2 37.2 -0.39 HANGER Tubing Hanger. Vetco. 2.992 coNDUaoR. 5,940.7 3.394.6 20.11 SENSOR Guardian Sensor @ 5,936' - 5,935' 2.992 a2-tzt MEAT TRACE. 5,982.5 3.433.9 19.92 INTAKE ESP -Intake. 2.992 so 5,987.2 3,438.3 19.90 TANDEM Upper and Lower Seal, SEALS EsP 6,001.0 3,451.3 19.83 GEARBOX GRU, 525, 9:1 MANDREL, za22 6,002.0 3,452.3 19.83 MOTOR ESP - Mator 57 hp, 1315v, KMHG 0.000 6.008.8 3 458.7 19.80 CENTRALIZER ESP Motor Centralizer 1.995 Other In Hole reline retrievable lu s valves um s fish etc. Top DepN (ND) Top Md Top lmcB) 1~8) (°) DesWptlon Comment Run Dale ID pn) 50 50.0 -0.33 HEAT TRACE ESP HEAT TRACE ATTACHED @ 10' DOWN ON JT 95 5/28!2008 0.000 Pertoratlons 8 Slots sha Top (TW) Btm (TVD) Dens To B etm RXB (RKeI IKKBI zone Date (sh-- Commett 6,060 6,090 3,506.9 3,535.1 WS D, 1D-126 9/22/1998 4.0 IPERF Odeg phase, down 6,122 6,142 3,566.1 3,584.8 WS B, 1 D-126 9117/1998 4.0 IPERF 9 deg phased, orient down 6,222 6,234 3,659.9 3,671.2 WS A3, 1 D-126 9/13!1998 4.0 IPERF 0 deg. phsing, 0 deg orient down ESP 6.239 6.256 3,675.9 3,692.0 WS A3, 1 D-126 9/13/1998 4.0 IPERF 0 deg phasing, 0 deg orient down MANDREL. 5,997 6.288 6,318 3,722.2 3.750.6 WS A2, 1D-126 8/25/1998 4.0 IPERF ODeg phase, down Notes: General & Safe Entl Date Amdatlon 6/18/2008 NOTE: VIEW w/9.0 SCHEMATIC SENSOR, scat INTAKE.5983 TANDEM SEPLS, 5,987 GEARBOX, 6,001 MOTOR,6002 ~` CENTRALIZER 5,009 \~~\\. \\\\\ ~ ~~~~ \. z~~ ao~~` \~A ~;~ IPERF ~~\ ~\~- 6,oso~oso =`~\~~~\\_ - arc\\z.z„= ~~ ~~ ~~~ \c ~~~~c~\~ - ~\\. s ~PERE. s,tz~,taa IPERF, 6,7275 734 IPERF, fi,2395,256 Mandrel Details Top Depth Top Port (ND) Ina OD Valve Latch Slze TRO RUn Sht To B MKeI 19 IYtake kfidet Iln) Serv Type Type M1 IPSII Run Date Can... IPERF' 1 2,422.2 1.597.9 65.06 CAMCO KBMG 1 ESP DMY BK-5 0.000 0.0 5/29!2008 6 2ee5 ~t e 2 5,896.9 3,353.5 20.30 CAMCO KBMG 1 ESP SOV BK3 0.000 0.0 1/7/2010 She... CamarR Plug, 5,$6U PRODUCTION, 41-6,691 TD. 5,716 ~- ConocoPhillips Al,a.~., !I :. CASING /TUBING /LINER DETAIL Tubinrr or Liner DescN~tton i D-126 ARCQ Alaska, Inc. DATE: 1112t319s Subsidiary of Atlantic RidniaM Canosnv 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH CenMtKt TOPS Note: 190 tlat bands 62 LaSalle Clam 3 ProtectorlfzerS on pump Raychem Heat Trace -3016' Note: 1 Heat Trace End Shoe 6' 470 Heat Trace Flat Guanis 6' 30 Heat Trace Flat Guards 4' 23 Heat Tree Flat Guards 3' 1524 Flat Bands FINAL CON~t.ETION RIG FLOOR TO LDS -Parker 24a~ 38.80 HGR ABB Vetoo G Tubing Hanger w/3-112" L-80 EUE 8rd Mod pup ' . 5.40 36.80 PUP'S 3-1/2" EUE 8rd AB MOD Spaceout 1-8.10 & 1 - 4.10 12.20 42.20 Jts S -169 3-112" EUE 8rd AB MOD tubing 5831.33 54.40 3-1/2"x1" CAMCO 'KBMM' GLM 5.39"OD - 2.86T'ID 6.70 5885.73 Jts 1t1~2 3-112" EUE 8rd AB MOD (full ' ) 63.28 5892.43 3-112" EUE 8 rd AB MOD 3paceout Pup 3.5"OD - 2.~"ID 10.17 5955.71 3-1/2" EUE 8 rd AB MOD Handlln Pup 3.5"OD - 2.99"ID 10.17 5965.88 Slotted Nipple 3.50" OD - 2.992 ID 3.00 5976.05 3-112" Tubing TTC Crossover 3.50" OD - 2.992" ID 1.51 5979.D5 ESP Tandem Seat GSB3 DB IL H6PFS 13.80 5980.56 ESP Gear Reduction Unit 8:1 525 Series 1.31 5994.36 ESP Motor 57 HP 1315126 KMH 6.86 5995.67 ESP Motor Centralizer .50 6002.53 6003.03 Note: Raychem Heat Trace attached X10' down on jt 93. Note: 80T Outside Sen G e attached to mzidle of 2nd 10' pup Remarks: String Weights with Bkx~rs: 75K# Up, 30iC# Dn, 81C# Blocks. Ran 188 joints of tubing Drifted tubing GLMs, >i hanger with 2.867" pisstlc rabbit. used Arctic Grade API Modifie . d t~lo Lead thread compound on aN cortnecuont:. i'uWng is non-coated. Nordic R~ #2 Drtlling Supervisor. M.C. HE1M L CASING / TUBING i LINER DETAIL 1D.12s Tubina or L1ner Descdat~an pA~; 17/2$/98 oRC~ Alaska. inC. ~ DF 2 pAt3E5 RECEIVED APR ~ 9 2010 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION LETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ~ Gas ^ SPLUG ^ Other ^ Abandoned ^ Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WAG ^ WDSPL ^ No. of Completions: 1b. Well Class: Development ^ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska; Inc. 5. Date Comp., Susp., or,4band.: April 3, 2010 12. Permit to Drill Number: 198-108 / 310-100 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: June 22, 1998 13. API Number: 50-029-22889-00 4a. Location of Well (Governmental Section): Surface: 301' FNL, 599' FEL, Sec. 23, T11N, R10E, UM 7. Date TD Reached: June 26, 1998 14. Well Name and Number: 1D-126 Top of Productive Horizon: 2351' FNL, 707' FWL, Sec. 23, T11 N, R10E, UM 8. KB (ft above MSL): 70' RKB GL (ft above MSL): 40' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 2438' FNL, 519' FWL, Sec. 23, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): 5560' MD / 3055' ND West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 560491 y- 5959364 Zone- 4 10. Total Depth (MD + ND): 6716' MD / 4130' TVD 16. Properly Designation: ADL 25650 TPI: x- 556535 y- 5957283 Zone- 4 Total Depth: x- 556348 - 5957195 Zone- 4 11. SSSV Depth (MD + ND): no SSSV 17. Land Use Permit: 468 18. Directional Survey: Yes ^ No a (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost MDlTVD: 2468' MD / 1617' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): not applicable 22. Re-drill/Lateral Top Window MD/TVD not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE CEMENTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 121' Surf. 121' 24" 260 sx AS II 7.625" 29.7# L-80 SurF. 6691' Surf. 4106' 9.875" 19o sx ASIII LW, 330 sx Class G and 475 sx ASIII LW, 60 sx AS 1 24. Open to production or injection? Yes ^ No 0 If Yes, list each 25. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 6011' none perforations plugged 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ~, q ~^~ =• ~ ~ ~, }~;-' t ~ :~, cement plug @ 5560' 48 bbls of 14.6 ppg RFC cement 27. PRODUCTION TEST Date First Production not applicable Method of Operation (Flowing, gas lift, etc.) plugged Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 28. CORE DATA Conventional Core(s) Acquired? Yes ^ No 0 Sidewall Cores Acquired? Yes ^ No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 12/2009ABDAAS APR 2 9 X10 CONTINUED ON REVERSE ~ y, z 4, ,O Submit original only ~~~~/~ 28. GEOLOGIC MARKERS (List all formations and markers a untered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes ~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 2468' 1617' needed, and submit detailed test information per 20 AAC 25.071. Top West Sak sand 6053' 3500' Base West Sak sand 6507 3930' N/A Formation at total depth: West Sak 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: B. Seitr @ 265-6961 Printed Name B. Seitr Title: Supervisor. Kuoaruk Engineerino Date -~" Phone 265-6961 /q~~'> l ~7 ~~® Si ~ gnature INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool Item 23: 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 1 D-126 Well Events Summary • DATE SUMMARY 3/26/10 Pumped 10.1 ppg CaCI kill weight f uid down the tubing to the perfs, circulated KWF down the tubing and up the IA to surface. Shut in press 0 psi on the tubing and IA. Pumped 200' of diesel freeze protect down the tubing and IA. Pumped a total of 406 bbl of 10.1 CaCI with 300 bbl of returns. 3/30/10 PUMPED 48 BBLS OF 14.6 PPG RFC CEMENT ACROSS THE PERFORATIONS. DISPLACED CEMENT WITH 42 BBLS OF 10.1 PPG CaCI BRINE AND 1.5 BBLS OF DIESEL. ESTIMATE TOC @ 5560' MD. 4/2/10 TAGGED TOC @ 5110' SLM. TESTED TBG TO ZERO, PASSED. MIT TBG 1500 PSI, PASSED. TESTED IA TO 20 PSI, GAINED 10 PSI IN 45 MIN. CALLED TO RIG JOB. IN PROGRESS. 4/3/10 PULLED DV f/ 2422' RKB. READY FOR LRS. 4/3/10 CIRCULATED 118 BBLS OF 10.1 PPG CaCI BRINE THROUGH OPEN MANDREL @ 2422' RKB. FREEZE PROTECTED WITH DIESEL DOWN TO 200' ON BOTH TBG AND IA. JOB COMPLETE. 4/17/10 GAUGE TBG TO 2.845" TO 550' SLM. RUN 3 MTT LOG PASSES FROM 220' TO SURFACE & BACK @ 5hz/ 8hz/ 10hz. OBTAINED GOOD DATA. JOB COMPLETE. 4/19/10 (AC-EVAL) SCLD- IN PROGRESS. NO FLUIDS TO SURFACE 4/20/10 SCLD--INCONCLUSIVE, NO FLUID TO SURFACE ~' ~ ~ ~, K UP 1 D-126 r t]t,, ~OCIQCi3rl t1~~Ip5 If ~~ ,Well Attributes Max Angle 8~ MD ~TD ~ ,°,Ki. 1 Wellhore API/UWI Field Name Well Status Inc! (") MD (ftK8) ( (Act Btm (%KB) - f 500292288900 (WEST SAK PROD 66 I9 4,217.98 6.116.0 IC nt IH25 (ppm) Date Annotation End Date ~KB-Grd (H( Rig Release Date _ SSSV. NONE ! 10 ( 8/7/2009 (Last WO' S/20p008 47.00 12/10!1998 M wen,c n6g 10 1zs,3r3'no1612.3a: 9 _ Schematic Ac1ua1 A notation iDe h ftK8 End Date ) Annotation Last Mod ... End Date 9/10/1998 (Rev Reason: PUMP CEMENI PLUG, COVER PERFS Imosbor 3/3012 0 1 0 last Tag- 6,185.0 1 ( ~ SV1o g3 g C IShm S O"' ~~ (t Sef De D L.. St n9-. Pt ) Set ~ Top JString Top Thrd , HANGER, 37- ' _, '.S ONDUI ,( ~ 1S 062 ~ 12 i 62 ~ 12110 H 40 420 WELDED I Casing Description St ing 0... (String ID Top (ftK8) Set Depth ((..- Set Depth (ND) Sf ing Wt... iSt 'ng . S[ring Top Thrd PRODUC I ION 7 518 6.750 41.1 6.690-8 4.105 8 29.70 L-80 ABM-Bl C Tubing Strings y Tubing Description SeI Depth (ND) String Wt... SI ng ... Set Depth (f..- Skiing 10 _..Top (ftK8) I. String 0... 1, 'Siring Top Thrd TUBING 2.992 3112 ' ( I 372 6,011.4 3 461-1 93U L 80 I EUEBrdABMOD Completion Det ~ ails To D t P P ;,: ':~ ~ i (ND) ~ TOp lncl Nomi.. 3 ~ i To ftK8 (HK6) P( (°) Item Descriph on Comment _ I ID (n( 7 37.2 0 39 HANGER Tubing Hanger Vetco, 2.99: conlDUCroR, 42-12° 5,940.7 3,394.6 20.11 SENSOR Guartllan Sensor @ 5,936' - 5,938' 2.99: Hear rzncr,. ' sa 5,9825 3,433.9 19.92 INTAKE ESP -Intake, 2.99: 5,987.2 3,438.3 19.90 TANDEM (Upper and Lower Seal, SEALS =s' i 6.001.0 3,451.3 19.83 GEARBOX 1~GRU, 525, 9'1 MAN JREL. - 2,a22 6,002.0 3,452.3 19.83 MOTOR _ ESP -Motor 57 hp. 1315v, KMHG ~I 0.00( ' ~ 6,008.8 3,458.7 19.80 CENTRALIZERESP Motor Centralizer 1.99` ~'I I ~ Top (ftK8( 50 (TVD) (ftK8( 50.0 Top Intl (°) Description -0.33 HEAT TRACE Comment ESP HEAT TRACE ATTACHED @ 10' DOWN ON JT 95 Run Data ID (in) 5/28/2008 0.00( ~ Perfora tions & Slots i _ j Shol I 1 Top (TVDI B[m (TVD(i Dens Top (ftK8( Bim (ftK8) (ftK8) (ftK8) Lone ~ ~ Date (ski", Type Comment - 6,060 6,090 3,506.9 3,535.1 WS D, 1D-126 19/22/1998 4.0 IPERF 0 deg phase, down : ~ 6,122 6,142 3,566.1 3,584.8 WS B, 1D-126 19/17/1998 4.0 IPERF 9 deg phased, orient down , ~ 6,222 1 6,234 3,659.9 3 6712 WS A3, 1 D-126 9/13/1998 4.0 IPERF I O deg. phsing, O deg orient down EsP MANDREL. ~ 6.239 6,256 3,675.9 3,692.0 WS A3, 1 D-126 9/13/1998 4 0 IPERF 0 deg phasing 0 deg orient down _ _ s.ew '-$ '1 6.288 6,318 3,722.2 3.750.6 WS A2, 1D-126 8/25/1998 4 0 IPERF IO Deg phase, tlown 'I r° Notes: General & Safety .,~ 9 "` End Date Annotation _ - _. '~ ``' 6/18/2008 NOTE~VIEW w190 SCHEMATIC SENSOR, _ -_ _ 5,541 ., .. INTAKE. 5,983 TANDEM SEA15. 5.967 GEARBOX, _ _ 6.001 MOTOR, 6,002 ;EMRALIZER, _ 6,009 IPERF, 6,060-6,090 IPERF 6.1226.142 IPERF, 6,222-6,236 IPERF, 6.235-6.256 IPERF, -_ - 6,288-6,318 Cemem Plug. 5.560 PRODUCTION, 41-6,651 TD. 6,716 -'.'Yf%. 4 • • ~~Q~~ 0~ Q~Q~~(Q /~..a~E..~~.~,. Perry Klein Well Integrity Supervisor ConocoPhillips Alaska, Inc. ~ f~,,,;~~~_~- ~; 1~'' ~ ~= z' ~ ~ ° ~ ~ P.O. Box 100360 ~"~ Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1 D-126 Sundry Number: 310-100 Dear Mr. Klein: 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of April, 2010. Encl. STATE OF ALASKA ~ lQ ~~~~'~~~ ALA OIL AND GAS CONSERVATION COMMIS t) APPLICATION FOR SUNDRY APPROVALS ~1~~',x~~APR 0 ~ 201Q -r1~ k•i, •~0 20 AAC 25.280 ~' 1. Type of Request: Abandon r Rug for Redrill r Perforate New WG r Repair well r iII~S Suspend rt/ Rug Perforations Perforate r Pull Tubing r lion r Operational Shutdow n r Re-enter Susp. Well ~ Stimulate ARer casin r g r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development ,~ Exploratory ~ 198-108 , 3. Address: Stratigraphic ~ Service r 6. API Number: P. O. Box 100360, Anchors e, Alaska 99510 50-029-22889-00 7. If perforating, Gosest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r ~ 1 D-126 9. Properly Designation: 10. Field/Pool(s): ADL0025850 Kuparuk River Field /West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 6716 4130 Casing Length Size MD ND Burst Collapse CONDUCTOR 79 16 121' 121' PRODUCTION 6850 7.625 6691' 4106' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6060-6090' 6122-6234' 6239-6318' 3507-3535' 3565-3671' 3676-3751' 3.5 L-80 5983 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) INTAKE -ESP -INTAKE, MD= 5983 ND= 3434 TANDEM SEALS -UPPER AND LOWER SEAL, MD= 5987 ND= 3438 GEARBOX - GRU, 525, 9:1 MD= 6001 ND= 3451 MOTOR -ESP -MOTOR 57 HP, 1315V, KMHG MD= 8002 ND= 3452 CENTRALIZER -ESP MOTOR CENTRALIZER MD= 8009 ND= 3459 12. Attachments: Description Sunrrnry of Proposal r 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch (- F-~Wloratory r Development ~ Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil ~. fiGas r WDSPL r Plugged ('" 18. Verbal Approval: yeg Date:3/30/2010 WINJ I GINJ r WAG r Abandoned r Commission Representative: Guy Schwartz ~~ ~ GSTOR r SPLUG r 17. 1 hereby certi ing is a rrect to the best of my knowledge. Contact: Perry Klein / MJ Loveland Print me Per ein Title: Well Integrity Supervisor, Projects Signature Phone: 859-7043 Date 3/30/2010 C i I Sundry Number. ~~ O ` lOO Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test [" Mechanical Integrity Test r Location Clearance r Other: ThSpGC~r'e-~ S per ZQ ~~L 25. /~~C~, Subsequent Form R wired: ~~ . !~/Q'T APPROVED BY /~ `7 `~'~ Approved by: COMMISSIONER THE COMMISSION Date: C)f? Form 10-403 Revi~ APR 0 9~Z~0y~y~ p R 1 G I N A L /' - c/ 7 ~a Su6m~i 'n Du~li/~to ~ ConocoPhillips Date: Subject: From/Location: Telephone: To/Location: Network Number: Background: 03/29/10 1 D-126 Cement Plug Nezaticky / Senden 943-1253 / 943-1174 Central Wells Group 10259601 • Interoffice Communication File code: NSK-69 Activity: ZX-52 1 D-126 is a single annulus ESP packerless completion. The singe casing barrier failed allowing well bore fluid to flowing'up the casing x conductor annulus. CaCI brine (10.1 ppg) was bullheaded into the perfs and then circulated up the IA. The well was shut in with 0 psi on the tubing and IA. After ~10 hrs the well head press began to climb (avg ~ 5 psi/hr). Cement will be pumped to cover the perfs Job Objective: Plug wellbore with cement. Well Status: Shut-in full of 10.1 ppg CaCI with 200' of diesel freeze protect. Pressure building on tubing and IA. Procedure: Pumping *Close production master and IA recirculation line before pumping* 1. Pump 10 bbl of CaCI down the IA taking returns off the tubing (remove gas cap and 2 bbl of diesel freeze protect in the tubing) 2. Pump 52 bbl (tbg vol) of 10.1 ppg CaCI brine down the tubing taking returns up the IA. Shut in IA and bullhead 20 bbl brine. 