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191-126
II.' RECEIVED STATE OF ALASKA 0 C T 2 2 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANC la.Well Status. Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑✓ Suspended ❑ lb.Well Class. 20AAC 25 105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ El WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2 Operator Name. 5 Date Comp,Susp, 12 Permit to Drill Number ConocoPhillips Alaska, Inc orAband.: February 8,2014 191-126/313-042 3.Address: 6.Date Spudded 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 January 20, 1992 50-029-22221-00 • 4a Location of Well(Governmental Section) 7.Date TD Reached 14 Well Name and Number: ,o.u.t/ Surface: 2211'FNL,2328'FEL,Sec. 17,T13N, RO9E,UM January 26, 1992 KRU 3Q-03 • IILS Top of Productive Horizon. 8. KB(ft above MSL): 63'RKB 15.Field/Pool(s). 1303'FNL, 1951'FWL,Sec.8,T13N, R9E,UM GL(ft above MSL): 21.7'AMSL Kuparuk River Field Total Depth. 9.Plug Back Depth(MD+TVD): 1134'FNL,3429'FEL,Sec.8,T13N, R9E, UM 9353'MD/6540'TVD Kupuruk River Oil Pool 4b Location of Well(State Base Plane Coordinates,NAD 27): 10 Total Depth(MD+TVD) 16 Property Designation Surface: x-516008 y- 6025861 Zone-4 9640'MD/6758'TVD ADL 373301, 255i 1., TPI: x-514975 y- 6032046 Zone-4 11 SSSV Depth(MD+TVD) 17.Land Use Permit. Total Depth. x-514875 y- 6032215 Zone-4 1927'MD/1792'TVD 4162 18.Directional Survey Yes El No❑✓ 19 Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD (Submit electronic and printed information per 20 AAC 25 050) N/A (ft MSL) 1720'MD/1593'TVD 21 Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25 071): 22 Re-drill/Lateral Top Window MD/TVD none not applicable 23 CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 42' 120' 42' 120' 24" 1875#Poleset 9.625" 36# J-55 42' 5210' 42' 3906' 12.25" 1240 sx PF E,495 sx Class G 7" 26# J-55 42' 9605' 42' 6732' 8" 212 sx Class G 24 Open to production or injection? Yes ❑ No ❑✓ 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) r41111. 41." 4.5" 9163' 9172'MD/6403'TVD 9361'-9401'MD 6546-6576'TVD26 ACID,FRACTURE,CEMENT SQUEEZE,+TETC � • t���!� Was hydraulic fracturing used during completion? Yes❑ No Q u � DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED I;.� none : 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure - Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press 24-Hour Rate-> 28 CORE DATA Conventional Core(s)Acquired? Yes ❑ No El Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed) Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE SCANNED - - E [[ ..- I i, S � 4 Form 10-407 Revised 10/2012 v i--c__ 2 /G// CONTINUED ON REVERSE D ii' 1410s Sub riginal only - ipt3 RBDM3 JAN - 6 2015 ICI 29. GEOLOGIC MARKERS(List all formations and mai Nes encountered). 