3. Open IA and circulate 250 bbl of brine down the tubing and up the IA to kill well (IA vol = 204 bbl from pump intake). 4. Bullhead 28 bbl of diesel down the IA for 200' freeze protect at job completion. SI IA. 3/30/2010 • 5. Mix and pump 160 sx (43 bbl) of cement per attached SLB cement pilot test as follows: a) Bullhead 75 bbl of fresh water down the tubing. After 55 bbls pumped, open IA and allow 10 bbls of diesel returns for fresh water spacer in IA. b) Shut in IA and bullhead cement slurry down tbg. c) Launch nerf plug and displace w/ 5 bbl freshwater and 32 bbl of 10.1 ppg CaCI brine. • d) Open IA for returns and pump 10 more bbl of brine and 1.5 bbl of diesel taking 11.5 bbl of returns. (TOC in IA and tubing @ 5560') *Open production master and IA recirculation after cement job with SSV closed to monitor pressures on Setcim* 6. WOC for 24+ hours, bleed tbg & IA pressure to 0 psi and monitor. 3/30/2010 I~WSR Historical -FILE COPY 1 D-126 • Job: Ann-Comm Report Date: 3/26/2010 Unit: LRS PUMPING 44 Nezaticky, Peter -CPAI, Wells Supervisor WO: API / UWI Field Name 5002922889 WEST SAK Well Type Original KB/RT Elevation (ft) Well Status Legal WeIlName Development 111.30 PROD 1 D-126 JOB Actual Start Date End Date Secondary Job Type Primary Wellbore Affected 3/26/2010 15:00 3/26/2010 22:00 ZX03 Pumping /Load Well 1 D-126 NETWORK Primary Job Type Project Description Common WeIlName AFE / RFE NetworkllD # Ann-Comm 1 D-126 Ann-Comm Producer 1 D-126 10259601 10259601 RIG Rig Accept Date Rig Release Date Rig Type Contractor Rig NamelNo 3!26/2010 15:00 3/26/2010 22:00 PUMPING LRS 44 Rig Supervisor Title Company Phone Work Phone Mobile Pager Nezaticky, Peter -CPAI, Wells Supervisor WO Wells Supervisor WO CPAI 659-7446 943-1253 N/A 'ob sco e, workstin information or noted if 'ob is erformed durin Drillin O erations Comment Circulate 10.1 ppg kill weight fluid DAILY OPERATIONS Report Start Date Report End Date Status at Reporting Time Time Log Hrs (hrs) Daily Cost Total 3/26/201015:00 3/26/201022:00 03/27/2010 7.00 71,230.89 initial and final ressures General Remarks Initial T/I = 170/170 psi (flowing to production) Final T/I = 0/0 psi this data box is reviewed dail b en freers su ervisors, and echs. Last 24hr Summary Pumped 10.1 ppg CaCI kill weight fluid down the tubing to the perfs, circulated KWF down the tubing and up the IA to surface. Shut in press 0 psi on the tubing and IA. Pumped 200' of diesel freeze protect down the tubing and IA. Pumped a total of 406 bbl of 10.1 CaCI with 300 bbl of returns. weather related data when and if weather has affect on 'ob Weather Wind T (°F) CONTRACTOR Supervisor Title Company Phone Work Mobile Pager MANJARREZ -LRS, Relief Pump Operator Relief Pump Operator LRS 659-7173 N/A N/A TIMELOG Cum Dur Start Time End Time Dur (hrs) (hrs) Operation Wellbore 15:00 17:00 2.00 2.00 ASRC rigging up hard line, choke maniflod and tanks. Press test lines. 1 D-126 17:00 18:00 1.00 3.00 MIRU Little red and Vac trucks with 400 bbl of 10.1 ppg CaCI brine. PJSM, press test lines to 400 psi. 1 D-126 18:00 21:30 3.50 6.50 Open IA from production to flowback tanks, start pumping brine: 1 D-126 1.25 bpm @ 125 psi (choke 230 psi, downstream 100 psi) 2 bpm @ 200 psi (choke 250 psi, downstream 100 psi) 2.5 bpm @ 200 psi (choke 275 psi, downstream 100 psi) Pumped 55 bbl (tubing full), shut in IA, bullhead 20 bbl down the tbg 2.5 bpm @ 375 psi (IA press 600 psi). Open IA to tanks, pumped 210 bbl at 2.5 bpm @ 350 psi (choke 500 psi, downstream 150 psi) Dropped rate to 1.5 bpm @ 200 psi (choke 400 psi, down stream 150 psi). Pumped 40 bbl and pump press dropped to 125 psi and choke full open with 90 psi down stream. Pumped a total of 406 bbl of 10.1 ppg CaCI brine. Final pump press 1.5 bpm @ 100 psi, choke full open with 15 psi downstream with 300 bbl of brine and crude to return tanks. Pumped 1.5 bbl of diesel down the tubing and 6 bbl down the IA. Shut in pressures 0 psi on the tubing, 0 psi on the IA. No fluid or gas activity in the conductor. 21:30 22:00 0.50 7.00 RDMO Little Red. ASRC will remain to monitor well. Notify DSO. 1 D-126 FLUIDS Fluid To (bbl) Note BRINE 406.0 10.1 ppg CaCI DIESEL 7.5 Freeze Protect www.peloton.com Page 1/1 Report Printed: 3/30/2010 CPAI HSE Statistics Database ConocoPhillips Alaska, Inc. Interim Agency Report Report Date: March 29, 2010 Submitted By: WEIdDY MANAN LOCATION OF DISCHARGE: 1D ADDITIONAL LOCATION INFO: 1D WELL 126 T]ME OBSERVED: 06:00:00 AM 03/26/2010 INITIAL NOTIFICATION BY: WENDY MAHAN . Page 1 of 2 (l~-IZCP ~~~ I r'1 t3" ~~ 8 TO: ADEC: CALLED ALASKA STATE TROOPERS, THEN SPOKE TO JOHN EBEL - 3/26/10 7:48 am, 8:30 am ADNR: LEFT MESSAGE FOR AND THEN SPOKE TO GARY SCHULTZ - 8:04 am, 8:22 am NSB: SPOKE TO ED TOOKPUK - 3/26/10 8:40 am Other: AOGCC FIELD REP: CHUCK SHEVE AND ANCHORAGE OFFICE: TOM MAUNDER - 7:58 am, 7:59 am RESPONSIBLE COMPANY: CONOCOPHILLII'S ALASKA TYPE AND AMOUNT: 149.0 Total Gallon(s) 149.0 Gallon(s) Unto Gravel, covering 62.8 sq ft area 0.0 Gallon(s) Unto Tundra, covering 0.0 sq ft area 0.0 Gallon(s) Into Water, covering 0.0 sq ft area 0.0 Gallon(s) Inside Secondary Containment 0.0 Gallon(s) Into Buildzng 100 % CRUDE OIL CAUSE OF DISCHARGE: UNKNOWN CAUSE UNKNOWN PENDING DIAGNOSTIC EVALUATION. VOLUME ESTIMATE IS SUBJECT TO CHANGE. VAC TRUCK COLLECTED ALL FREE FLUIDS FROM THE CELLAR AND REMAINS ON LOCATION TO COLLECT ANY ADDITIONAL FLUIDS AS WELLWORK CONTINUES. FROZEN SPILL MATERIAL IS CONFINED TO WELL SHELTER AREA PLUS 6'X3' AREA BEHIND WELL AND 4" X 8' AREA ON EACH SIDE OF THE SHELTER. ENVIRONMENTAL DAMAGE: NONE CLEANUP ACTIONS: VAC TRUCK COLLECTED FLUID FROM CELLAR AREA. SPILL AREA WAS DELINEATED. WAITING UNTIL WELLWORK IS COMPLETE AND AREA IS SAFE BEFORE CLEANUP ACTIVITIES RESTART. AT THAT TDvIE THE REMAINING CONTAMINATED MATERIAL WILL BE RECOVERED AND SAMPLES COLLECTED TO CONFIRM CLEANUP. CLEANUP VERffICATION: AMOUNT OF SPILL RECOVERED: 10% http://akapps.conocophillips.net/akstats/Agency5pillRpt.asp?spillId=6470&printerVersion... 3/2912010 HP LaserJet 3390 Fax Call Report KUPARUK ENVIRONMENTAL 9076597712 Mar-29-2010 7:50AM Job Date Time Type Identification Duration Pages Result 6035 3/29/2010 7:49:20AM Send 92767542 1:29 2 OK Date: 3/29110 Spill Notification To: ® ADEC 9-1-907.451-2362 O ADEC Kenai 9-1-907-262-2244 ® ADNR 9-1 907-451-2751 O CiRi 9-2635190 ® NSB 9-1-907-852-0322 O BLM Anchors 9-267-1304 O EPA 9271-3424 O eLM Fbnks 9-1-907.474-2280 O USGC 9-271-6761 q SPCO 9-272.0690 © AOGCC 9-276-7542 O PSIO 9.269-3484 From: Kuparuk Environmental Coordinator Number of Pages: Cover + 1_ RE: Spill Date „3/26110„_,_ Interim 3~ Final Comments: Please see the following interim report for a crude spill that occurred in Kuparuk on 3126110. ConocoPhillips ... a,i. ~,t. In;. HANGER, 37- - CONDUCTOR, az-1z1 HEAT TRACE, 50 ESP MANDREL, 2,azz ESP MANDREL, 5,897 SENSOR, 5,941 INTAKE, 5,983 TANDEM SEALS, 5,987 GEARBOX, 6,001 MOTOR, 6,002 - - - CENTRALIZER, 6,009 IPERF, _ _ 6,060-6,090 IPERF, 6,122-6,142 --~~- IPERF, ~o~?~we - ~'~ ~ KUp ~ 1 D-126 _~ Well Attributes Max Angle & MD TD --- --- - Wellbore API/UWI Field Name Well Status ~Incl (°) MD (ftKB) Act Btm (ftKB) PROD 66.19 4,217.98. 6,716.0 500292288900 WEST SAK _ Comment H2S m Date Annotation End Date KB-Grd ft Ri Release Date PM __ _ Annot t1oONE - Depth (ftKB) End Dao ) IAn otatlon~ Last WO ~ 5/20/2008 ~ 4~)Last Mod g En1d DateB Last Tag: 6,185.0 1 9/10/1998 ,Rev Reason: PULL ESP Pump Assembly - Imosbor 1 /25/2010 Casing Strings - -- -- Casing Descnption ~-String 0... String ID ,., To 42 OB Set D21th0 (f Set Del t2h1(OND) St 6z $t String . Stnng Top Thrd g P g g P( P( ( ) g i H-40 WELDED CONDUCTOR 16 15.062 ~• P ( ) P I~ - P 9 String ... Stnng Top Thrd Casm Descri lion Strin O. Stnn71U ••' 41.1 6 690.8 1Set Dep1h0 $D ... Str29 0 L-80 ABM-BTC To- ftKB) Set De th f... -- --.. -- - - - - ----_-_ _ PRODUCTION 7 5/8 6. 50 i , __ - -- ~ --- i _ L __- --- -- Tub9ng Strings g g P ( ~ P ~ Set Depth (TVD) . !String Wt .. String ... String Top Thrd TUBINGescription $tr312•• St2992••• To 37.2 Se6,011h4t~ - ~_ __ 3,461.1 - 9.30 L-80 II EUE8rdABMOD - -_ _ - Completion Details - - _ - --_ - - -- 1 - --- 'Top Depth, ~'"' Top (ftKB) ~ ITVDI Top Incl Nomi... (ftKB) (°) I Item Description Comment -_ - ~~'. ID (in) - -- 37.2' 37.2 -0.391HANGER ,Tubing Hanger, Vetco, 2.992 - - - 'SENSOR 'Guardian Sensor @ 5 936' - 5,938' 2.992 5,940.7, 3,394 6 20.11 - - - 3,433 9 19.90 INTAKE ESP -Intake, 2.992 5 987.211 TANDEM ~-Upper and Lower Seal, 3,438 31 SEALS - - - - 6,001.O 3,451.31, 19.83 GEARBOX GRU, 525, 9:1 6,002.0'.__ - -- - - ' 3,452.3 ~ 19.83 MOTOR 'ESP -Motor 57 hp, 1315v, KMHG 0.000 6,008.8 3,458.7' 19.SO~CENTRALIZER ESP Motor Centralizer 1.995 nHole (Wireline retrievable plugs, valves, pumps, fish, etc.) Other I ITop Depth Top (ftKB) i, (TVD) .Top Incl ' (ftKB) (°) Description ~ Comment 1, Run Date ID (in) 50 ~ 50.0 -0.33 HEAT TRACE i ESP HEAT TRACE ATTACHED @ 10' DOWN ON JT 95 5/28/2008 0.000 Pe orations Btm ftKB SIOtS _ _ _ _ _ Top (TVD) Btm (TVO) ~~ (ftKB) I (ftKB) Dens - --~ --_.- Top 6 06011 6 090' 3,506.9 3,535.1 Zone Date (sh ~~ Type Comment ~ - i ---- - --- - - ------_ 6 122~I IPERF 0 deg phase, down - - - ~ - - - - 3,584.5 WS B, 1D-126 ,9/17/1998 4.O~IIPERF '9 deg phased, orient down --6,222 8,2341 3,659.91 _1 - ~ __ -- - 8,239 6,256, 3,675.g' 3 671.2,1 WS A3, 1 D-126 9/1311998 4.0 IPERF ~0 deg. phsing, 0 deg orient down - --- - -- -- ~ - - -- 3,692.0 WS A3 1 D-126 9/13/1998 1 4.0 IPERF 0 deg phasing, 0 deg orient down i ~ -- - ---~-- - - -- _ 6,288'. 6,3181, 3,722.2 3,750.6' WS A2 1D-126 8/25/1998 ~ 4.01IPERF 0 Deg phase, down ~ %L -~-6J :. , a c 87 del/6r ~ 5 ~ ~ ~: S Z 13aC- s_ Page 1 of 1 Schwartz, Guy L (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Wednesday, April 07, 2010 8:21 AM To: Schwartz, Guy L (DOA) Subject: 1 D-126 (PTD 198-108) 10-403 Guy, Please modify our 1 D-126 (PTD 198-108) 10-403 request to suspend the well. Instead of the currently selected plug perforations. Please let me know if you need any additional documentation. Regards MJ Loveland WeII Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 4/7/2010 Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, April 02, 2010 2:35 PM To: 'Senden, R. Tyler'; NSK Problem Well Supv; NSK Well Integrity Proj Cc: Schwartz, Guy L (DOA) Subject: RE: 1D-126 Plan Forward `~~_ ~ 0~ Tyler, That is good news. A little extra cement shouldn't be a worry here. I do have one request, is it possible for you or someone else to send in the "spill reports" for this episode? At the start I got a call from Wendy Mahan reporting that bubbling crude was in the cellar, then we received the notice from Martin about the communication and after that the documents and message regarding the plugging work. It would be nice to fill in some of the other details. Thanks in advance. Tom Maunder, PE t~.~.cs.\ ~cQac~t- Svc ~~ AOGCC W ~ S ~~ ~~ ~ ~O "' ~~ From: Schwartz, Guy L (DOA) Sent: Friday, April 02, 2010 2:29 PM To: Senden, R. Tyler Cc: Maunder, Thomas E (DOA) Subject: RE: iD-126 Plan Forward Awesome... thanks for the update. Do you know what the long term plans are now??? Fix surface leak?? P & A completely?? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) ~.... ._~........_ 444-3433 (cell) From: Senden, R. Tyler [mailto:R.Tyler.Senden@conocophillips.com] Sent: Friday, April 02, 2010 2:14 PM To: Schwartz, Guy L (DOA) ~~, ~ ;; ~ ~~ ?S`)5~;~ Subject: RE: 1D-126 Plan Forward r~~y~~~~ ~ ~.w Guy, The job was pumped exactly per the procedure with one exception. We pumped 48 bbls of cement instead of 43 bbls (Schlumberger brought a little extra). Slickline rigged upon the well today and .tagged cement at 5110' SLM (5131' RKB). They got a passing MIT-T to 1500# and both the tubing and the annulus passed a drawdown test. Thanks, Ty Senden From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, April 02, 2010 9:06 AM To: NSK Well Integrity Proj Cc: Senden, R. Tyler ~5~ t ~;~ ~`C~ 7!26/2010 Page 2 of 3 Subject: RE: iD-126 Plan Forward Any updates on the 1 D-126. ??? Did cement pump as planned? Drawdown test ok?? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Thursday, April 01, 2010 8:48 AM To: Schwartz, Guy L (DOA) Cc: Senden, R. Tyler Subject: RE: 1D-126 Plan Forward Guy, It left the slope in the Morning mail on Wednesday. You will probably get it today or tomorrow. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, April 01, 2010 8:45 AM To: NSK Well Integrity Proj Cc: Senden, R. Tyler Subject: RE: iD-126 Plan Forward Guys, Haven't seen a hardcopy of the 403 sundry yet. What is the holdup??? I know we gave a verbal on the operation already but I need the official 403 ASAP. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Tuesday, March 30, 2010 9:41 AM To: Schwartz, Guy L (DOA) Cc: Senden, R. Tyler Subject: FW: iD-126 Plan Forward Guy, 7/26!2010 Page 3 of 3 Please fine enclosed the schematic, Well Service Report of the well kill, and proposed cementing plan. We would like verbal permission to pump cement this afternoon. I will draft a 10-403 sundry request and a-mail it shortly. Please tet me know if this plan is acceptable or if you have any questions. Sincerely, Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 Voice Pager 659-7000 x937 7/26/2010 C~ Regg, Jaynes B (DOA) Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.com] cep 3~' ~ ~ I ~ Sent: Friday, March 26, 2010 4:09 PM ~ ~ j To: ' Schwartz, Guy L (DOA); Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF1 DS Lead Techs; CPF1 Prod Engr; CPF1 Ops Supv Subject: 1 D-126 (PTD# 198-108) Report Of Casing Leak Attachmerts: 1D-126 TIO Plot.pdf; 1D-126 Well Schematic.pdf Guy/Jim/Tom; West Sak ESP producer 1 D-126 (PTD# 198-108) was discovered to have a casing leak that resulted in produced fluids to surface. The Ileak has been contained and CPAI is planning to circulate kill weight fluid in the well. The wel alTi s been- shutut in since 12/29/09 and wil rf e a so until the source of communication can be identified and repaired. 1 D-126 will also be adde~ to the SCP report. Attached is a'~wellbore schematic and 90 day TIO plot. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 3/31/2010 CJ • I 1 _ _ ^-~ KUP . 1 D-126 ConocoPhillips (` ~ ell attributes -- __ _ aX a,n le s~ MD Tro _ Wellbore APINWI Fleltl N~:ne Well Statue Inc! (°) MD (ftKB) Act Btm (ftKB) 500292288900 WEST SAK PROD 66.19 4,217.98 6,716.0 Comment H2S (ppm) Date Annotation End Data KB-Grtl (R) Rip Release Dal wau coon _ 1 _ ~ _ ~ _ .--: ~ i nz^s PM SSSV: NONE 10 817Y2009 Last W0: 5/20/2008 47.00 12/10/1998 a sc-~ -., ~ nduai Annotation Depth (ftKB) End Date Annotation Laat Mod ... End Date i ~~ Last Taq: 6 185.0 9/10/1998 Rev Reason: PULL ESP Pump Assembly Imosbor 1/25/2011 Casing_Stnngs _ __ ___ ' ~ escnpu„n ~8tnng 0... String ID ... Top (ftK8) Set Depth (t... Set Depth (ND) ... String V=/t... H PNOER, 37 " -'~ n< CONDU CTOR 16 15.062 42.0 121.0 121.0 62.58 ~...___~ ' -- Cesin Deacri n 9 PRo Strin 0... 9 Strin ID ... 9 To RKB P( I Set De th f P (••• Set De th ND P 1 1 ••• Strin Wt... 9 ~ PRODUCTION 75/8 6,750 41.1 6,690.8 4,105.8 29.70 " Tubin Strin s 9 a - _- Tubing Descr ption String 0... String ID ... Top (RKB) Bet Depth (L.. Sat Depth (ND) ... String Wt... ' ~ i TUBING_ „___ __. 3 U2 I 2.992 _ _37.2 ~ 6,011.4 3,461,1 9.30 k ~ C_om letion De tails - _ Top Depth (NDI Top Inc! t Top (ftKB) (ftKB) (°I Item Description Comment 37.2 37.2 -0.39 HANGER Tubing Hanger, Vetco, CONDUCTOR, I r;.. 5,940.7 3,394.6 20.11 SENSOR Guardian Sensor @ 5,936' - 5,938' 4z-1 z1 HEAT TRACE, 5,982.5 3,433.9 19.92 1NTAKE ESP-Intake, ~ - ~' 5,987.2 3,438.3 19.90 TANDEM Upper and Lower Seal, i ', ~ SEALS ye . , _ 6,001.0 3,451.3 19.83 GEARBOX GRU, 525, 9:1 ',MANDREL E y~ Ily 6,002.0 3,452.3 19.83 MOTOR ESP-Motor 57 hp, 1315v, KMHG z,azz k'•Y 6,008.6 3,458.7 19.80 CENTRALIZER ESP Motor Centralizer Other In Hole Wirelin e retrievable plugs, valves, pumps, fish, etc_ I 11 Top Depth ' I (ND) lop Inc! . ;~ Top IftKBI (ftKB) (°) Deacription Comment 50 50.0 -0.33 HEAT TRACE ESP HEAT TRACE ATTACHED @ 10' DOWN ON JT ESP MANDREL, 5,897 ', SENSOR, 5,941 INTAKE, 5.983 TANDEM SEALS, 5.967 ',GEARBO%, 6,001 MOTOR, &002 :ENTRALIZER, 6,009 IPERF, fi,Ofi04i,090 IPERF, 6,122b,142 • IPERF, 6,222b,234 IPERF, • 'b,239-6.256 IPERF, 6,288-6,318 • PRODUCTION, 41$,691 TD. 6,716 WELDED itring Top Thrd ABM-BTC i4ing Top Thrd EUERrdARMOD Nomi... 1;olh,l Run Date 1 ID Perforat_io__ns_&_S_I_ots_____ _ _ _ ~ Shot t Top (ND) Btm (ND) Dena Too IftNR1 atm fRKB11 fRK81 IRKBI Zona Date ~lah•~~ Tvoe Comment ~ -~ r .5 r + _ ~, j 1! } trY L~ , f Notes: General & 6!18!2008 NOTE: VIEW w/9.0 SCHEMATIC etails Man dre t D _ _ ___ __ Stn _ _ _ _ ' Top (ftKB) Top Depth (ND) (RKB) To Inc! (`) p Make Model OD (in) __ Serv Valve Type Latch Type Port Size (in) TRO Run (pai) Run Date Com... 1 2,422,2 1,597.9 65.06 CAMCO KBMG 1 ESP DMY BK-5 0.000 0.0 5/29/2008 2 5,896.9 3,353.5 20.30 CAMCO KBMG 1 ESP SOV BK-5 0.000 0.0 1!7/2010 She... ~ ~ ~~~ ~c~ ~F~ ~~ \ C ~ G~~ ~~~ ~mvJ~ C~~.vv~p~ss ~~~t~~~~ ~ ~~~ S~ ~5~~ Cc~.S~ S~~ ~~ wS (~~ ~ ~~~ lrA~sF CoS~~ ~°i `3C~ • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~,~ ll ~i ~ :~ x.008 REPORT OF SUNDRY WELL OPERATION ~~~ ~~~ ~°~~• C°mri~issi°'~ 1. Operations Pertormed: Abandon ^ Repair Well 0 Plug Perforations ^ Stimulate ^ Other ' After Casing ^ Pull Tubing ~ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perrorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhIIIIpS Alaska, InC. Development ~ Exploratory ^ 198-108 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22889-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 70' ~ 1 D-126 • 8. Property Designation: 10. Field/Pool(s): ADL 25650 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 6716' - feet true vertical 4130' ~ feet Plugs (measured) Effective Depth measured 6185' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 6650' 7-5/8" ~ 6691' ~~ „ 4~~ ~U~ g ~~~~ Perforation depth: Measured depth: 6060'-6090', 6122'-6142', 6222'-6234', 6239'-6256', 6288'-6318' true vertical depth: 3507'-3535', 3565'-3584', 3660'-3671', 3676'-3692', 3722'-3751' Tubing (size, grade, and measured depth) 3-1/2", L-80, 6011' MD . Packers &SSSV (type 8~ measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 194 4 98 - 167 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. 1 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 Brett Packer @ 265-6845 Printed Name Brett Packer ~~" ~ ~p ~~ l / Title Wells Group Engineer ~ L f /o ~ ~ `~_ \ Signature -^' Phone: 265-6845 Date ~ ~_ / arnd b heron Allsu k 2~3~l61~ Form 10-404 Revised 04/2006 ~ ~ ~ ~'~~ ~ Submit Origi~~Only7 • a• o$ ~onacoF'hillips Time Log & Summary ~~t~~~ web R°~°~,,~ Report Well Name: 1 D-126 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 5/15/2008 3:00:00 AM Rig Release: 5/20/2008 8:00:00 PM Time Loc~~ Date From To Dur S. Depth E Depth Phase Code 5ubcode T Comment 5/15/2008 24 hr Summary Swap ESP Cable spool. Move off 1 D-134 and MIRU on 1 D-126. Install handi berm. RU kill lines to Tiger tank and PT @ 2,500 psi. Accept Nordic Rig 3 @ 15:00 HRS ON 5-15-08. Lubricate out BPV. RU cellar circ lines and PT @ 2,500 psi. Open up well. Circ hot 8.6 ppg Seawater w/ 6% KCL. Displace well w/ 9.6 ppg Brine w/ 6% KCL. 12:00 13:00 1.00 MIRU MOVE DMOB P PJSM, Swap ESP spools to rig floor. RD / re for move to 1 D-126. 13:00 15:00 2.00 MIRU MOVE MOB P PJSM, commence move Nordic rig 3 1 D-134 to 1 D-126 . 15:00 17:00 2.00 MIRU RPCOM RURD P Spot rig over well, RU kill hardlines, test same ult~ I BPV: Cont RU on 1 D-126 while prep fluid handling equip for well kill /circ. ACCEPT NORDIC RIG 3 THIS DATE 1500 HRS. 17:00 19:00 2.00 COMPZ WELCTL OTHR P RU Cellar lines and PT @ 2,500 psi. Open up well 440 psi TBG Psi, 380 Psi IA. 19:00 21:00 2.00 COMPZ WELCTL CIRC P Held well kill drill on 5-15-08. Circ down tbg @ 4 bpm 1,220 psi ICP taking returns to Tiger Tank. w/ 8.6 ppg 150?F Sea water w/ 6% KCL. FCP @ 4 bpm @ 470 psi. SWI. Recovered 280 bbls and Pumped 342 bbls. Blow down return line to Tiger Tank. 21:00 23:00 2.00 COMPZ WELCTL CIRC P RU to Reverse circ to pits. Fill Poorboy Gas buster to Utube w/ 10 bbls. SITP @ 90 psi and SIIAP @ 190 psi. Begin reverse circulating @ 2 bpm @ 210 psi. w/ 8.6 ppg 68?F sea water w/ 6% KCL, then increase 4 bpm @ 270 psi. for 1 hole vol. Losses to formation was 14 b 23:00 00:00 1.00 COMPZ WELCTL CIRC P Displace 8.6 ppg sea water w/ 9.6 ppg Brine w/ 6% KCL. Reverse Circ 4 b m 250 si ICP. 5/16/2008 Monitor and kill well w/ 9.8 ppg Brine. Install BPV and ND Tree. NU BOPE and test @ 250/2,500 psi. 44 bbl loss toda and 141 total loss to formation. 00:00 01:00 1.00 COMPZ WELCTL CIRC P Continue to Reverse Circ and Displace 8.6 ppg sea water w/ 9.6 ppg Brine w/ 6% KCL @ 4 bpm @ 250 psi. Recovered 39 bbls of prior losses Burin circulation. 01:00 01:30 0.50 COMPZ WELCTL OWFF P Monitor well -found to be slightly flowing 11 bbl gain over 30 min. eriod. r',;:~~c 1 of 5 • Time Logs Date From To Dur 5 De th E. De th Phase Code Subcode T Comment 01:30 02:30 1.00 COMPZ WELCTL CIRC P Reverse circ @ 2 bpm @ 140 psi. Sta a um down slow! 02:30 03:00 0.50 COMPZ WELCTL OWFF P Monitor well for flow. 3 bbl gain over 30 minute eriod. 03:00 03:30 0.50 COMPZ WELCTL OWFF P SWI and obtain SIP's. 0 psi SITP, 10 si SIIAP 03:30 04:00 0.50 COMPZ WELCTL OWFF P Open up TBG and calculate flow @ 7.5 bbls / hr 04:00 06:30 2.50 COMPZ WELCTL OWFF P Monitor well for flow /pressure readin s. 20 si tb , 40 si ann. 06:30 08:00 1.50 COMPZ WELCTL COND P Wt up partial surface volume to 9.8 08:00 10:30 2.50 COMPZ WELCTL CIRC P Circ /displace well volume with 9.8 kill fluids. 10:30 11:30 1.00 COMPZ WELCTL OWFF P Monitor well, "0" psi tbg and annulus. Well static. 11:30 13:30 2.00 COMPZ RPCOM CIRC P Reverse circ well clean. Crude returns to kill tank. Cont circ clean returns. No as. 13:30 15:30 2.00 COMPZ RPCOM OWFF P Monitor well, "0" psi, well static. Sli ht vacuum on annulus. 15:30 17:00 1.50 COMPZ RPCOM NUND P PJSM, set BPV, ND prod tree. 17:00 21:00 4.00 COMPZ RPCOM NUND P PJSM, NU BOPE 21:00 00:00 3.00 COMPZ RPCOM SFEO P Fill Stack and test 250/2 500 si. 44 bbl loss today and 141 total loss to formation. 5!17/2008 Continue to Test BOPE @ 250/2,500 psi. Pull BPV and Pull hanger to Rig floor. Monitor well for flow. Pooh w/ 3 1/2 ESP Completion. Recovered all equipment other than 6 steel bands. 146 bbl loss today and 287 bbl Total loss to formation. 00:00 02:00 2.00 COMPZ WELCTL BOPE P Continue to Test BOPE @ 250/2,500 psi. Draw down test. Start- 3,000 psi. draw down to 1,950 psi. Build was 200 psi in 30 seconds and full recovery was 1:15 seconds. Nitrogen bottles AVE 4 @ 2,200 psi. Breakdown testing equip and blow down lines. Witness of BOPE Installation test waived by Chuck Scheve 05:45 on 5-15-08 02:00 02:30 0.50 COMPZ RPCOM SFEO P Pull Blankin lu and BPV. Install Isolation Sleeve. 02:30 03:30 1.00 COMPZ RPCOM OTHR P MU landing jt w/ circ sub. Screw into hanger and BOLDS. Pull hanger off seat @ 120k and PU on pipe. 90k u wt. 03:30 07:00 3.50 COMPZ WELCTL CIRC P Circulate 420 bbls @ 2 bpm @ 70 psi w/ 9.8 ppg Brine w/ 6% KCL and .2 Ib/bbl DDCWT. Monitor well. Well static. 07:00 08:30 1.50 5,950 5,897 COMPZ RPCOM OTHR P Pull tbg hqr to floor, break all elect connections / penetrators. Remove tb h r. 08:30 10:00 1.50 COMPZ RPCOM RURD P Thread elect cables through spools. Troubleshoots ooler. Page2€~fa l Time Logs Date From To Dur 5 De th E De th Phase Code Subcode T Comment 10:00 17:00 7.00 5,897 2,961 COMPZ RPCOM RCST P PJSM, flow check, POH 3-1/2 ESP y com trin to end of Heat Trace. f/ 5,897' to 2,961' 17:00 22:00 5.00 2,961 148 COMPZ RPCOM RCST P RD Heat Trace spool and sheave. Continue to Pooh w/ 3 1/2 ESP Com letion f/ 2,961' to 148' 22:00 00:00 2.00 148 0 COMPZ RPCOM PULD P Pooh laying down 3 jts, ESP com letion a ui ment f/ 148'. 5/18/2008 Clean and clear rig floor and pipe shed. set wear ring and Load pipe shed w/ Test PKR and RBP. Rih w/ test PKR assy to 6,011'. Test csg to 2,500 psi -good. Pooh laying down DP. 160 bbls loss today and 447 bbl total to formation. 00:00 00:30 0.50 0 COMPZ RPCOM PULD P Pooh w/ ESP Components. Tear down and inspect. Found damage to the MLE @ pump intake area. (copper showing) All components rotated and fluids looked good. Recovered all equipment other than 6 steel bands. 00:30 02:00 1.50 COMPZ RPCOM OTHR P Clean and clear rig floor. Clean and clear Pi a shed. 02:00 03:00 1.00 COMPZ RPCOM OTHR P Change over from TBG equipment to DP E ui ment. 03:00 03:30 0.50 COMPZ RPCOM DHEO P Meg ESP Cable pulled and clean and wra .Cable me ed ood. 03:30 04:00 0.50 COMPZ RPCOM OTHR P Set wear ring 04:00 05:00 1.00 0 210 COMPZ RPCOM TRIP P PU and MU Test PKR and RBP. 05:00 10:00 5.00 210 5,991 COMPZ RPCOM TRIP P Rih w! Test PKR and RBP to 5991 ft. 10:00 13:00 3.00 5,991 6,011 COMPZ RPCOM DHEO P Flow check, PJSM, set RBP 6011 ft, set test kr 5987 ft. Test RBP and 7-5/8 cs to test kr 2 00 si unseat test pkr, test 7-5/8 csca to surface 2500 psi / 30 min. Retrieve RBP. All tests successful. 13:00 15:00 2.00 6,011 6,011 COMPZ RPCOM CIRC P Flow check, circ / cond fluids, cont circ well free of crude. 3.5 bpm - 320 si. 15:00 17:30 2.50 6,011 4,024 COMPZ RPCOM TRIP P Flow check, static loss 2-5 bph. POH, lay do 3-1 /2 DP for ESP com letion. f/ 6,011' t/ 4,024' 17:30 21:00 3.50 4,024 4,024 COMPZ RPCOM OTHR P Remove guards and prep to unload ESP Cable pulled w/crane. Hold PJSM w/ crane operator. Remove old spool of ESP Cable and Heat Trace. The heat trace spool that was to be reloaded was a partial spool. Attempt to locate full spool. Reload New ESP Cable and re install uards. 21:00 00:00 3.00 4,024 210 COMPZ RPCOM TRIP P Pooh w/ test PKR and RBP laying down DP f/ 4,024' to 210'. 5/19/2008 Pooh laying down Test PKR and RBP. Pull wear ring . Begin to Rih w/ 3 1/2 ESP Completion to 5,690' 85k u wt. 55k do wt. Total losses for toda was 85 bbls and 532 bbls total losses. 00:00 01:30 1.50 210 0 COMPZ RPCOM TRIP P . Pooh laying down dc's and Test.PKR and RBP. Page ~ ~f 5 • Time Logs _ Date From To Dur S De th E. De th Ph Code Subcode T Comment 01:30 02:00 0.50 0 0 COMPZ RPCOM OTHR P Pull wear ring. 02:00 04:00 2.00 0 0 COMPZ RPCOM PULD P PU and service motor and Seal unit. 04:00 08:00 4.00 0 109 COMPZ RPCOM PULD P Thread ESP Cable over Sheeve and connect MLE, Guardian, install guage @ jts 1 & 2 test same. All tests ood. 08:00 08:30 0.50 109 122 COMPZ RPCOM RCST P Flow check, approx 3-5 bph static losses. Follow motor /pump assy with GLM# 2 08:30 13:00 4.50 122 2,992 COMPZ RPCOM RCST P Be in running w/ 31 stands or 93 its of 3 1/2 TBG from derrick to 2,992' and be in heat trace. 13:00 16:30 3.50 2,992 3,594 COMPZ RPCOM RCST P Continue to Rih w/ 6 stands or 18 jts of 3 1/2 TBG from derrick to 3,576' and install GLM# 1. 16:30 22:30 6.00 3,594 5,440 COMPZ RPCOM RCST P Continue to Rih w/ 1 single and 19 Stands or 58 jts of 3 1/2 TBG from derrick to 5,440' and ran out of dual cross c I #2 fiber clam s. 22:30 23:30 1.00 5,440 5,440 COMPZ RPCOM WOEQ T Wait for dual cross cplg #2 fiber clam s to arrive. 23:30 00:00 0.50 5,440 5,690 COMPZ RPCOM RCST P Continue to Rih w! 3 stands or 18 jts of 3 1/2 TBG from derrick to 5,690' 85k up wt and 55k do wt. Total losses for toda was 85 bbls and 532 bbls total losses. 5/20/2008 Continue to Rih w/ 3 1/2 Completion and MU hanger. Install penetrators and space out. Make final splices in Heat Trace, ESP Cable and Itec wire. 00:00 01:00 1.00 5,690 5,975 COMPZ RPCOM RCST P Continue to Rih w/ 3 stands or 18 jts of 3 1/2 TBG from derrick to 5,975.0' 85k u wt and 55k do wt. 01:00 02:00 1.00 5,975 COMPZ RPCOM PULD P PU and MU hanger and install side port isolation sleeve. Install enetrators. 02:00 04:00 2.00 COMPZ RPCOM OTHR P Begin making final splices in ESP Cable, Heat Trace and Itec wire. 04:00 06:00 2.00 COMPZ RPCOM OTHR T Inspect and repair Itec wire 06:00 06:30 0.50 5,975 6,011 COMPZ RPCOM HOSO P Land han er and RILDS w/ ail 6 011'. UP WT = 87K, SO WT = 55K. 06:30 08:00 1.50 6,011 COMPZ RPCOM SFEO P Rig up and test hanger seals to 5000 PSI - 15 minutes as er FMC re . 08:00 08:30 0.50 COMPZ RPCOM OTHR P Pull Isolation sleeve & install Two wa check valve. 08:30 11:30 3.00 COMPZ RPCOM NUND P Held PJSM. Nipple down BOP stack. Utilize crane to remove all ESP & heat trace a ui ment. 11:30 12:00 0.50 COMPZ RPCOM SFEQ P Perform pre-final check on ESP, Itec and heat trace lines. 12:00 13:30 1.50 COMPZ RPCOM NUND P Nipple up tree. 13:30 14:00 0.50 COMPZ RPCOM SFEQ P Perform test on void to 5000 PSI - 10 minutes as er FMC re . • Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 14:00 15:30 1.50 COMPZ RPCOM SFEQ P Rig up and test tree to 5000 PSI - 5 Minutes as per FMC rep.Rig down, and blow down lines. 15:30 17:00 1.50 COMPZ RPCOM FRZP P Held PJSM with crew & Little Red Services. Rig up and test lines. Pump 90 BBLS of freeze protect diesel down annulus. Bull head 30 BBLS of diesel down tbg. FCP = 1200 PSI on tbg. FCP on IA = 925 PSI. SIP = 700 PSI on the tbg, 400 PSI on the IA. 17:00 19:00 2.00 COMPZ MOVE DMOB P Rig down all equipment. Roll up tarps. Start & roll moving system while wait on lubricator. 