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 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 1720' 1593' needed,and submit detailed test information per 20 AAC 25 071 Top Kuparuk C 9357' 6543' Bottom Kuparuk C 9368' 6552' Top Kuparuk A 9368' 6552' Bottom Kuparuk A 9430' 6599' N/A Formation at total depth: Kuparuk A 11 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact: .Gary Eller @ 263-4172 Email J.Gary.Eller@conocophillips.com Printed me Dan V haus Title CTD Engineering Supervisor + I Signature L— Q�U Phone 263-4372 Date V4�2k I � INSTRUCTIONS 111 General: This for 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 10/2012 • � D.Venhaus CTD Engineering Supervisor • Drilling&Wells P.0.Box 100360 RECEIVED Anchorage,AK 99510-0360 ConocoPliiflips Phone: 907-263-4372 OCT 22 2014 October 20, 2014 AOGCC AOGCC Commissioner 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Subject: Revised Completion Report for 3Q-03 PTD#191-126 Dear Commissioner: Attached for your review is the revised completion report for 3Q-03. Correction to the original completion report include the revised bottomhole location data in box 4a and 4b. This package should be added to the data we already sent with the original completion report which includes the final directional survey, daily operations summary and a schematic. If you have any questions, please feel free to call me at anytime. Sincerely, D. n ausb CTD ineering Supervisor CPAI Drilling DV/JGE/skad 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. n Other, No/Type OVERSIZED ' . [] Logs .of various kinds [] Other COMMENTS: Scanned by: Beverly Dianna t athan Lowell ,. TO RE-SCAN Date: Is/ Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: IS~ ? i1- Y 'r 'ti STATE OF ALASKA r? ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND la.Well St-ttus: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ B WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: February 8,2014 191-126/313-042 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 January 20, 1992 50-029-22221-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 2211'FNL,2328'FEL,Sec. 17,T13N, RO9E,UM January 26, 1992 3Q-03 Top of Productive Horizon: 8. KB(ft above MSL): 63'RKB 15.Field/Pool(s): 1303'FNL, 1951'FWL,Sec.8,T13N, R9E,UM GL(ft above MSL): 21.7'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 1122'FNL, 1912'FWL,Sec.8,T13N, R9E,UM 9353'MD/6540'TVD Kupuruk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-516008 y- 6025861 Zone-4 9640'MD/6758'TVD • ADL 373301 TPI: x-514975 y- 6032046 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-514935 y- 6032227 Zone-4 1927'MD/1792'TVD 4162 18.Directional Survey: Yes ❑ No❑✓ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1720'MD/1593'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD none not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 42' 120' 42' 120' 24" 1875#Poleset 9.625" 36# J-55 42' 5210' 42' 3906' 12.25" 1240 sx PF E,495 sx Class G 7" 26# J-55 42' 9605' 42' 6732' 8" 212 sx Class G 24.Open to production or injection? Yes ❑ No B 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) 4.5" 9163' 9172'MD/6403'TVD 9361'-9401'MD 6546'-6576'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No Q DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED none %AIMED APR 2 5 2014 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE RB®MS APR 18 24 Form 10-407 Revised 10/2012 CONTINUED ON REVE SE "1414 11/1,4//y Submit original only Ver 4/13/1,4, .. �� ✓G 29.GEOLOGIG MARKERS(List all formations and ma,. .rs encountered): 30. 