19:00 20:00 1.00 COMPZ RPCOM OTHR P Make up Lubricator, SET BPV, NORDIC RIG 3 RELEASED THIS DATE 20:00 HRS TOTAL 678 WO FLUIDS LOST TO WELL DURING WO. page § of 5 ~ _. _ €`aa)t~c~cillips i..kd,YiK:. 'API/UWI n 5002922889 _ Feia Name WEST SAK m Iw Il Status PROD ~ KUP e _ ...(Maximum Iodination (°) 66.19 1 D-126 total Ueptn (ttK6) ~'II 6716.0 Comment H25 (ppm) Date Annotati... Entl Date KB-G rountl Distance (ft) 'Rig Release Date ~, _ry -,e11~o. ciat 0~05.[,.Og PM Last WO. 5/20/2008 47.00 I 12/10/1998 Scnertlaric-F.p;ual_. _ - _- Annotation Depth (ftK8) Entl Date Annotaton Entl Date last Tag: 6,185.0 9/10/1998 Rev Reason: WORKOVER, set ESP PUMP 6/17/2008 HANGER, 3l 1 II 1 CONDUCTOR, 0-121 I ii HEAT TRACE, 50 ~' ~I GAS LIFT, 2,422- - ,t ,! GAS LIFT 5,891 [ __ = ~ r IOn vu (In) ID (In) Top (ftK8) Set Depth (ftK8) Set Depth (ND) (kKB) Wt (msm) Grade Toy wu.iectiuu CONDUCTOR 16 15.062 0.0 121.0 121.0 62.58 H-40 WELDED Casing Descrlptlon PRODUCTION OD (In) 7 5/8 ID (in) 6.750 Top (ftK8) 25 0 Set Depth (ftK8) 6.716.0 Set Depth (ND) (kKe) 4.129.9 Wt (Ibs/k) 29.70 _ Grade '~TOp L nection L 80 ABM-BTC J ® l ul.ing Dencnynun utr tin) IG iu,t Toy titre... sit iueyu, tItKB/ .set Depth (ND) (ftK8) Wt (IbsHt) Gratle Tay :, „nection TUBING 31/2 2.992 37.2 6,011.4 3,461.1 9.30 L-80 EUE SRD AB-modified e _ Top tlthB) j Item Description Comment -- _I ID (in) 37.2jHANGER Tubing Hanger, Vetco, 2.992 2,422.2;GAS LIFT GLM 1, Camco, KBMG, BK-5, tin with DMY STA 1 2.992 5,896.91,GAS LIFT GLM 2, Camco, KBMG, BK-5, tin with SOV STA 2 2.992 525, • + ~.. ~ ,~ '" lop (ftK8) Descrlptlon Kure Irate iu tin! '.. '' 50.0 HEAT TRACE ESP HEAT TRACE ATTACHED @ 10' DOWN_ON JT 95 ___ _ __ ___ ~ 5/28/2008 0.000'. 5,915.0 SLIPSTOP SLIPSTOP set 5/29/2008 5%29/2008 1.500 5,921.0 PAC KOFF PACKOFF @ 5921' WLM, set 5/28/2008 5/28/2008 1.500 5,935.0 PUMP PCP 250-T-1800 PUMP (33.13') @ 5989' RKB,. set 5/29/2008 X5/2 812 00 8 Shot l.al~ul... Btm ' Top (ND) Btm (ND) Dens Shot Top (ftK8) (ftK8) ~I, (ftK8) (ftK8) Type Zone (sho Total Date Comment 6,060.0; 6,090 01, 3,506.9 3,535.1 IPERF WS D, 4 0 12---0 rrr---9/22/1998 0 deg phase, down ~ ' 1D-126 6,122.0 6,142.0 3,566.1 3,584.8 IPERF WS B, 4.0 80!9/17/1998 9 deg phased, orient down 1 D-126 6,222.0 6,234.0 3,659.9 3,671.2 IPERF WS A3, 4.0 489/13/1998 0 deg. phsing, 0 deg orient down 1 1 D-126 6,239.0 6,256.0 3,675.9 1 3,692.0' IPERF WS A3, 4.0 68;9/13/1998 0 deg phasing, 0 deg orient down 1 D-126 6,288 0 j 6,318 0 3,722.2 3 750 6 (IPERF WS A2, 4.0 120;8/25/1998 O Deg phase, down I ~ 1D-126 I 1 D-126 (PTD 198108fl) failed ESP : Downhole short Page 1 of 1 Maunder, Thomas E (DOA) Frain: NSK Problem Well Supv [n1617@conocophilGps.com] Sent: Wednesday, October 03, 2007 6:22 PM To: Maunder, Thomas E {DOA); Regg, James B (DOA) Cc: NSK West Sak Prod Engr; NSK Well Integrity Proj; NSK Problem Well Supv Subject: 1 D-126 (PTD 1981080) failed ESP : Downhole short Tom & Jim, 1 D-126 (PTD 1981080} ESP failed on 09/19/07 due to a downhole electrical short. The well will remain shut in until it can be worked over. The well is a single casing ESP and we will not attempt to temporarily gas lift the well. Please let me know if you have any ques#ions. Brent Rogers Problem Wells Supervisor 659-7224 ~~~1 ~~~ ~~~~ ~ ~ ~flfl7 10!4/2007 . . Conoc6Phillips Alaska RECEIVED JUL 1 0 Z007 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 l.\iaska Oil & Gas Cons. Commission Anchorage July 6, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 :dANN@ "JDL 1 1 7007 \ot3 fl~" \-, Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please M.J. Loveland at 907-659-7043, if you have any questions. ConocoPhillìps Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field June 9,2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft aal 1 0-09 198-065 23" na 5 6/912007 10-101 200-183 2" na 3.2 6/9/2007 10-102 200-075 2" na 3.2 6/9/2007 10-103 202-096 5" na 8 6/9/2007 1O-105a 201-202 25" na 38 6/912007 10-106 197-240 2" na 3.2 6/9/2007 10-107 200-177 2" na 3.2 6/912007 10-108 198-187 8" na 12.8 6/9/2007 10-113 198-178 2" na 1 6/912007 10-114 198-159 2" na 1 6/912007 10-115 197-232 2" na 1 6/912007 10-116 198-172 2" na 1 6/9/2007 10-117 197-237 2" na 1 6/912007 10-118 197-229 2" na 1 6/912007 10-119 197-222 2" na 1 6/9/2007 10-122 198-149 2" na 1 6/9/2007 10-123 198-170 2" na 1 6/9/2007 1O-125a 200-044 2" na 1 6/9/2007 1 0-126 198-108 2" na 1 6/912007 10-127 198-109 8" na 2.5 6/9/2007 10-128 198-133 2" na 1 6/9/2007 10-129 197-213 2" na 1 6/912007 10-130 197-183 23" na 5 6/912007 198-108-0 KUPARUK RIV U WSAK 1D-126 50- 029-22889-00 PHILLIPS ALASKA INC Roll gl: Start: Stop Roll #2: Start Stop MD 06716 TVD 04130 Completion Date: 11/28/98 Completed Status: 1-OIL Current: Name Interval Sent Received T/C/D D 8481 1-3 SPERRY GR OH 7/15/98 7/15/98 L DGR/EWR4-MD FINAL 12106716 OH 7/22/98 7/22/98 L DGR/EWR4-TVD FINAL 1214130 OH 7/22/98 7/22/98 L USIT-REPROSCET FINAL BL(C) 50-6550 CH 5 9/4/98 9/9/98 R SRVY CALC BHI 121-6716 OH 1/4/99 1/5/99 R SRVYRPT SPERRY 0-6716. OH 7/13/98 7/22/98 Tuesday, January 09, 2001 Page 1 of 1 ARCO Alaska, Inc. *~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 30, 1998 Mr. Robert W. Chfistenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-126 (Permit No. 98-108) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak 1D-126. If there are any questions, please call 265-6890. Sincerely, T. W. Mc Kay Senior Drilling Engineer AAI Drilling TWM/skad STATE OF ALASKA '~--~LASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [] GAS I--I SUSPENDED r--I ABANDONED--] SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-108 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22889 4 Location of well at surface ~'~--,~.,.~-~:-;k~:~'-~ 9 Unit or Lease Name 301' FNL, 599' FEL, Sec. 23, T11N, R10E, UM :' ~ !] ~~~[' Kuparuk River Unit At Top Producing Interval ~ ~ f ! ~ ~, ~ 10 Well Number 2351' FNL, 707' FVVL, Sec. 23, T11N, R10E, UM ~__ West Sak 1D-126 At TotalDepth { ~!i~? i: !;'~':t~' 11 Field andPool 2438' FNL, 519' FWL, Sec. 23, T11N, R10E, UM .q' ~.-~ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease'DeSi~nation and Serial No. West Sak Oil Pool RKB 41', Pad 70'I ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions 22-Jun-98 26-Jun-98 28-Nov-98 NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 6716' MD & 4130' TVD 6560' MD & 3981' TVD YES IXI NO U NA feet MD 1518' APPROX 22 Type Electric or Other Logs Run GR/Res, USIT, GR/CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.58# H-40 SURF. 121' 24" !260 sx AS II 7.625" 29.7# L-80 SURF. 6691' 9.875" !1. 190 sx ASIII LW, 330 sx Class G 2. 475 sx ASIII LW, 60 sxAS I 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) 6060'-6090' MD 3507'-3535' TVD 3.5" 6003' N/A 6122'-6142' MD 3565'-3584' TVD 6239'-6256' MD 3676'-3692' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 6222'-6239' MD 3660'-3676' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6288'-6318' MD 3722'-3751' TVD see attachments 4spf r~ ~' r_ I ~1 ~ r~ [~1- ~.,r I V L i,/ 27 PRODUCT,ONTEST 0 r,l[ A I ,JAN 1999 Date First Production Method of Operation (Flowing, gas lift, etc.) ~, 110 1 i ~1/~ L ,2/,9,98 Gas L~t Alaska 0il l Gas Cor~. C0mmi~ Date of Test Hours Tested PRODUCTION FOF',OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RAT~q~.rlCrl0rag8 12/25/98 6 TEST PERIOD 84 34 10 100I 697 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 186 0 24-HOUR RATE: 303 211 41 0 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 9. ~'--' 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 West Sak Sand 6053' 3500' Base West Sak Sand 6507' 3930' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Shallow Sands Team Leader DATE Prepared by Name/Number Sharon AIIsup-Drake/263-4612 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- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 10/14/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-126 WELL_ID: AK9629 TYPE: AFC: AK9629 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:06/22/98 START COMP: RIG:RIG # 245 WI: 0% SECURITY:0 API NIIMBER: 50-029-22889-00 BLOCK: FINAL:06/30/98 06/20/98 (D1) TD: 121' (121) SUPV:DCL 06/21/98 (D2) TD: 121'( SUPV:DCL o) 06/22/98 (D3) TD: 1257'(1136) SUPV:DCL 06/23/98 (D4) TD: 4141'(2884) SUPV:DEB 06/24/98 TD: 5399' SUPV:DEB D5) 1258) 06/25/98 TD: 5993' SUPV:DEB D6) 594) 06/26/98 (D7) TD: 6716' (723) SUPV:DEB MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 Move rig from iH pad Prepare modules for move. Move both modules 2 miles from iH pad. MW: 8.3 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 PU 4" DP Move to iD pad. NU diverter. MW: 9.1 VISC: 275 PV/YP: 32/53 APIWL: 7.8 Drilling NU diverter. Function test diverter. Drilling from 121' to 1257' MW: 10.0 VISC: 229 PV/YP: 39/47 APIWL: 6.4 Short trip, RBIH Drill from 1257' to 4141' MD. MW: 9.9 VISC: 278 PV/YP: 47/67 APIWL: 5.4 Drilling ~ 5640' Drill from 4141' to 5399' MW: 10.0 VISC: 289 PV/YP: 51/61 APIWL: 5.4 Drilling ~ 6469' Drill from 5399' to 5707' Pump slug. POH with worn bit. Wash and ream from 5100' to bottom. Drill to 5993' MD. MW: 9.9 VISC: 238 PV/YP: 40/48 APIWL: 6.8 RUNNING 7-5/8" CASING Drill from 5993' to 6716' POH. Pulled tight between 1108' to 358'. Run 7-5/8" casing. Date: 10/14/98 06/27/98 (DS) TD: 6716'( SUPV:DEB 06/28/98 (D9) TD: 6716'( SUPV:DEB 06/29/98 (D10) TD: 6716'( 0 SUPV:DEB 06/30/98 (Dll) TD: 6716'( 0 SUPV:DEB ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 MW: 9.9 VISC: 98 PV/YP: 35/35 Slow Cooling Weld on Adapter APIWL: 7.2 Run 7-5/8" casing. Pump cement. MW: 9.3 VISC: 44 PV/YP: 12/10 RIH with 7-5/8" casing scrapers APIWL: 13.2 Weld Gray adapter on 7-5/8" stub. Install tubing head. NU BOPE and test to 300/2000 psi. Clean out cement from 2860' to 2894'. Clean out cement, plug and drill out stage tool at 2934'. Ream out cement/debris. Clean out cement from 6378' to plug on baffle collar at 6565' MW: 8.3 VISC: Running 3.5" frac string 0 PV/YP: 0/ 0 APIWL: 0.0 RIH with scraper, scraper ran thru stage tool @ 2931' with no problem. POH. RIH with USIT tools and log from 6550' to surface. MW: 0.0 VISC: Rig Released 0 PV/YP: 0/ 0 APIWL: 0.0 Finish running USIT log from 6550' to surface. Run 3.5" tubing, frac string. Pump caustic soda with hogwash. Freeze protect. ND BOP. NU tree and test to 5000 psi. Rig Released @ 2200 hrs. 6/30/98. Date: 12/28/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 REMEDIAL AND COMPLETION OPERATIONS WELL:iD-126 WELL ID: AK9629 TYPE: -- AFC: AK9629 STATE:ALASKA 22889-00 AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:06/22/98 START COMP:11/24/98 RIG:NORDIC # 2 BLOCK: FINAL:06/30/98 WI: 0% SECURITY:0 API NUMBER: 50-029- 11/24/98 (C12 TD: 0' PB: 0' 11/25/98 (C13 TD: 6716' PB: 6560' 11/26/98 (C14 TD: 6716' PB: 6560' 11/27/98 (C15 TD: 6716' PB: 6560' 11/28/98 (C16 TD: 6716' PB: 6560' 11/29/98 (C17) TD: 6716' PB: 6560' 11/30/98 (C18) TD: 6716' PB: 6560' N/U BOPE. MW: 8.7 BRINE SUPV:M.C. HEIM Move rig from 1D-127 to 1D-126. Accept rig @ 1900 hrs. 11/24/98. RUNNING IN HOLE F/ 3992 MW: 8.7 BRINE SUPV:M.C. HEIM N/D tree, N/U BOPE and test to 350/3500%, OK. RIH w/mill. PULL UP HOLE 2 STANDS TO MW: 8.7 BRINE SUPV:M.C. HEIM RIH w/6.75" mill. Clean out to 3941'. Mill from 5960' to 6188' PICKING UP 3-1/2" TBG. MW: 8.7 BRINE SUPV:M.C. HEIM Milling 1 jt and reversing out, packing off. Milled to 6219' Mill and clean hole to 6554' RUNNING COMPLETION. MW: 8.7 SUPV:M.C. HEIM Hole clean. RIH w/3.5" tubing. Run ESP assembly. BRINE MOVE RIG. MW: 8.7 BRINE SUPV:M.C. HEIM Run completion. N/D BOPE, N/U tree and test to 250/5000%. NEW WELL MW:15.4 DOILW SUPV:M.C. HEIM Freeze protect well. Release rig @ 0530 hrs. 11/30/98. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,ak, WELL SERVICE REPORT '~' K1(1D-126(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-126 FRAC, FRAC SUPPORT 0822980836.4 DATE DAILY WORK UNIT NUMBER 08/25/98 PERFORATE A2 SANDS 8305 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I YESI YES SWS-ELMORE JONES FIELD AFC# CC# Signed ESTIMATE AK9629 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 0 PSI 100 PSI 0 PSI 100 PSI 0 PSII 0 PSI DALLY SUMMARY ISWS RAN GR/CCL LOG FROM 5870' TO 6560'. PERFED FROM 6288' TO 6318' W/2 1/8" E J, 4 SPF, BH, 0 PHASE, DOWN USING 275 PSI WHP. TAG @ 6560'. [Perf] LOG ENTRY TIME 11:00 SWS STAYED RIGGED UP FROM PREVIOUS JOB. MU 1 11/16" GR/CCL, WB, ROLLER & HEAD. PT LUB TO 3000#. 11:15 MIH W/GR/CCL TOOLS, CORR TO ARCO BASIC LOG 7-20-98. OBTAINED GR/CCL LOG FROM 6560' TO 5870'. TAG DOWN @ 6560 RKB. 11:45 POH & LD TOOLS. 12:15 MU SAFE GUN & PT LUB TO 3000#. MIH W/30' - 2 1/8" ENERJET, 4 SPF, BH, 0 PHASED, DOWN, SAFE, MPD, CCL, WB, ROLLERS, HEAD. CORR TO SWS GR/CCL LOG 8-25-98 & PERF FROM 6288' TO 6318' WITH 275 PSI WHP. 14:15 POH & LD GUN, ALL SHOTS FIRED. 14:45 RIG DOWN. 15:30 RELEASE SWS. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '' K1 (1 D-126(W4-6)) .. WELL JOB SCOPE JOB NUMBER 1 D-126 FRAC, FRAC SUPPORT 0822980836.4 DATE DAILY WORK UNIT NUMBER 09/09/98 FRAC "A2" SANDS DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 2 YES YES DS-GALLEGOS SCHWEN DERMAN FIELD AFC# CC# Signed ESTIMATE AK9629 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 1000 PSI 400 PSI 0 PSI 0 PSII 0 PSI 0 PSI DALLY SUMMARY "A2" SAND FRAC, PUMPED TOTAL OF 80,153 LBS PROP. WITH 80,53 LBS PROP OUT PERFS AND LEAVING 100 LBS PROP J LEFT IN PIPE. AVERAGE TREATING PRESSURE 2584 PSI. MAXIMUM TREATING PRESSURE 4857 PSl.[Frac-Refrac] I TIME LOG ENTRY 07:00 MIRU DS FRAC UNIT(GELLEGOS; LRS; HES; APC) TGSM, EVAC PLAN, WIND DIRECTION. PT LINES TO 8000 PSI. 09:42 PUMPED DIESEL DOWN ANNULAS TAKING RETURNS OUT TUBING UNTIL CLEAN. 10:09 PUMPED BREAKDOWN 2% KCL WATER 28 BPM, MAX 6079 PSI. SD ISIP 603 PSI. 10:41 PUMPED 50# HEC DATA FRAC 15 BPM, 2100 PSI, SD ISIP 1105 PSI. 12:30 PUMPED MAIN FRAC AS DESIGNED THROUGH 10 PPA AT 30 BPM, AVERAGE TREATING PRESSURE OF 2584 PSI AND MAX TREATING PRESSURE OF 4857 PSI. PUMPED RIGHT THRU TO FLUSH. TOTAL OF 80,153 LBS PROP PUMPED. 80,053 LBS PROP IN PERFS, LEAVING 100 LBS PROP IN PIPE. 13:15 REVERSED OUT TUBING WITH 100 BBLS OF DIESEL UNTIL CLEAN. SHUT IN WELL. REMOVED TREE SAVER. 15:00 RD ALL EQUIPMENT. LEAVE EQUIPMENT ON LOCATION FOR NEXT FRAC. LEAVE WELL SHUT IN FOR FOLLOW UP SL AND CTU. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~, WELL SERVICE REPORT '~' K1(1D-126(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-126 FRAC, FRAC SUPPORT 0822980836.4 DATE DAILY WORK UNIT NUMBER 09/13/98 PERF "A3" SAN D DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 6 YESI YES SWS-JOHNSON SCHWENDERMAN FIELD AFC# CC# Signed ESTIMATE AK9629 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 200 PSI 300 PSI 0 PSI 0 PSI 0 PSII 0 PSI DAILY SUMMARY RAN 2-1/8" ENERJET PERF GUNS WITH SAVE ASSEMBLY. PERFORATE 7-5/8" CASING F/6256' - 6239' (17') AND F/6239' - 6222' (17').[Perf] TIME 19:00 21:00 22:15 LOG ENTRY MIRU SWS (JOHNSON AND CREW) TGSM, PROPER LIGHTING AT NIGHT. MU #1 PERF ASSEMBLY. 2-1/8" ENERJET 17', BH, 4 SPF, 0 DEG PHASING, 0 ORIENT DOWN. ( EJ GUN/SAFE/MPD/WT/WT/CCL/SWIVEL/HEAD) TL=40'. PT LUB TO 3500 PSI. RIH. TIE IN USING SCHLUMBERGER JEWLRY LOG DATED 8/25/98. PERFORATE 7-5/8" CASING FROM 6256' - 6239' (17'), GOOD SUFACE INDICATIONS. POH. RD ALL SHOTS FIRED. MU PERF ASSEMBLY #2, SAME AS ABOVE. RIH. 00:15 TIE IN. PERFORATE 7-5/8" CASING FROM 6239'- 6222'. GOOD SURFACE INDICATIONS. POH. 02:00 AT SURFACE, RD. ALL SHOTS FIRED. LEAVE WELL SHUT IN AND NOTIFIED DSO. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~, K1(1D-126(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-126 FRAC, FRAC SUPPORT 0822980836.4 DATE DAILY WORK UNIT NUMBER 09/13/98 PERF "A3" SAND DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 6 YESI YES SWS-JOHNSON SCHWENDERMAN FIELD AFC# CC# Signed ESTIMATE AK9629 18WSTF7SC InitialTbgPress FinalTbgPress Initial lnner Ann Final lnner Ann IlnitialOuterAnn I Final Outer Ann 200 PSI 300 PSI 0 PSI 0 PSII 10 PSI 0 PSI DAILY SUMMARY I RAN 2-1/8" ENERJET PERF GUNS WITH SAVE ASSE,,MBLY. ,P,,ERFORATE 7-5/8" CASING F/6256' - 6239' (17') AND F/6234' - 6222' (17'). BOTTOM 5' DID NOT FIRE ON 2ND RUN.F/6234 - 6239 [Perf] TIME LOG ENTRY 19:00 MIRU SWS (JOHNSON AND CREW) TGSM, PROPER LIGHTING AT NIGHT. MU #1 PERF ASSEMBLY. 2-1/8" ENERJET 17', BH, 4 SPF, 0 DEG PHASING, 0 ORIENT DOWN. ( EJ GUN/SAFE/MPD/WT/WT/CCL/SWIVEL/HEAD) TL=40'. PT LUB TO 3500 PSI. 21:00 RIH. TIE IN USING SCHLUMBERGER JEWLRY LOG DATED 8/25/98. PERFORATE 7-5/8" CASING FROM 6256' - 6239' (17'), GOOD SUFACE INDICATIONS. 22:15 POH. RD. ALL SHOTS FIRED. MU PERF ASSEMBLY #2, SAME AS ABOVE. RIH. 00:15 TIE IN. PERFORATE 7-5/8" CASING FROM 6239'- 6222'. GOOD SURFACE INDICATIONS. POH. 02:00 AT SURFACE, RD. BOTTOM 5' DID NOT FIRE F/6239' TO 6234'. LEAVE WELL SHUT IN AND NOTIFIED DSO. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT ~, K1(1D-126(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-126 FRAC, FRAC SUPPORT 0822980836.4 DATE DAILY WORK UNIT NUMBER 09/14/98 "A3" SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 7 YESI YES DS-GALLEGOS SCHWENDERMAN FIELD AFC# CC# Signed ESTIMATE AK9629 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 300 PSI 200 PSI 200 PSI 200 PSII 0 PSII 0 PSI DAILY SUMMARY FRAC "A3" SAND. PUMPED TOTAL OF 82,351 LBS OF PROP. WITH 80,310 LBS PROP OUT PERFS, FLUSHED LEAVING 2,041 LBS IN PIPE. [Frac-Refrac] TIME LOG ENTRY 07:00 MIRU DS UNIT (GALLEGOS, CREW, LRS, HES, APC)TGSM, EVAC AND JOB OVERVIEW. INSTALLED TREE SAVER. PT LINES TO 8000 PSI. 09:00 REVERSE CIRC 70 BBLS DIESEL UNTIL RETURN WERE CLEAN OUT TUBING. 08:45 PUMPED 150 BBLS 3% KCL SW HPBD AT 30 BPM, TREATING PRESSURE 4797 PSI. SD, ISIP 850 PSI. 09:20 PUMPED 50# HEC GEL DATA FRAC. 15 BPM AVERAGE TREATING PRESSURE 1600 PSi. FLUSHED WITH 3% KCL SW. SD, ISIP 1021 PSI. 10:45 PUMPED 110 BBLS 50# HEC GEL PAD. FOLLOWED BY MAIN FRAC PUMPING 30 BPM, STARTING 2 PPA RAMP UP TO 7 PPA HOLD STAGE AND REDUCED RATE TO 15 BPM, RAMP UP TO 10 PPA AND FLUSHED WITH 3% KCL SW, SWITCH TO DIESEL LAST 30 BBLSA. REACHED MAXIMUM ANNULAS PRESSURE OF 3100 PSI , SD. MAXIMUM TREATING PRESSURE 4300 PSI. 11:18 SHUT DOWN AND REVERSED UT WITH TOTAL OF 80 BBLS OF DIESEL PUMPED UNTIL CLEAN FLUID FLUID. 13:00 RD DS. LEAVE EQUIPMENT ON LOCATION FOR NEXT STAGE FRAC. NOTIFIED DSO ON WELL CONDITION. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~, K1(1D-126(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-126 FRAC, FRAC SUPPORT 0822980836.4 DATE DAILY WORK UNIT NUMBER 09/17/98 PERFORATE B SANDS 2128 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 9 YESI YES VETROMILE JONES FIELD AFC# CC# Signed ESTIMATE AK9629 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 350 PSI 300 PSI 350 PSI 300 PSII 0 PSII 0 PSI DALLY SUMMARY I= 52' OF SAND ABOVE A3 TOP PERF.[Perf] SWS PERFORATED B SANDS FROM 6122' TO 6142' IN ONE RUN W/2 1/8" E J, 4 SPF, BH, DOWN. TAGGED SAND CAP @ 6170' TIME LOG ENTRY 13:45 DID NOT RIG DOWN FROM PREVIOUS JOB. MU 20' SAFE GUN & PT LUB TO 3000#. 14:15 MIH W/20' - 2 1/8" ENERJET, 4 SPF, BH, 0 PHASED, DOWN, SAFE, MPD, CCL & (2) WB. CORR TO SWS JEWELRY LOG 8-25-98 & PERF B SANDS FROM 6122' TO 6142'. TAG SAND @ 6170' = 52' SAND ABOVE TOP OF A3 PERFS. 15:30 POH & LD GUN, ALL SHOTS FIRED. 16:30 RIG DOWN. 17:15 RELEASE SWS. ARCO Alaska, Inc. "- ....... ~ .... KUPARUK RIVER UNIT ,~ WELL SERVICE REPORT ,, K1(1D-126(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-126 FRAC, FRAC SUPPORT 0822980836.4 DATE DAILY WORK UNIT NUMBER 09/19/98 B SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 10 YESt YES DS-GALLEGOS LIG ENZA FIELD AFC# CC# Signed ESTIMATE AK9629 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 196 PSI 700 PSI 200 PSI 700 PSII 10 PSI 0 PSI DAILY SUMMARY PUMPED 150 BBL PAD. PUMPED MAIN FRAC W/16/20 PROPPANT & 50# HEC W/PROPLOK. 15 BPM @ 2400 PSI AVERAGE. PUMPED 2 - 7 PPG. PUMPED 61,412# OF PROPPANT W/59,949# OF 7 PPG TO PERFS. REVERSE OUT W/DIESEL.EXPECT TAG BELOW TUBING TAIL. BHP 1464[Frac-Refrac] TIME LOG ENTRY 07:30 MIRU, TGSM, 19 PEOPLE ON LOCATION. PT TO 7500#. 14:15 PUMP HP BD W/150 BBLS H20 & 66 BBLS 50# HEC GEL @ 30 BPM @ 4,600 PSI. 15:10 PUMP DATA FRAC 15 BPM W/34 BBLS 50# HEC GEL & 71 BS H20 @ 2360 PSI. ISIP= 680 PSI. 17:10 PUMPED 150 BBL PAD. PUMPED MAIN FRAC W/16/20 PROPPANT & 50# HEC W/PROPLOK. 15 BPM @ 2400 PSI AVERAGE. PUMPED 2 - 7 PPG PROPPANT. PUMPED 61,412# OF PROPPANT W/59,949# OF 7 PPG TO PERFS. REVERSE OUT W/DIESEL. 18:14 RDMO DOWELL ARCO Alaska. Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~' K1(1D-126(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-126 FRAC, FRAC SUPPORT 0822980836.4 DATE DALLY WORK UNIT NUMBER 09/22/98 PERFORATE D SANDS 2128 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 13 YESI YES SWS-V ETRO MILE JON ES FIELD AFC# CC# Signed ESTIMATE AK9629 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 400 PSI 300 PSI 300 PSI 200 PSI 0 PSII 0 PSI DAILY SUMMARY ISWS PERFORATED D SANDS IN ONE RUN FROM 6060' TO 6090' W/2 1/8" EJ, 4 SPF, BH, 0 PHASED, DOWN. TAGGED SAND @ 6093' - 29' ABOVE B SAND TOP PERF.[Perf] TIME LOG ENTRY 10:00 SWS MIRU, HELD TGSM. MU SAFE GUN & PT LUB TO 3000#. 12:15 MIH W/30'- 2 1/8" ENERJET, 4 SPF, BH, 0 PHASED, DOWN, SAFE, MPD, CCL, WB, SWIVEL, HEAD. UNABLE TO GET BELOW 3400'. 14:00 POH & LD GUN, NOT FIRED. 15:15 MU SAME GUN W/SAFE, MPD, CCL, WB, ROLLER, WB, ROLLER, SWIVEL & HEAD. 16:00 MIH W/GUN AS ABOVE, CORR TO SWS JEWELRY LOG 8-25-98 & PERF D SANDS FROM 6060' TO 6090'. TAG SAND @ 6093' = 29' ABOVE TOP OF B SAND PERFS. 17:15 POH & LD GUN, ALL SHOTS FIRED. 18:15 RELEASE SWS (NO RIG DOWN NEEDED FOR NEXT JOB). ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~' K1(1D-126(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-126 FRAC, FRAC SUPPORT 0822980836.4 DATE DAILY WORK UNIT NUMBER 09/25/98 PUMP D-SAND FRAC (DATA FRAC) DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 14 NO] YES DS-GALLEGOS LIGENZA FIELD AFC# CC# Signed ESTIMATE AK9629 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 265 PSI 780 PSI 265 PSI 780 PSII 0 PSII 0 PSI DALLY SUMMARY PUMP D-SAND DATA FRAC. PUMPED BREAKDOWN 150 BLS OF WATER, 63 BBLS OF 50# HEC GEL AT 30 BPM. AVERAGE TREATING PRESSURE 5800 PSI. PUMP DATA FRAC, 37 BBLS OF 50# HEC GEL, 68 BBLS OF WATER @ 15 BPM. AVERAGE TREATING PRESSURE 2000 PSI. FINAL CLOSURE PRESSURE - 1080 PSI. REVESED OUT W/70 BBLS DIESEL. DOWELL COSTS WILL BE ADDED WHEN FRAC IS COMPLETE.[Frac-Refrac] TIME LOG ENTRY 08:00 MIRU DS, TGSM (JOB PLAN, RIG MOVE, TAPS SD, PINCH POINTS), PT 8100 PSI. REVERSE OUT 65 BBLS OF DIESEL. 09:50 PUMPED BREAKDOWN 150 BLS OF WATER, 63 BBLS OF 50# HEC GEL AT 30 BPM. AVERAGE TREATING PRESSURE 5800 PSI. PUMP 3 ONE BBL PULSE'S. ISIP=1040 PSI. 10:55 PUMP DATA FRAC, 37 BBLS OF 50# HEC GEL, 68 BBLS OF WATER @ 15 BPM. AVERAGE TREATING PRESSURE 2000 PSI. PUMPED 3 ONE BBL PULSE'S. FINAL CLOSURE PRESSURE = 1080 PSI. 12:15 REVERSE OUT 70 BBLS DIESEL. CLEAN RETURNS. 12:30 RDMO DOWELL. ARCO Alaska, Inc. KUPARUK RIVER UNIT ~, WELL SERVICE REPORT ,~ K1(1D-126(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-126 FRAC, FRAC SUPPORT 0822980836.4 DATE DAILY WORK UNIT NUMBER 09/27/98 PUMP D-SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 15 NOI NO DS-GALLEGOS LIGENZA FIELD AFC# CC# Signed ESTIMATE AK9629 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 348 PSI 740 PSI 348 PSI 740 PSI 0 PSII 0 PSI DAILY SUMMARY FRAC D-SAND. 63 BBLS 50# HEC GEL @ 5 BPM. 137 BBLS @ 15 BPM. 80 BBL OF 2# PPA @ 15 BPM. 267 BBLS OF 2-7# PPA @ 15 BPM. 15 BBLS 7-10# PPA @ 15 BPM. 15 BBLS 10# PPA @ 15 BPM. FLUSH 25 BBLS 50# HEC GEL & 7.7 BBLS DIESEL. SCREENED OUT W/10PPA AT PERFS. TOTAL PROP 56,450 LBS W/51,340 LBS TO THE PERFS. REVERSED OUT TUBING W/70 BBL OF DIESEL. AVERAGE TREATING PRESSURE= 2204 PSI. MAXIMUM TREATING PRESSURE= 6107 PSl.[Frac-Refrac] LOG ENTRY TIME 10:30 MIRU, TGSM, 17 PEOPLE ON LOCATION. PT TO 8000 PSI. 12:30 PUMP MAIN FRAC. 63 BBLS 50# HEC GEL @ 5 BPM. 137 BBLS @ 15 BPM. 80 BBL OF 2# PPA @ 15 BPM. 267 BBLS OF 2-7# PPA @ 15 BPM. 15 BBLS 7-10# PPA @ 15 BPM. 15 BBLS 10# PPA @ 15 BPM. FLUSH 25 BBLS 50# HEC GEL & 7.7 BBLS DIESEL. SCREENED OUT W/10 PPA PROP AT PERFS. 13:20 REVERSE OUT TUBING W/70 BBLS DIESEL. 13:50 RDMO DOWELL. [ i [ i SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-98483 Sidetrack No.Page1 of 2 BI; [11~= I :~"~ Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLING,CO- #245 Field KUPARUK RIVER UNIT Well Name & No. 1 D-PAD/1D#126/J1 Survey Section Name SPERRY SUN BHI Rep. WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -301.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. E/W -599.00 Magn. Declination 27.461 Calculation Method' MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft~ 30m~ lOm~ Vert. Sec. Azim. 243.18 ' Magn. to Map Corr. 27.461 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F'r) (DD) (DD) (FT) (FT) (FT) (FT) (Per lO0 FT). Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT ~, 22-JUN-98 MWD 121.00 0.00 0.00 121.00 121.00 0.00 0.00 0.00 0.00 0.00 8"MACH 1C-AKO-1.8deg. · 22-JUN-98 MWD 202.40 0.38 346.58 81.40 202.40 -0.06 0.26 -0.06 0.47 0.47 22~JUN-98 MWD 292.19 2.21 282.77 89.79 292.16 1.20 0.94 .-1182 2.31 2.04 8"MACH 1C-AKO-1.75deg. 22~JUN-98 MWD ' 379.82 6.38 270.06 87.63 379.53 6.85 1.31 -8.34 4.85 4.76 -14.50 22-JUN-98 MWD 469.99 10.52 261.66 90.17 468.71 19.13 O. 12 " ' -21.50 .4.7.8 4.59 -9.32 22-JUN-98 MWD 560.82 17.17 253.63 90.83 556.86 40.21 -4.86 -42.59 7.60 7.32 ' .-8.84 . 22-JUN-98, MWD 651.32 23.13 249.51 90.50 641.78 71.04 -14.86 -72.09 6.77 6.59 -4.55 22-JUN-98 ,MWD 742.27 28.12 246.29 90.95 723.76 110.22 -29.74 -108.47 5.69 5.49 ' -3.54 22-JUN-98 ~ MWD 831.72 33.40 244.27 89.45 800.61 155.92 -48.92 '-149.98· ' 6.01 : 5.90 -2.26 22-J U N-98 MWD 923.99 39.69 244.05 92.27 874.70 210.83 -72.86' -199.40 .6.82 6.82 -0.24 22-JUN-98 MWD 1014.75 44.72 243.84 90.76 941.91 271.77 -99.64 -254.16 5.54 . 5.54 -0.23 , 22-JUN-98 MWD. 1105.52 49.38 242.66 90.77 1003.74 338.19 -129.56 -313.46 5.22 5.13 ' -1.30 22-JUN-98 MWD 1196.02 53.35 242.35 90.50 1060.23 408.86 -162.19 -376.15 4.39~ .' 4.39 -0.34 "!' , 23-JU N-98 MWD 1291.99 58.02 243.12 95.97 1114.32 488.11 -198.48 -446.59 4.91 4.87 · 0.80 23-JUN-98 MWD 1386.57 . 62.37 244.46 94.58 1161.32 570.15 -234.70 -520.21 4.76 4.60 1.42 23-JUN-98 MWD, ' 1481.38 64.78 243.11 . 94.81 1203.51 655.04 -272.21 -596.37 2.84 2.54 . -1.42 23-J U N-98 MWD 1671.24 64.93 241.00 189.86 1284.19 826.86 -352.75 -748.19 1.01 · 0.08 -1.11 23-JUN-98 MWD 1861.15 65.38 241.06 189.91 1363.98 999.07 -436.22 -898.96 0.24 0.24 0.03 23-JUN-98 MWD 2050.11 64.98 243.20 188.96 1443.31 1170.53 -516.39 -1050.56 1.05 -0.21 1.13 23-JUN-98 MWD 2239.00 65.65 243.19 188.89 1522.20 1342.16 -593.78 -1203.74 0.35 0.35 -0.01 23-JUN-98 MWD 2521.62 65.15 243.83 282.62 1639.85 1599.12 -708.40 -1433.73 0.27 -0.18 0.23 23-JUN-98 MWD 2805.68 65.40 244.09 284.06 1758.66 1857.12 -821.67 -1665.55 0.12 0.09 0.09 , __ 23-JUN-98 MWD 3184.02 63.51 241.02 378.34 1921.83 2198.38 -978.91 -1968.46 0.89 -0.50 -0.81 , _ I _;.q~mllinl~H- II~ ...'. I~'~nl~allnt~Z~,m [IkNfftl~[l~! I I i~'~K~m~1. SURVEY CALCULAT,ON AND F,ELD WORKSHEET Job No. 0450-98483 Sidetrack No. __ Page 2 of 2 Company ARCO ALASKA. INC. Rig Contractor & No. PARKER DRILLING.CO- #245 Field KUPARUK RIVER UNIT · Well Name & No. 1D-PAD/1D#126/J1 Survey Section Name SPERRY SUN BHI Rep. I~kr~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -301.00 Grid Correction 0.000 Depths Measured From:' RKB ~ MSL ~ SS~ Target Description Target Coord. E/W Slot Coord. E/W -599.00 Magn. Declination 27.461 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft~ 30m~ lOm[-] Vert. Sec. Azim. 243.18 Magn. to Map Corr. 27.461 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I'VD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F~ .(DD) ' (DD) (FT) (F'I') (FT) (FT) (Per ~o0 FT) Drop (-) Left (-) 23-JUN-98 MWD 3467.51 63.90 242.19 283.49 2047.42 2452.44 -1099.76 -2192.04 0.39 0.14 0.41 . 8"MACH 1C-AKO-1.75deg. .' 23-JUN-98 MWD 3751.18 63.22 243.18 283.67 2173.73 2706.42 -1216.32 -2417.71 0.39 -0.24 0.35 23-JUN-98 MWD 3940.34 65.60 243.85 189.16 2255.43 2877.01 -1292.39 -2570.40 1.30 1.26 0.35 ,. 24-JUN-98 MWD 4217.98 66.19 242.66 277.64 2368.82 3130.43 -1406.44 -2796.71 0.45 0.21 -0.43 24-JUN-98 MWD' 4510.66 65.05 242.03 292.68 2489.63 3.396.98 -1530.17 -3032.83 · 0.44 -0.39 . -0.22 24-JUN-98 MWD 4797.i 9. 64.34 · 242.84 286.53' 2612.11 3655.99 -1650.04 -3262.45 0.36 .0.25 ' '.0;28 , 24-JUN-98 MWD 5080.93 63.25 242.20 · 283.74 2737.40 3910.54 -1767.50 -3488.31 0.43 '. " -0.38 '-0.23 * . . 24-JUN-98 MWD 5174,07: 55;74 241,35 93,14 2784,65 3990,71 -1805,41 -3558,97 8.10 -8,06 -0,91 .' 24-JUN-98 MWD 5269.00 50,37 239,83 94.93 2841,69. 4066,47 -1842,62 -3625,05 5,80 -5,66 * ~1,60 25-JUN-98 MWD 5365,11 45,32 . 236,61 ~ 96,11 2906,18 4137,42 -1880,05 -3685.63 5.81 . -5.25 '. -3,35 · . 25-JUN-98 MWD . 5458,63 40,38 237,32 93,52 2974,72 4200,62 -1914,73 -3738,92 5,31 -5,28 0,76 I 25-JUN-98 MWD 5550,43 35,98 236,32 91,80 3046,87 4257,01, -1945,75 -3786,41 4,84 -4.79 ' -1,09 25-JUN-98 MWD 5643.73 30,92 237,91 93,30 ~ 3124,69 4308,12 -1973,70 -3829,56 5,50 -5,42 ' 1,70 , . 25-JUN-98 MWD 5742,42' 26,36 243,04 98,69 3211,29 4355,31 -1997,12 -3870,59 5,25 -4.62 .. 