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 1720' 1593' needed,and submit detailed test information per 20 AAC 25.071. Top Kuparuk C 9357' 6543' Bottom Kuparuk C 9368' 6552' Top Kuparuk A 9368' 6552' Bottom Kuparuk A 9430' 6599' N/A Formation at total depth: Kuparuk A 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic p 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. \c v 4 I o$14 Contact: J.Gary Eller @ 263-4172 Email: J.Gary.Elleraconocophillips.com Printed Name - 1�G.11 It/Cf ht KS Title: CTD Engineering Supervisor �[ Signature �/..44t--tf-- Phone 263-4924- L/3 7 Date ( - INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 10/2012 1 KUP PROD 3Q-03 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(3 MD(ftKB) Act Btm(ftKB) (.,....S+akp1 500292222100 KUPARUK RIVER UNIT PROD 54.83 6,700.00 9,640.0 -•- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date DEVIATED-30-03,3/17/2014 10'.06:36 AM SSSV:NIPPLE 180 12/24/2012 Last WO. 9/15/2013 40.99 1/28/1992 Vertcel schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,424.0 12/16/2013 Rev Reason:GLV C/O hipshkf 3/17/2014 HANGER 38.0-L. J COSI ng Strings ,u,+",m„u,,,u""muun"u,""""nm,ru"me",w" '''''"4.09 Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.835 42.2 5,210.0 3,903.5 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread Window for'A'sidetrack 7 6.276 9,359.0 9,365.0 6,5492 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread Ali, /1,4.1k. PRODUCTION 7 6.276 42.2 9,614.4 6,736.6 26.00 J-55 BTC MOD CONDUCTOR; 0-4 Tubing Strings Tubing Description 'String Ma...l ID(in) !Top(ftKB) 'Set Depth(ft..J Set Depth(ND)(...I Wt(lb/ft) 'Grade 'Top Connection TUBING WO 41/2 3.958 38.0 9,16311 6,3963 12.60 L-80 IBT-M NIPPLE;1,926.8 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top'nal(") Item Des Com (in) 38.0 38.0 0.00 HANGER TUBING HANGER 3.958 1,926.8 1,791.7 37.97 NIPPLE SCSSSV,TRM-4PE-CF w/3.813""DB"NIPPLE 3.813 GAB LIFT;3,117.4 9,145.1 6,382.6 40.13 LOCATOR BAKER LOCATOR 3.870 9,146.4 6,383.5 40.09 SEAL ASSY BAKER SEAL ASSY 3.870 Tubing Description l String Ma...'ID(in) 'Top(ftKB) 'SetDepth(ft..'Set Depth((TVD)(...l Wt(lb/ft) !Grade 'Top Connection STACK PACKER 4 1/2 3.958 9,152 1 9,300 3 6,500.3 12.60 L-80 IBT-M GAS LIFT,5.045.6 4 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top!nein Item Des Com (in) 9,152.1 6,387.9 39.98 PBR BAKER 80-47 PBR 3.870 L 9,172.0 6,403.1 40.14 PACKER BAKER PREMIER PACKER 3.870 9,223.2 6,442.0 40.40 NIPPLE HES"X"PROFILE NIPPLE 3.813" 3.813 9,296.7 6,497.5 40.85 WLEG WIRELINE GUIDE 3.958 SURFACE;42.25,210.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl ---. Top(ftKB) (ftKB) rt Des Com Run Date ID(in) 9,353.0 6,540.1 40.78 WHIPSTOCK Whipstock for'A'sidetrack in 7" 2/7/2014 GAS LIFT;6,523.3 -THRU TBG Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/f GAS LIFT'7,690.2 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 9,361.0 9,368.0 6,546.1 6,551.4 C-1,A-1,3Q- 2/15/1992 4.0 IPERF 41/2"Csg Gun;180 03 deg.phasing 9,368.0 9,401.0 6,551.4 6,576.4 C-1,A-1,3Q- 2/15/1992 4.0 IPERF 4 1/2"Csg Gun;180 03 deg.phasing GAS LIFT;8,642.1 Mandrel Inserts Sl ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com • 3,117.4 2,606.8 CAMCO KBG-2- 1 GAS LIFT GLV BK 0.156 1,284.0 3/14/2014 GAS LIFT;9094.9 r r 1R 2 5,045.6 3,801.5 CAMCO KBG-2- 1 GAS LIFT GLV BK 0.188 1,324.0 3/14/2014 1R 3- 6,523.3 4,702.1-CAMCO KBG-2- 1 GAS LIFT OV BKO-3 0.000 0.0 3/15/2014 1R -- 4 7,6902 5,408.4 CAMCO KBG-2- 1 GAS LIFT DMY BK 0.000 0.0 1/26/2014 LOCATOR;9,145.1 - 1R 5 8,642.1 6,022.7 CAMCO KBG-2- 1 GAS LIFT DMY BK-5 0.000 0.0 9/132013 SEAL ASSY;9,146.41 R PBR;9,152.1 - 6 9,094.9 6,344.3 CAMCO KBG-2- 1 GAS LIFT DMY BK 0.000 0.0 3/13/2014 1R Notes:General&Safety PACKER;9,1720 End Date Annotation 1 11/29/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 NIPPLE;9,223.2 14 WLEG;9,296.6 Slotted Uner'A"lateral;9,239.2- 11,69101 WHIPSTOCK-THRU TBG; ' 9,353.01 'PERF;9.361 0-9,368,0 Window tar'A'sidetrack;9,359.0 l -9,365,0 IPERF;9,368 0-9,401.0 PRODUCTION;42.2-9,614.4 a. K § k o\ 03CO =wp 5E \ )(\ ® 0 \ ° )\Ti h.ci //) G . � . \ §§ 0 c ° . % .-- \ § \ e » . e5/)\ 2 _2@_, ae - \ \ ) ."a. > / _ =f ` c � \ G N o/{�) u CO .R - 0 § e-= "" § _ )\ / §j% /\fZ $_ / §m §/\�A e 2 {} 0 §\ -J �0 3 { \ƒ sf 0- o - §[ 0 // »{ \/ � �c ea^-co cF) ,< t}\ 03 2 Y= e 4% « £5 }#a= )1-----'\ri \ \/ \j \in \ �^ °.F \° ° /}S\ ` `0)\%i #a> /\/ 1 § ail . E _ ________/2 0 f Ill U) ... Oy'yyM I- I— — �-- 0 ƒLLo § c § 'a ' in En \\ f® 27 Cs1 0. C.1 }§ \§ _ kCO a )q \f §~ §j§ \\ /} 4) 3Q-0" ''RE-RIG WELL WORK SUMMARY DATE SUMMARY 9/25/2013 SET 3.78"CATCHER @ 9120' SLM. PULLED SHEAR VLV&SET DV@ 7690' RKB; PULLED DV& SET OV@ 6523' RKB; PULLED 1"DV @ 5046' RKB. IN PROGRESS. 9/26/2013 SET GLV @ 5046' RKB; PULLED DV&SET GLV @ 3117' RKB; PULLED CATCHER @ 9120'SLM; BAIL DRILLING MUD f/9120' SLM -9185' SLM. IN PROGRESS 9/27/2013 RAN 3" PUMP BAILER AND BAILED FROM 9185'TO 9189' SLM (UNABLE TO EQUALIZE PLUG). IN PROGRESS 9/28/2013 BAIL FILL FROM 9219'-9223 RKB; ATTEMPT TO EQUALIZE XX PLUG @ 9223' RKB. IN PROGRESS. 9/29/2013 BAIL MUD; EQUALIZED AND MADE TWO ATTEMPT TO PULL XX PLUG @ 8223' RKB. IN PROGRESS. 9/30/2013 ATTEMPT TO PULL XX PLUG @ 8223' RKB. IN PROGRESS. 10/1/2013 PULLED XX PLUG FROM 9188'SLM. IN PROGRESS. 10/2/2013 TAGGED @ 9342' SLM. MEASURED BHP @ 9340' SLM: 4331 PSI. COMPLETE. 12/5/2013 TAGGED @ 9377'SLM. MEASURED BHP @ 9398' RKB: 3260 PSI. GAUGED TBG TO 3.79"TO 9285' RKB. ATTEMPTED SET SS, UNABLE TO PASS SSSV; APPARENT TAR/ASPHALTENES. IN PROGRESS. 12/6/2013 BRUSHED & FLUSHED TBG. PULLED DV, REPLACED w/OV @ 7690' RKB. PULLED OV, REPLACED w/ GLV @ 6523' RKB. BLED IA PRESSURE TO CONFIRM GL INTEGRITY. COMPLETE. 12/16/2013 TAG FILL @9424' SLM (EST 24' OF RAT HOLE); MEASURE BHP (3615 psi) @ 9398' RKB. JOB COMPLETE 1/4/2014 (PRE-CTD)TIFL PASSED, TREE VALVE TEST PASSED. 1/22/2014 EXERCISED SSSV @ 1926' RKB. BRUSHED &GAUGED TBG TO 3.75"TO 9223' RKB. IN PROGRESS. 1/26/2014 FUNCTION TESTED SSSV. SET 3.81"XX PLUG W/GAUGES @ 9223' RKB. SET CATCHER ON XX PLUG. PULLED OV FROM 7690' RKB, SET DV @ SAME. PULLED GLV FROM 6523' RKB. IN PROGRESS. 1/27/2014 SET DV @ 6523' RKB. PULLED GLVs @ 5045' & 3117' RKB, SET DVs @ SAME. PULLED DV FROM 9095' RKB. LOADED TBG & IA WITH 250 BBL INHIB SW&80 BBL DSL CAP. COMBO MIT 2500 PSI, GOOD. IN PROGRESS. 