5,20 8"MACH 1C-AKO-1,4 DEG, 25-JUN-98 MWD 5836,30 21,68 243,39 93,88 3297,02 4393,51 -2014,35 -3904,69 4,99 -4,99 * 0,37 25-JU N-98 MWD 5930,80 20,15' 244,15 94,50 3385,29 4427,24 -2029,27 -3934,95 1,64 .~1,62 0,80 26-JUN-98 MWD 6119,98 19,30 244,09 189.18 3563,37 4491,08 -2057,13 -3992,40 0,45 -0,45 , -0,03 · 26-JUN-98 MWD 6310,68 18,68 ' 244,88 190,70 3743,69 4553,12 -2083,87 -4048,39 0,35 -0,33 * 0,41 26-JUN-98 MWD · 6499,43 17,62 · 246,47 188,75 3923,05 4611,86 -2108,11 -4101,96 0,62 -0,56 0,84 26-JUN-98 MWD 6652,08 17,08 245,96 152,65 4068,75 4657,31 -2126,46 -4143,61 0,37 -0.35 -0.33 PROJECTED TO TD · , 26-JUN-98 MWD 6716,00 17,08 245,96 63,92 4129,85 4676,07 -2134,11 -4160,76 0,00 0,00 0,00 CLO DIST=4676,15'AZI=242,85 · · · · I I i iii - ii ii ri Ft I I_1_ I I~1 13 13-Jul-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 D-126 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 6,716.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company Kuparuk Unit Kuparuk 1D 1D-126 S UR VEY REPORT 8 July, 1998 Your Reft AP1-500292288900 Last Survey Date 26-June-98 Job# AKMM80264 KBE- 111.3' DRILLING SERVICES ORI.$'I. AL RECEIVED 'JUN ? 2. 1998 A~a~a Oil & Gas Cam. Cmnmission Am~o~age Survey Reft svy38 Sperry-Sun Drilling Services Survey Report for 1D-126 Your Ref: API-500292288900 Kuparuk Unit Measured Depth (ft) Incl. 0.00 121.00 202.40 292.19 379.82 469.99 560.82 651.32 742.27 831.72 923.99 1014.75 1105.52 1196.02 1291.99 1386.57 1481.38 1671.24 1861.15 2050.11 2239.00 2521.62 2805.68 3184.02 3467.51 3751.18 3940.34 4217.98 4510.66 4797.19 0.000 0.000 0.380 2.210 6.380 10.520 17,170 23.130 28.120 33,400 39.690 44.720 49,380 53.350 58.020 62.370 64.780 64.930 65.380 64.980 65.650 65.150 65.400 63.510 63.900 63.220 65.600 66.190 65.050 64.340 Azim. 0.000 0.o00 346.580 282,770 270.060 261.660 253,630 249.510 246,290 244,270 244,050 243.840 242.660 242.350 243.120 244.460 243.110 241.0o0 241.060 243.200 243.190 243.830 244.090 241.020 242.190 243.180 243,850 242.660 242.030 242,640 Sub-Sea Depth (ft) -111.30 9.70 91.10 180.86 268.23 357.41 445.56 530.48 612.46 689.31 763.40 830.61 892.44 948.93 1003.02 1050.02 1092.21 1172.89 1252.68 1332.01 1410.90 1528.55 1 647.36 1810.53 1936.12 2062.43 2144.13 2257.52 2378.33 2500.81 Vertical Depth (ft) -111.30 9.70 91.10 180.86 268.23 357.41 445.56 530.48 612.46 689.31 763.40 830.61 892.44 948.93 1003.02 1050.02 1092.21 1172.89 1252.68 1332.01 1410.90 1528.55 1647.36 1810.53 1936.12 2062.43 2144.13 2257.52 2378.33 2500.81 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 540.31S 2.19 E 5959363.92 N 560490.68 E 0.00 540.31S 2.19 E 5959363.92 N 560490.68 E 0.000 0.00 540.04 S 2.13 E 5959364.18 N 560490.62 E 0.467 -0.06 539.37 $ 0.37 E 5959364.84 N 560488.85 E 2,306 1.20 538.99 S 6.15W 5959365.17 N 560482.33 E 4,852 6.85 540.18 S 19.31W 5959363.87 N 560469.18 E 4.779 19.13 545.17 S 40.40W 5959358.71 N 560448.13 E 7.604 40.21 555,16 S 69.90W 5959348.48 N 560418.71E 6.766 71.04 570.05 S 106.28W 5959333.31 N 560382.45 E 5,694 110.22 589.22 S 147.79W 5959313.79 N 560341.10 E 6.014 155.92 613.17 S 197.21W 5959289.46 N 560291.87 E 6.818 210.83 639.94 S 251.97W 5959262,24 N 560237.33 E 5.544 271.77 669.86 S 311.26W 5959231.84 N 560178.28 E 5.221 338.19 702.50 S 373.96W 5959198.71 N 560115.85 E 4,395 408.86 738.79 S 444.40W 5959161.85 N 560045.70 E 4,911 488.11 775.00 S 518.02W 5959125.04 N 559972.37 E 4,761 570.15 812.52 S 594.18W 5959086.92 N 559896.52 E 2.844 655.04 893.05 S 746.00W 5959005.16 N 559745.36 E 1,009 826.86 976.52 S 896.77W 5958920.48 N 559595.26 E 0,239 999.07 1056.69 S 1048.37W 5958839.09 N 559444.31 E 1.049 1170.53 1134.09 S 1201.55W 5958760.46 N 559291.76 E 0.355 1342.16 1248.71S 1431.54W 5958644.00 N 559062.70 E 0.271 1599.12 1361.98 S 1663.36W 5958528.87 N 558831.79 E 0,121 1857.12 1519.21S 1966.27W 5958369.20 N 558530.16 E 0.886 2198.38 1640.07 S 2189.85W 5958246.55 N 558307.57 E 0.395 2452.44 1756.63 S 2415.51W 5958128.18 N 558082.84 E 0.394 2706.42 1832.70 S 2568.21W 5958050.88 N 557930.77 E 1.298 2877.01 1946.75 S 2794.51W 5957935.01N 557705,39 E 0.445 3130.43 2070.47 S 3030.64W 5957809.39 N 557470.27 E 0.436 3396.98 2190.34S 3260.26W 5957687.67 N 557241.61 E 0.356 3655.99 Comment Kuparuk 1D ContinueS.. 8 July, 1998 - 14:36 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-126 Your Ref: API-500292288900 Kuparuk Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 5080.93 63.250 242.200 2626.10 2626.10 5174.07 55.740 241.350 2673.35 2673.35 5269.00 50.370 239.830 2730.39 2730.39 5365.11 45.320 236.610 2794.88 2794.88 5458.63 40.380 237.320 2863.42 2863.42 5550.43 35.980 236.320 2935.56 2935.56 5643.73 30.920 237.910 3013.39 3013.39 5742,42 26.360 243.040 3099.99 3099.99 5836.30 21.680 243.390 3185.72 3185.72 5930.80 20.150 244.150 3273.99 3273.99 6119.98 19.300 244.090 3452.07 3452.07 6310.68 18.680 244.880 3632.39 3632.39 6499.43 17.620 246.470 3811.75 3811.75 6652.08 17.080 245.960 3957.45 3957.45 6716.00 17.080 245.960 4018.55 4018.55 2307.81S 3486.12W 5957568.40 N 557016.71 E 0.434 3910.54 2345.71 S 3556.78W .5957529.92 N 556946.36 E 8,101 3990.71 2382.92 S 3622.86W 5957492.18 N 556880.58 E 5.799 4066.47 2420.35 S 3683.44W 5957454.26 N 556820.30 E 5.811 4137.42 2455.03 S 3736.73W 5957419.16 N 556767.29 E 5.307 4200.62 2486.06 S 3784.22W 5957387.75 N 556720.05 E 4.840 4257.01 2514.01 $ 3827.37W 5957359.45 N 556677.13 E 5.504 4308.12 2537.43 S 3868.41W 5957335.70 N 556636,29 E 5.246 4355.31 2554.65 S 3902.50W 5957318.21 N 556602.33 E 4.987 4393.51 2569.57 S 3932.76W 5957303.05 N 556572.19 E 1.644 4427.24 2597.44 S 3990.21W 5957274.72 N 556514.97 E 0,449 4491.09 2624.17 S 4046.20W 5957247.53 N 556459.19 E 0.352 4553.12 2648.41S 4099.77W 5957222.86 N 556405.83 E 0.620 4611.86 2666.77 S 4141.42W 5957204.17 N 556364.32 E 0.368 4657.31 2674.42 S 4158.57W 5957196.39 N 556347.24 E 0.000 4676.07 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. -,~ ~'he Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 243.180° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6716.00ft., The Bottom Hole Displacement is 4676.15ft., in the Direction of 242.846° (True). Comment Projected Survey Kuparuk 1D Continued... 8 July, 1998 - 14:36 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-126 Your Ref: API-500292288900 Kuparuk Unit Kuparuk 1D Comments Measured Depth 0.00 6716.00 Station Coordinates TVD Northings Eastings (ft) (ft) -111.30 540.31 S 2.19 E 4018.55 2674.42 S 4158.57 W Comment Tie-on Survey at Surface Projected Survey 8 July, 1998 - 14:36 - 4 - DrillQuest 9~4~98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11476 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: West Sak (Reservoir Analysis Logs) Well Job # Log Description Date Color RF Sepia Floppy Pr. int---~ Disk WS 1D.126 ~--~.-IO'~ 98373 REPROCESSEDUSlT 980629 WS 1D-127 C~,~-I©c~ 98373 REPROCESSEDUSlT 980707' WS 1D-131 ~- I~© 98373 REPROCESSEDUSlT 980714 f' ,~. S I G N E D: --. ~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. WELL LOG TRANSMITTAL To: State of Alaska Julv 15, 1998 .Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 _..-~ ~<-. /;) ~ REz MWD Formation Evaluation Logs 1D- 126(J1), .~-MM-80264 1 LDWG formatted Disc with verification listing. APl#: 50-029-22889-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMrFrAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: 'i~'d k' I/I; 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser industries, Inc. WELL LOG TRANSMiTFAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 July 22, 1998 RE: MWD Formation Evaluation Logs 1D-126 (J1), ,~aK-MM-80264 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of~ ,Mi Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, Al~; 99518 1D-126 (J1): 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22889-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22889-00 1 Blueline 1 Folded Sepia 1 Blueline I Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser industries. Inc. TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June I1, 1998 Mr. Thomas McKav Shallow Sands Team Leader ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re~ Kuparuk River Unit 1 D- 126 ARCO Alaska. Inc. Permit No: 98-108 Sur. Loc.: 301'FNL. 599'FEL, Sec. 23, TllN. R10E. UM Btmhole Loc: 2416'FNL. 499'FWL, Sec. 23, T11N. R10E, UM Dear Mr. McKav: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission max, witness the test. Notice max' be given by contacting the Commission petroleum field inspector on the North Slope pager at 659~3607~t~~~~. Chairman BY ORDER OF THE COMMISSION dlffenclosures CC: Department of Fish & Game. Habitat Section w/o encl. Departmcnt of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill lb Type of Well Exploratory C~ Stratigraphic Test E~ Development Oil X Re-Entry Deepen Service E] Development Gas E] SingleZone X Multiple Zone E] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 70' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 301' FNL, 599' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 2342' FNL, 643' FWL, Sec. 23, T11N, R10E, UM 1D-126 #U-630610 At total depth 9. Approximate spud date Amount 2416' FNL, 499' FWL, Sec. 23, T11 N, R10E, UM 6/12/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 D-124 6707' MD 499' @ TD feet 30' @ 100 feet 2560 4092' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 64.96° Maximum surface 1366 psig At total depth 1795 psig (TVD) 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD -I'VD (include stage data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOE 6666 41' 41' 6707' 4092' 700 Sx Arcticset III & 311 Sx Class G & 60 sx AS I 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~ i!! ::''~'' I ' Conductor :~- ~ ? ~/;: F~ Surface ~ ~'- Intermediate L. Liner Perforation depth: measured ~.~i~!$~8. 0ii ,~:~ f~.: r, .... true vertical .anchorage 20. Attachments Filing fee X Property plat [] BOP Sketch X[] Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21' I hereby certify that the f°reg°ing !true '~nd cOrr'ect tO the best Of my knOwledge Signed~~'}~4 ~ ~~ Title Shallow Sands Team Leader Date { [ Commission UseOnl¥ PermitNumber APl numb~ KJ ~ I Approval date.. ~, ~ I See cover letter for ~ ..../~"~/~)~ I 50-4::~-- ~~ 7 I ~'"//~ ¥ ~I other requirements uonaition§ of approval Samples required' [-~ Yes [~ No Mud Icg required F; Yes ,~ No Hydrogen sulfidemeasures E~Yos ~No Directional surveyrequired ~Yes E~ No Required workingpressureforBOPEi_.Jr'--12M~ ~ 3M ~] 5M BI 10M BI 15M Other: Orlgln8! blgtk~u David W. Johnston by order of/'_ //' Approved by Commissioner the commission Date ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor June 1,1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-126 West Sak Phase lA Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1 D pad. The well is designed including hydraulic fracturing stimulation treatments using resin coated type proppant material. The stimulation procedure is designed to control sand production expected in these unconsolidated formations. The well is planned as a producer well using a progressive cavity ESP ("PCESP") to artificially lift the well. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak Pool Rules. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU and West Sak wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-126, such as shallow gas. There have been eight (10) Kuparuk wells and (14) West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diver[er system only. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is June 12, 1998. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. ~- Thomas A. Brockway ,~ Operations Drilling Engineer Attachments: cc: West Sak 1D-126 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK6 General Procedure: Drill and Case Plan for West Sak 1D-126 (J1) Frac-for-Sand Control Producer 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. . Move in / rig up drilling rig. Install diverter & function test same. Spud and directionally drill 9-7/8" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. o , . . 10. 11. Run and cement 7-5/8" 29.7# L80 BTC casing to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3,000 psi. Pick up 6-3/4" mill tooth bit with 3-1/2" drill pipe and collars. Trip in and drill out stage collar. Clean out to PBTD. Shut in BOP's and pressure test casing to 2,000 psi for 30 minutes per AOGCC regulations. Record results. Swap well over to non-freezing completion brine. Filter brine to desired level. Trip out. Pick up 3-1/2" tubing deadstring and TIH. Circulate filtered brine to desired level. Hang tubing in wellhead, install back pressure valve, and nipple down BOP stack. Nipple up and pressure test production tree. Secure well. 12. Release rig. 1 D-126 Page I TAB,06/01/98,v1 Completion Plan for West Sak 1D-126 Frac-for-Sand Control Producer Four-Stage, Frac-for-Sand Control Completion (Off Ri_q Fracs) General Procedure: Well Preparation 1. Rig up frac equipment on well, and pressure test lines and production tree. Pull back pressure valve, and pressure test tubing and annulus. . Stage 1 3. Rig up E-line unit, and make correlation run as required with GR/CCL to correlate logs for perforating. NOTE: The number of stages frac'd may decrease from four (4) to three (3) depending on log results and final completion design strategy. Rig up thru-tubing perf guns for Stage I frac job which includes the West Sak A2 sands. RIH with perf guns, and position guns on depth. 4. Perforate Stage 1 overbalanced, and POOH with E-line. 5. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage I interval. 6. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 1 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 1 from Stage 2 to follow. Pressure test sand plug as required. 7. RIH with slickline and confirm sand top above Stage I perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 2 8. Rig up thru-tubing perf guns for Stage 2 frac job which includes the West Sak A3 sands. RIH with perf guns, and position guns on depth. 9. Perforate Stage 2 overbalanced, and POOH with E-line. 10. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 2 interval. 11. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 2 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 2 from Stage 3 to follow. Pressure test sand plug as required. 12. RIH with slickline and confirm sand top above Stage 2 perfs. Use CTU as required to jet sand plug top to desired PBTD. StaRe 3 13. Rig up thru-tubing perf guns for Stage 3 frac job which includes the West Sak A4 and B sands. RIH with perf guns, and position guns on depth. 14. Perforate Stage 3 overbalanced, and POOH with E-line. 1D-126 Page 2 TAB,06/01/98,v1 15. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 3 interval. 16. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 3 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 3 from Stage 4 to follow. Pressure test sand plug as required. 17. RIH with slickline and confirm sand top above Stage 3 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 4 18. Rig up thru-tubing perf guns for Stage 4 frac job which includes the West Sak D sands. RIH with perf guns, and position guns on depth. Perforate Stage 4 overbalanced, and POOH with E-line. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 4 interval. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 4 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 4 from tubing tail. Pressure test sand plug as required. RIH with slickline and confirm sand top below tubing tail. Use CTU as required to jet sand plug top to desired PBTD. Set back pressure valve in tubing hanger, pressure test production tree and secure well. Release frac, E-line, CTU, and slickline equipment as required. Deadstrin.q, Clean Out Well, Run ESP and Production Tubing MIRU completion rig on well. Nipple down production tree and nipple up BOP stack on wellhead. Install 3-1/2" rams unless VBR's are available. Pressure test BOP stack to 3,000 psi. Pull back pressure valve. Pull tubing hanger and circulate well to clean brine as required. TOH and lay down deadstring. Pick up rock bit and casing scraper and TIH with workstring. Clean out sand plugs, proppant, and perforating debris to PBTD below base of West Sak interval. Circulate well to clean brine. TOH with workstring. Pick up Centrilift ESPCP (progressive cavity ESP) motor, seal assembly, and tubing crossover on 3-1/2" production tubing. Run in well with ESPCP motor assembly with power cable and data gathering information wire attached to tubing. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 19. 20. 21. 22. 23. Pull 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. 1 D-126 Page 3 TAB,06/01/98,v1 34. Position ESPCP at desired depth, set tubing hanger and run electrical penetrators through same. 35. Make surface electrical connections as required, and set back pressure valve in tubing hanger. 36. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. 37. Release rig and turn well over to production. Note: For E-line retrievable ESPCP pumps, the pump components may be run in the well with slickline after the completion rig has released from the well. 1 D-126 Page 4 TAB,06/01/98,v1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-126 (J1) Drillinc~ Fluid Type Extended Bentonite Slurry Drillinq Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.7-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12 % Drillinq Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes:. Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A combination surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface using a stage (DV) collar. The stage collar will be placed approximately 200 feet TVD below the base of the permafrost interval. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-126 well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. 1D-126 Page I TAB,06/01/98,v.1 Based on actual well test data from the nearby WS1-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/fi, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.7 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,482' MDFFVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base to surface, the following MASP can be computed: MASP = (3903 ft)(0.46 - 0.11 psi/fi) = 1366 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 7-5~8" combination surface / production casing in this well, the BOP stack will be installed and tested to 3,000 psi. The stage collar will then be drilled out and the well cleaned out to PBTD. At that time, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi as well. The 7- 5~8" 29.7# LB0 BTC-MOD casing to be used has a burst rating of 6,890 psi; 70 % of this burst rating is 4,823 psi. A deadstring will then be run in the well in preparation for off-rig perforating and fracture stimulation treatments. A completion rig would then return to the well following fracture stimulation work to remove the deadstring, and to install the ESP pump, power cable, heat trace, and production tubing. Drillinc~ Area Risks: Drilling risks in the West Sak 1D-126 area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted 1/'" overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D-126. Well Proximity Risks: The nearest existing well to West Sak 1D-126 is WS 1D-124 (G3). As designed, the minimum distance between the two wells would be 30' at 100' MD. Annular Pumpinq Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-1D. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-126 surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 7-5~8" combination surface / production casing and prior to the drilling rig moving off of the well. 1 D-126 Page 2 TAB,06/01/98,v. 1 I V cr. ot.d by ~.=h For: BROCKWAY Dais platted : 2G-May-fl8 Plot Reference is WS 1D-126/dl Ver~. Caordinotes are ~n feet reference slot ~12~. True Vertical Depths ere reference RKB (Perker 350 0 35O 7OO 1050 1400 i750 2100 2450 2800- 3150 5500 3850 4200 4550 , 35O IAH ,CO A aska, InE 1 ructure : Pad 10 Well : J1 Field : Kuporuk River Unit Location : North Slope, AlaskaI <--West (feet) 4200 3850 .3500 3150 2800 2450 2100 1750 1400 1050 700 350 0 I I I I I I I I I I I I I I I I I I I I t I I I I ESTIMATED SURFACE LOCATION: 270 Az 301' FNL, 599' FEL Begin Turn to Targe~.(~) SEC__. 23__2, T~I J N__, R~I OE EOC 243.18 AZIMUTH ..-'"'~Bose Permafrost 4524' (TO TARGET) / uase~ermorrost ...-'"'Beoin Anole Droo I 2342' FNL, 643' FWL /~..~.~'op Ug~u Son'ds ' [ SEC. 23, T11N, RIOE TD -- -[VD=3628 ~ ~ a' I TD LOCATION: TMD=6215 RKB ELEVATION: ] 2416' FNL, 4gg' FWL DEP=4524 l SEC. 23, T11N, RIOE SOUTH 2041 WEST 4038 KOP TVD=300 TMD=300 DEP=O 5.goBEGIN TURN TO TARGET TVD=270 TMD=383 DEP=3 7.56 DLS: 6.00 deg per 100 ft 23.52 2g.49 35.47 41.46 53.44 EOC TVD=1174 TMD=1392 DEP=552 350 350 0 35O 700 1050 1400 1750 2100 2450 MAXIMUM ANGLE 64.96 DEG PERMAFROST TVD=1629 TMD=2467 DEP=1525 BEGIN ANGLE DROP TVD=2743 TMD=5099 DEP=5910 64.89 52.89 T/ UGNU SNBS TVD=2896 TMD=5378 DEP=4142 40.89 DLS: 6.00 deg per 100 ft 54.89 28.89 22.89 END ANGLE DROP TVD=5293 TMD=5861 DEP=4407 T/ W SAK SNBS TVD=3482 TMD=6061 DEP=4473 TARGET A3 TVD=3628 TMD=6215 DEP=4524 TARGET ANGLE 19.25 DEG B/ W SAK SNDS -I-VD=3903 TMD=6507 DEP=4620 TI) - CSG PT TVD=4092 TMD=6707 I)EP=4686 t 350 i i I i i I i i I i I I I I i Ii I i 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 VerticalSection (feet)-> Azimuth 243.18 with reference 0.00 N, 0.00 E from slot #126 i i i i i i 4200 4550 4900 I V 4O 20 2O ~ 6o 0 J 80 100 120 140 160 18o 200 ARCO Alaska, C~ot~by~;.~h For: BROCKWAY Structure : P~d 1D Well : J1 Pio~; Reference i~W$ 1D-126/J1 Vets. ~5. ~ Field : Kup~ruk River Unit Locotion : North Slope, Alosko <- Wesl (*eeo 340 320 300 280 260 240 220 200 180 160 140 120 1 O0 80 60 40 20 0 20 40 60 80 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 I I ~ I I soo ................. 90o ..................... 2ooo ~oo ~oo ~o 1000 ~ .................500 40 12OO 11 O0 20 500 1~00 2200 600 ...... ~ 0 ~oo ...... ¢~' ~oo ~oo ...... eeo 1600 .-'"'""' , .......... 'goo . 7o,¢.,'" uu ..-'" ...... 800 ..-" /' .................... ~zuu ........ ' ...... ~~oo ....... ~'ooo ......... ,.....' ~ . ....... . ....... //" .-'""'"' 110~ ' 200 . 120 ~-' ///900 /'/' ' , '/ ~0 /"~;; ./'~0 ~00 1600 / '" gOO 140 /' ./ ,' ,/ ~ ............ ~ 1400 ,,,' ~oo.,, ~ / ,,' ....-"' ...,'"' oo, ,,poo . oo 5 3;0' 3hO ' 3;0 ' 2;0' 260 2;0' 2~0' 2;0 180 ' 1;0 ' 140' 120 ' 1;0 80 6~ 4'0 ' 2'0 0 20 40 60 8' ' ' ' ' ' ' ' '0 , 200 <- West (feet) 4O 80- 120 - 160 - 200 24O 280 520 360 ARCO A~aska, I~c~ C~eotod by f~.ch For: BROCKWAY Dote plotted : 20-Moy-98 Plot Ref ...... is WS 1D-126/J1 V .... #5. Ccordinot ..... in feet ref ....... lot #126. <- West Structure : Pad 1D Well : J1 Field : Kuparuk River Unit Location : North Slope, Alaska 1080 1040 1000 960 920 880 840 800 760 720 680 640 600 560 520 480 440 400 360 520 280 240 200 .......................... i4oo ........... 80 ................ ........... ~ .......--'"'" ........-""1100 ////' 2200 ..-'"'" ..-"'" .//' ..... ~S'oo ......... ,.,'"~ooo ¢'~ 200 ~~__~¢ ........................ ....---'"" ..... .~.;;;;- ....'""'""' ...-"" ....... i'400 ....... /ffi O0 /' 150( ,... /'(~oo lOOO ....-"'"' ""' 1300 // ~{5oo ................. .,'" -'"' 400 ./ ./ ,// 1100 440 ......... '1'~00 ...... {~; /'/'/'/1200 /"/"/~400 11 ~1 600 440 / / 480 480 ./' /. .........-"' /'//' /'//' 800 ,,,/~ / 560 ~o ~.,(~oo ~,, 600 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 i i i i i i i i 600 1080 1040 1000 960 920 880 840 800 760 720 680 64.0 600 560 520 480 440 400 360 520 280 240 200 <- West (feet) 0 280 '-~ ~2o --i- z6o I ¥ c~o~d by ~inch For: BROCKWAY Dote plotted : 20-Moy-98 Plot Reference is WS 1B-126/J1 Vers, #5. Coordinot ..... in feet rcf ....... lot #126. ARCO Alaska, Inc. Structure : Pad 1D Well : J1 Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 4800 4600 4400 ¢200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 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 I I I I I I 200 1500 1700 1900 ..................... 21 O0 2~oo ....... 23oc 200 2,30..o. 250t '"' 2500 270( / '""~'"' 2700 ............... 290 ~ 1500 ..-"~.-'" 2900 ............... '1 ~ .---'.--" 1500 400 3900 3500 .3_J_C?.O_ ............... 350C ~' . ..... :; ..... // J~'-- 1..7- '0' '0:;': - ' ' i'~ 00 1 300~,,":,1'~3C~ 600 .--'"'..-'"' /"/'1300 t.o.o.,.%. ..... .....::..... · . ....... . 2100..-'" ..."' //;/' 1500 /130.8' 8O0 ....... . ...... 2300 ....... .... ..-- 2500. ....... . ....... /,,,'/,' / //~?'UU 1000 2700 ....... '-. ....... ..'"..'" 17oo/ /Ysod 30301 O0 1200 ..'"'" /',;";/ 3500 ,,,,, ^ ~ / 1800 ...'" 2900 /;;/ / ~uuu ' 2100 "' ,¥:/ 2500 ," / ..-'*' 31 O0 2307,;;;2~500 ,' 2000 ...-" 3300 ,, 700 / EZE] ..--'%7oo ,,/ '" ,,,':"::;/ 2700 ,' , / ,,;;" 3900 /'~1 O0 I' 2300 2200 ,4/ 2900 / 250,1/,,;, $1 O0 / ,, / /?,,ff,"~ / , 2400 2400 / /4'2900 /" ., 2500 2600 2600 I i i I i f i i i i I I I I I I I i I I II I I I I I I I I i I I I I I [~,~ i I 4800 4600 4400 4200 4000 3800 5600 3400 5200 000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 <- West (feet) o 2O0 4o0 600 800 1000 1200 1400 16O0 1800 2000 2200 I V ~r' ARCO Alaska, Inc. Pad 1D J1 slot #126 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : WS 1D-126/J1 Vets. #5 Our ref : prop2199 License : Date printed : 20-Ma¥-98 Date created : 16-Apr-97 Last revised : 20-Ma¥-98 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 17 58.355,w149 30 36.370 Slot Grid coordinates are N 5959363.700, E 560490.407 Slot local coordinates are 301.00 S 599.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEAR~%NCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PMSS <0-5462'>,,J3,Pad 1D PMSS <O-4778'>,,H4,Pad 1D PMSS <0-5015'>,,GT,Pad 1D PMSS <0 - 7340'>,,10,Pad 1D PMSS <556-7024'>,,9,Pad 1D MSS <3311-8200'>,,7,Pad 1D PGMS <O-8610'>,,6,Pad 1D PGMS <O-8930'>,,5,Pad 1D PGMS <O-7502'>,,4,Pad 1D PGMS <O-8070'>,,3,Pad 1D PGMS <O-9783'>,,2,Pad 1D PGMS <0-8365'>,,1,Pad 1D WS 1D-134/L5 Vets WS 1D-132/K4 Vets WS 1D-131/L3 Vets WS 1D-128/K2 Vets WS 1D-127-L1 Vets WS 1D-101/C5 Vets PMSS <1957-5265 #2,,LS,Pad 1D #2,,K4,Pad 1D #2,,L3,Pad 1D #2,,K2,Pad 1D #2,,L1,Pad 1D #3,,C5,Pad 1D >,,JS,Pad 1D WS 1D-108/A3 Vers. #3,,A3,Pad 1D WS 1D-104/A7 Vets. #3,,AT,Pad 1D WS 1D-103/B6 Vets. #3,,B6,Pad 1D WS 1D-102/A5 Vets. #3,,AS,Pad 1D 1D-D Version #2,,1D-D,Pad 1D 1D-F Version #2,,1D-F,Pad 1D Closest approach with 3-D Last revised Distance M.D. 1-Dec-97 89.3 300.0 9-Nov-97 103.1 560.0 13-Nov-97 214.2 720.0 28-Apr-98 255.0 100.0 29-Apr-98 165.0 120.0 6-Nov-97 177.5 640.0 13-Nov-97 62.0 20.0 13-Nov-97 57.5 300.0 4-Aug-92 177.6 383.3 4-Aug-92 298.0 20.0 4-Aug-92 417.8 383.3 10-Dec-97 537.9 383.3 17-Apr-98 209.0 480.0 17-Apr-98 135.0 240.0 17-Apr-98 120.0 240.0 17-Apr-98 30.0 300.0 17-Apr-98 15.0 240.0 21-Jan-98 493.0 280.0 24-Nov-97 145.8 604.9 22-Jan-98 373.0 280.0 21-Jan-98 448.0 280.0 21oJan-98 463.0 280.0 21-Jan-98 478.0 280.0 24-Nov-97 46.9 460.0 24-Nov-97 162.3 600.0 Minimum Distance method Diverging from M.D. 300.0 560 0 72O 0 100 0 120 0 6706 7 500 0 300 0 383 3 5973 9 383 3 383 3 480.0 240.0 240.0 300.0 240.0 280.0 604.9 6520.0 280.0 280.0 280.0 460.0 600.0 WS 1D-107/84 Vets. #1,,B4'~:d 1D 1D-B Version #3,,1D-B,Pad 1D WS 1D-151/Gll Vets. #1,,G11,Pad 1D WS 1D-138/K6 Vets. #1, WS 1D-161/L7 Vets. #1, WS 1D-160/K8 Vets. #1, WS 1D-159/L9 Vets. #1, WS 1D-157/K10 Vets. #1, WS 1D-156/J9 Vets #1, WS 1D-155/H8 Vets #1, WS 1D-154/J11 Vets #1, WS 1D-153/H10 Vets #1, WS 1D-150/F10 Vets #1, WS 1D-152/G9 Vets #1, WS 1D-149/F8 Vers #1, WS 1D-148/Ell Vets #1, WS 1D-147/E9 Vets #1, WS 1D-146/D10 Vets #1, WS 1D-145/Cll Vets #1, WS 1D-144/D8 Vets #1, WS 1D-143/C9 Vets #1, WS 1D-139/88 Vets #1, WS 1D-140/A9 Vets #1, WS 1D-142/810 Vets #1, WS 1D-141/Ali Vets #1, WS 1D-158/L11 Vets #1, PMSS <381-6092'>,,C7 PMSS <0-5126 >,,D6 PMSS <0-4850 >,,D4 PMSS <0-5047 >,,G3 PMSS <0-5205 >,,ET PMSS <0-5142 >,,E3 PMSS <0-4590 >,,ES PMSS <0-4515 >,,F4 PMSS <0-4530 >,,F6 PMSS <0-4414 >,,G5 WS 1D-136/J7 Vets. #1 TOTCO Sur~zey,,WS-8 WS1D-111/82 Vets. #3 WS 1D-112/A1 Vets #3 WS 1D-113/C1 Vets #3 WS 1D-114/D2 Vets #3 WS 1D-116/E1 Vets #3 WS 1D-122/F2 Vets #3 WS 1D-123/G1 Vets #3 WS 1D-125/H2 Vets, #3 WS 1D-110/C3 Vets. #3 ,K6,Pad 1D ,LT,Pad 1D ,KS,Pad 1D ,Lg,Pad 1D ,K10,Pad 1D ,Jg,Pad 1D ,HS,Pad 1D ,Jll,Pad 1D ,H10,Pad 1D ,F10,Pad 1D ,Gg,Pad 1D ,F8,Pad 1D ,Ell,Pad 1D ,E9,Pad 1D ,D10,Pad 1D ,C11,Pad 1D ,D8,Pad 1D ,cg,Pad 1D ,BS,Pad 1D ,Ag,Pad 1D ,B10,Pad 1D ,All,Pad 1D ,L11,Pad 1D ,Pad 1D .Pad 1D .Pad 1D .Pad 1D .Pad 1D .Pad 1D .Pad 1D .Pad 1D .Pad 1D .Pad 1D ,JT,Pad 1D .Pad 1D ,B2,Pad 1D ,Al,Pad 1D ,C1,Pad 1D ,D2,Pad 1D ,El,Pad 1D ,F2,Pad 1D ,Gl,Pad 1D ,H2,Pad 1D ,C3,Pad 1D 17-Apr- 97 24 -Nov- 97 15 -Apr- 97 16-Apr-97 16-Apr-97 16-Apr-97 16 -Apr- 97 15-Apr- 97 15-Apr- 97 15 -Apr- 97 15 -Apr- 97 15-Apr- 97 15-Apr- 97 15-Apr-97 15 -Apr- 97 15 -Apr- 97 15 -Apr- 97 15 -Apr- 97 15-Apr-97 15-Apr-97 15-Apr- 97 15-Apr- 97 15-Apr-97 15-Apr-97 15 -Apr- 97 16-Apr- 97 27-Jan-98 19-Jan-98 12-Jan-98 6-Jan-98 7-Jan- 98 30-Dec-97 22-Dec-97 16-Dec-97 19-Dec-97 8-Dec-97 10-Feb-g8 10-Feb- 98 22-Jan-98 22-Jan-98 22-Ja~- 98 26-Jan-98 26-Jan-98 26-Jan-98 26-Jan-98 26-Jan-98 22 -Jan- 98 388.0 75.7 240.7 272.0 359.2 346.3 333.5 308.5 296.4 284.5 273.0 261.8 230.9 251.0 221.6 213.0 205.2 198.1 192.0 186.9 182.9 178.9 178.0 180.0 178.4 320.9 434.5 405.0 360.0 30.0 210.0 240.0 194.5 150.0 135.0 120.0 233.4 281.5 328.0 283.0 268.0 253.0 223.0 103.0 87.2 13.1 343.0 300. 520. 300. 320. 300. 300. 260, 300. 300. 300. 300. 300. 300. 300. 300. 300. 300. 300. 300. 300. 300. 260. 300. 300. 260. 260. 280. 100. 100. 100. 100 180 383 100 100 100 660 800. 300. 240. 280. 26O 362 362 420 383 28O 0 0 8 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 3 0 0 0 0 0 0 0 0 0 5 5 0 3 0 6640 0 520 0 300 0 320 8 300 0 300 0 260 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300.0 300.0 300.0 300.0 5522.5 300.0 6185.7 260.0 300.0 300.0 260.0 260.0 280.0 100.0 100.0 100.0 100.0 180.0 383.3 100.0 100.0 100.0 660.0 800.0 300.0 240.0 280.0 260.0 362.5 362.5 420.0 6320.0 280.0 Wes' Sak 1 D-126 (J1) ProduCer Well Four (4) Stage Frac-for-Sand Control with 3-1/2" Deadstring 16" Conductor Casing @ 80' Weatherford Gemoco 754HO 7-5/6" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) 3-1/2" Tubing Deadstring 9.3~ L-80 EUE 8RD-Mod (to fmc through off-rig) 7-5/8" Casing Marker Joint 29.7# L-80 BTC-Mod (set +/- 50' above top perforation) D Sand Fmc'd with Resin Coated Proppant B + A4 Sands Frac'd with Resin Coated Proppant A3 Sand Frac'd with Resin Coated Proppant 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD Cemented to Surface (+/- 6707' MD / 4092' TVD) A2 Sand Frac'd with Resin Coated Proppant ARCO Alaska, Inc. TAB, 05/18/98, v. 1 Sak] D~] 26 (J ] )Prod ucer We~ FoUr (4)stage FraC-fOr'Sand COntro~ Completion 16" Conductor Casing @ 80' 3-1/2" Production Tubing 9.3# L-80 EUE 8RD-Mod Raychem Heat Trace (through permafrost) Weatherford Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) Power Cable for ESP Centdlift Camco 3-1/2" x 1" 'KBMM' Gas Lift Mandrel Arctic Lift 3500 psi Shear circulating valve preqoaded in GLM (cimu~ate well for freeze protection purposes) ESP Pump Section Centdlift ESP Gearbox Centrilift 7-5/8" Casing Marker Joint 29.7# L-80 BTC,Mod (set +F 50' above top perforation) ESP Motor Section Centdlift 7~5/8" Combination Surface/Production Casing, 29.7# L~80 BTC-MOD Cemented to Surface (+F 6707' MD / 4092' 'DC'D) D Sand Frac'd with Resin Coated Proppant B ~ A4 Sands Frac'd with Resin Coated Proppant A3 Sand Frac'd with Resin Coated Proppant A2 Sand Frac'd with Resin Coated Proppant ARCO Alaska, Inc. TAB, 05/18/98, KUPARUK RIVER UNIT- WEST SAK OPERATIONS 20" DIVERTER SCHEMATIC 5 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. 4 3 2 HCR MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THATAN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA. INC.. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"- 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINF- THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20'- 2000 PSI ANNULAR PREVENTER. TWM, 9/1~97 4 3 13 5/8" 5000 PSI BOP STACK West Sak Operations - Producer Wells 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 THE IADC REPORT. THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD, ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5, OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSi AND 30(X3 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES. ENES. AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. & OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. -TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUTOF HOLE. CLOSE BUND RAMS AND TEST TO 3000 PSI FOR 3 MINUTE~. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESELAND ALL VALVES ARE SET IN THE DRILUNG POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSi FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILMNG SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2' TO 6' OR 4-1/2' TO 7' PIPE ODS AS APPROPRIATE. 1. 16'-STARTING HEAD 11'- 5000 PSI HORIZONTAL TUBING HEAD 3. 11' 5000 PSI X 135/8' 5000 PS! DOUBLE STUDDED ADAPTER/SPACER SPOOL 4. 13-5/8' - 5000 PSI X 13-5/8' - 5000 PSI SPACER SPOOL 5. 13-5/8' - 5000 PSI PIPE RAMS 6. 13-5/8'- 5(XX) PSI DRLG SPOOL W/ CHOKE AND KILL LINES 7. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP. BLIND RAMS ON BTM 8. 13-5/8' - 5000 PS! ANNULAR TWM, 9/22/97 D.S. 1-D ~' ~~ ~ '~ ~ ~ ' $URVEY j ~ : 111 ~ 14.15 ; ,~ 23~ . m 112~ ~ ~6~ ''~ ~ , ~CINI~ MAP ~ 117 ~ ~ ~e~ 4 ~ SCALE: I = I MILE 120~; 119 122~ 121 125 ~ 5 124 125~ 126 127~ 128 ~ Q 6 ' ~ , ~ 129 ~ 1~1 · 132 134 1~ LEGEND s~E SHE~ t 2 FOR NOTES ~O LO~TION , o EX/S~ conDucTors ~ LOUNSBURY · "AS-STAKED" CONDUCTOR LOCA nON ~/J~ ~ A ASSOC[ATES, INC. ~ "PROPOSED" CONDUCTOR LOCATION ~~E~NE~ P~N~S suRv~Yo~ AREA' 1D M~ULE XX UNIT' D1 ~ DRILL SI~ 1-D ARCO Alaska,Inc. ~ ~s~ s~x ,.~s~ ~.- ~ co. ouc~o,s AS-STAKED LOCA~ONS ~ ~.~ .o. I ..~... I~"~""~ "~ .~ ~ ~n~-~ I~': I"~v: .......... ~ 1 OF2 0 I~EV DATE BY CK APP DESCRIPTION APP DESCRIPTION --. r'-' DS1B .NOTES ~ ~. COORDINA~S SHO~ ARE A.S.P. ZONE 4. N.A.D. 2Z ~- ELEVA~ONS SHO~ ARE BRITISH PETROLEUM MEAN PIT C ~. CONDUCTORS ARE LOCATED ~THIN PROTRACTED 5ECDON5 ~~, '4 ~ 23. TO'SHIP." NOR~. RANGE 10 EAS~ U.M. ~'=)~ Pgs. 8-~4. . . ' ~ ~ SAK-1 5. DRILL SITE '-D G~ID NORTH IS ROTATED 00' O' 05 ,, ~ [~ ~ 5 S~1 ~.~ ~ST FROM A.S.P. ZONE 4 GRID NORTH. J~ ~. SEE DRA~NC NSK-3.5-1 FOR AS-BUILT LOCAnONS OF ~ CONDUCTORS ,-8: CEA-D,DX-6IO4D,O FOR CONDUCTORS 21 105,106,109,115.117-121,124,129,130.133 a 135; AND CEA-DIDX-6104DI3 FOR CONDUCTORS 9 ~ 10. ~ClNITY MAP Sc~E: ~"= wall A.S.P.s I LA TITUDE I LONGITUDE sec SEC. PAO O. No. 'Y' 'X'~ ~ ~ ~ E~E~ E~E~ Sec. 14, T. 11 N., R. IO E. F.S.L.F.E.L. ~08 ,,5,959,7~8.9 560,490.6 70' 18' 02.05" ~49' ~0' 36.28" 74' 596' 70.4' 62.4' t~O **~,959,708.9 560,490.6 70' 18' 0~.75" 149' 30' 36.28" 44' 596' 70.4' 66.5' l~1 **5,959,693.9 560,490.6 70' 18' 01.60" 149' ~0' 36.29" 29' 596' 70.4' 66.5' Sec. 23, T. 11 N., R. I O E. F.N.L.F.E.L. 1~2 ,,5,959,64&9 560,490.6 70' 18' of. t6" ~49' 30' 36.3o" 16' 597' 70.4' 63.1' 113 ,,5.959,6~3.9 560,490.6 70' 18' ol, o~" 149' 30' 36.3o" 3~' 597' 7o. 4' 63.2' 1~4 ,,5,959.6~&9 56o, 49o. 6 70' 18' oo. 87" 149' 30' 36.3o" 46' 597' 70.4' 63.2' 116 ** 5,959,588.9 560,490.6 70' I8' oo. 57" 149' 30' 36.3t' 76' 597' 70.4' 63.3' 122 5,959,469. o 560,490.7 70' 17' 59.39" ~49' 3o" 36.34" 196' 598' 7o. 5' 64.~" ~23 5,959,453.9 56o. 49o. 7 70' 17' 59.24" ~49' ~o' 36.~4" 2~1' 598' 70,4' 64.2' ~25 5,959,379.2 560,490.7 70' 17' 5&51' 149' 30' ~6.36" 286' 599' 70,3' 64.3' ~26 5,959.363.9 560,490.7 70' 17' ~.~6" 149' 30' 36.36" 3o1' 599' 70,3' 64.3' ~27 5,959,34&9 560,490.7 70' ~7' 5&21' ~49' 30' 36.36" 316' 599' 7o, 3' 64.3' 128 5,959.334.1 560,490.7 70' ~7' 5&o6" t49' ~o' 36.37" 331' 599' 70,3' 64.5' ~3~ 5,959,244. o 560,490.7 70' 17' 5z~8" t49' 30' 36.39" 42~' 600' 70,5' 69.9' 132 5,959,229.2 560,490.7 70' I7' 5Zo3" 149' 30' 36.39" 436' 600' 70,4' 69.8' ~34 5,959,153.8 56o, 49o. 8 70' ~7' 56.29" 149' 30' 36.41" 5~' 6o~' 70,5' 69.1' ~* Proposed Iocotion, work in progress [~ & ASSOCIATES, INC. ~ ENGINEERS P~NE~ SUR~O~ ARIA: 1D ~0DUL[: ~ UNIT: D1 DR tL C~DD FILE NO. m ........ ,. -. I I o · WELL PERMIT CHECKLIST FIELD & POOL COMPANY INIT CLASS PROGRAM: exp [] dev~redrll [] serv [] wellbore seg [] ann. disposal para req [] UNIT# / )] ~ 0 ON/OFF SHORE ADMINISTRATION ENGINEERING DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-'day wait ........... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. N Y N Y N N GEOLOGY 30. 31. 32. 33. 34. ANNULAR DISPOSAL 35. APPR DATE Conductor string provided ,~ N Surface casing protects all known USDWs ........... ~ N CMT vol adequate to circulate on conductor & surf csg ..... N CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... ~ N Casing designs adequate for C, T, B & permafrost ....... ~,~ N Adequate tankage or reserve pit ................. N If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... ~ N Drilling fluid program schematic & equip list adequate ..... ~y.Y N BOPEs, do they meet regulation ................ .Y N BOPE press rating appropriate; test to psig. ,Y N Choke manifold complies w/APl RP-53 (May 84) ........ N Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. , Y Per}nit can be issued w/o hydrogen sulfide measures ..... Y Data presented on potential overpressure zones ........ Seismic analysis of shallow gas zones ............. ., Seabed condition survey (if off-shore) ............. Con, tact.nam, e/phone for weekly progress reports ...... ,/ Y N l explora~ory only] With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... ..~ N (B) will not contaminate freshwater; or cause drilling waste. ~ Y N to surface; (C) will not impair mechanical integrity of the wel! u.~d"for d!sposal; Y N (D) will not damage producing formation or im_j;~q~recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.25"2'6r 20 AAC 25,412. , Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: BE~~[~ WM DWJ ~St~- JDH / RNC ' "' co Comments/Instructions: M:cheklist rev 05~29~98 dlf:C:\msoffice\wordian\diana\checklist Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Thu Jul 09 11:21:30 1998 Reel Header Service name ............. LISTPE Date ..................... 98/07/09 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/07/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER (WESTSAK POOL) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) MWD RUN 1 AK-MM-80264 S. BURKHARDT D. LUTRICK 1D-126 (J1) 500292288900 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 09-JUL-98 MWD RUN 2 AK-MM-80264 S. BURKHARDT D. LUTRICK MWD RUN 3 AK-MM-80264 S. BURKHARDT D. BREEDEN 23 liN 10E 301 599 KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .00 111.80 70.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 6716.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL DEPTHS ARE DRILLER'S DEPTHS. DEPTH SHIFTING OF THE MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN MIKE WERNER AND ALI TURKER ON 07/02/98. MWD IS PDC. 3. MWD RUNS 1 THROUGH 3 ARE DIRECTIONAL WITH DUAL GAivRvLA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. WELL 1D-126 REACHED A TOTAL DEPTH OF 6716'MD, 4130'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SPIALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 121.0 6677.0 ROP 122 5 FET 123 5 RPD 123 5 RPM 123 5 RPS 123 5 RPX 123 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: 6717.0 6669.5 6669.5 6669.5 6669.5 6669.5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 121.0 286.0 2 286.0 5706.0 3 5706.0 6716.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 121 6717 3419 13193 121 GR 8.8082 116.248 58.2647 13113 121 ROP 7.0112 783.761 233.953 13190 122.5 RPX 1.4614 2000 73.8308 13093 123.5 RPS 1.3626 2000 88.3264 13093 123.5 RPM 1.1194 2000 121.354 13093 123.5 Last Reading 6717 6677 6717 6669.5 6669.5 6669.5 RPD 1.1663 2000 119.754 13093 FET 0.1024 13.3933 0.65743 13093 123.5 123.5 6669.5 6669.5 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 6717 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUNSqARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 121.0 249.0 ROP 122.5 285.5 FET 123.5 241.0 RPD 123.5 241.0 RPM 123.5 241.0 RPS 123.5 241.0 RPX 123.5 241.0 $ LOG HEADER DATA DATE LOGGED: 22-JUN-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 286.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 121.0 286.0 .4 .4 TOOL NUMBER P0946CRG6 P0946CRG6 9.880 9.9 SPUD MUD 175.00 32.0 8.5 75O 7.8 1.350 1.570 4.500 1.850 14.5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 RPX MWD 1 RPS MWD 1 RPM MWD 1 RPD MWD 1 FET MWD 1 FT/H 4 1 68 OHMS4 4 1 68 OHM~ 4 1 68 OHM~ 4 1 68 OHMM 4 1 68 HOUR 4 1 68 8 12 16 20 24 28 Name DEPT GR ROP RPX RPS RPM RPD FET Min 121 12 1461 29 8219 18 1098 22 2997 25 2734 32 8552 0.247 Max Mean Nsam 285.5 203.25 330 76.4521 32.4298 257 305.397 173.958 327 205.242 70.1098 236 1748.56 163.745 236 2000 862.685 236 2000 1008.29 236 0.7724 0.532415 236 First Reading 121 121 122 5 123 5 123 5 123 5 123 5 123 5 Last Reading 285.5 249 285.5 241 241 241 241 241 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 285.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 242 5 RPD 242 5 RPM 242 5 RPS 242 5 RPX 242 5 GR 250 5 ROP 287 0 $ LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: STOP DEPTH 5663 0 5663 0 5663 0 5663 0 5663 0 5670 5 5707 0 25-JUN-98 ISC 5.06 CIM 5.46 MEMORY 5706.0 286.0 5706.0 2.2 66.2 TOOL NUMBER P0946CRG6 P0946CRG6 9.880 9.9 LSND 190.40 278.0 8.3 5OO 5.4 7.000 5.099 7.000 8.000 37.8 $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 2 API 4 1 68 ROP MWD 2 FT/H 4 1 68 RPX MWD 2 OHM~ 4 1 68 RPS MWD 2 OHM~ 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHM~ 4 1 68 FET MWD 2 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name DEPT GR ROP RPX RPS RPM RPD FET Min 242.5 8 8082 7 0112 1 4882 1 3626 1 1194 1 1663 0 1024 Max 5707 111.59 783.761 2000 2000 2000 2000 8.6429 Mean Nsam 2974.75 10930 56.5015 10841 255.145 10841 85.9773 10842 101.397 10842 126.112 10842 121.005 10842 0.564843 10842 First Reading 242.5 250.5 287 242.5 242.5 242.5 242.5 242.5 Last Reading 5707 5670.5 5707 5663 5663 5663 5663 5663 First Reading For Entire File .......... 242.5 Last Reading For Entire File ........... 5707 File Trailer Service name ..... ' ........ STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 5660 5 5660 5 5660 5 5660 5 5660 5 5669 0 5707 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUMANGLE: 6669 6677 6717 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: STOP DEPTH 6669 5 6669 5 6669 5 6669 5 5 0 0 26-JUN-98 ISC 5.06 CIM 5.46 MEMORY 6716.0 5706.0 6716.0 17.1 26.4 TOOL NUMBER P0946CRG6 P0946CRG6 9.880 9.9 LSND 192.30 289.0 8.2 MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHN94) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 5OO 5.4 6.000 3.996 7.000 6.500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 RPX MWD 3 OHM~ 4 1 68 12 4 RPS MWD 3 OHMM 4 1 68 16 5 RPM MWD 3 OHMM 4 1 68 20 6 RPD MWD 3 OHMM 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8 37.8 Name DEPT GR ROP RPX RPS RPM RPD FET Min 5660.5 23.483 15 0069 1 4614 1 6189 1 7975 1 9527 0 1618 First Max Mean Nsam Reading 6717 6188.75 2114 5660.5 116.248 71.0167 2017 5669 379.76 129.934 2020 5707.5 99.9045 8.85736 2019 5660.5 92.679 9.1017 2019 5660.5 90.4524 8.86351 2019 5660.5 80.1293 8.86952 2019 5660.5 13.4043 1.20539 2019 5660.5 Last Reading 6717 6677 6717 6669.5 6669.5 6669.5 6669.5 6669.5 First Reading For Entire File .......... 5660.5 Last Reading For Entire File ........... 6717 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/07/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/07/09 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File