1/28/2014 SET 2000 PSI CSG SHEAR SOV @ 9095' RKB. MIT TBG 2000 PSI, PASSED. PULLED CATCHER FROM 9190' SLM. PULLED 3.81"XX PLUG & GAUGES FROM 9223' RKB. FINAL BHP: 3164 PSI. READY FOR BPV. ConocoPhiIIips Time Log & Summary Welly-Jew Web Reporting Report Well Name: 3Q-03 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 2/5/2014 6:00:00 PM Rig Release: 3/5/2014 8:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/01/2014 24 hr Summary Released from 2G-13 00:00 01:00 1.00 0 0 MIRU MOVE CTOP P Bleed off N2, Blow down rig lines and Putz while still on 2G pad. 01:00 04:30 3.50 0 0 MIRU MOVE CTOP P PJSM, R/U and unstab CT from injector and secure to storage reel 04:30 08:00 3.50 0 0 MIRU MOVE CTOP P Load out 2"ct reel and load 2 3/8" CT string 08:00 11:00 3.00 0 0 MIRU MOVE CTOP P Change out gripper blocks to 2 3/8" Work on BOPE swap, 11:00 14:30 3.50 0 0 MIRU MOVE CTOP P PJSM, R/U crane and swap goosenecks 14:30 19:00 4.50 0 0 MIRU MOVE CTOP P Install inner reel iron, Pressure Bulkhead continue with BOPE prep for swap 19:00 00:00 5.00 0 0 MIRU MOVE CTOP P Swap out stripper to 2 3/8, Hook up gooseneck hydraulics, Continue BOPE swap prep 02/02/2014 Complete reel swap to 2 3/8", Outfit injector for 2 3/8"CT, Nipple down stack components 00:00 06:00 6.00 0 0 MIRU MOVE CTOP P Continue working swap to 2 3/8"pipe 06:00 11:30 5.50 0 0 MIRU MOVE CTOP P Align gooseneck rollers,swap spacers to other side of rollers 11:30 18:00 6.50 0 0 MIRU MOVE CTOP P Pull test C/T grapple connector, Stab pipe in injector. Prep coil and install CTC, Pull test to 40K 18:00 00:00 6.00 0 0 MIRU MOVE CTOP P Install piper valve on new BOPE stack, Head up BHI UQC. Installed high capacity eline anchor pins for 5/16 cable.Tested wire all good. Removed fittings from old BOP and capped off. 02/03/2014 Prep for 2 3/8 ops 00:00 00:30 0.50 0 0 MIRU MOVE SFTY T Present/discuss spill presentation. Unable to move because of lack of Peak trucks. 00:30 06:00 5.50 0 0 MIRU MOVE MOB T Continue Demob/2 3/8 swap ops 06:00 18:00 12.00 0 0 MIRU MOVE MOB T Clean up gooseneck, removed worn rollers, Install choke line in cellar. Install quick connect bracket and lines for stripper. Rebuild,test, and install plug valve on cement line. Remove flow line and cap lines in the PUTZ. 18:00 00:00 6.00 0 0 MIRU MOVE MOB T' Continue Demob&2-3/8 pipe swap ops Page 1 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/04/2014 24 hr summary Move rig modules from 2G pad to 2Q-pad. Spot modules over 3Q-03, RU rig equipment. 00:00 02:00 2.00 0 0 MIRU MOVE MOB T Continue waiting on Peak equipment for rig move to 3Q-pad. 02:00 09:00 7.00 0 MIRU MOVE MOB P PJSM. Move off 2G-17, Stage on pad, hook up jeeps while C/O stack, load out shop 09:00 17:00 8.00 0 0 MIRU MOVE MOB P PJSM with transport drives. Move rig from 2G-Pad to 3Q-Pad. 17:00 21:00 4.00 0 0 MIRU MOVE MOB P MIRU CDR,spot module on 3Q-03. PJSM. Safe out walkways, stairs, berm cellar, and RU PUTZ. 21:00 00:00 3.00 0 0 MIRU MOVE MOB P PJSM. NU BOPS, deployment line, kill line, and choke lines. 02/05/2014 Continue new BOP stack installation, finish rigging up interconnect,steam, landings,and load pits with SW. Install new MP, Choke, and Koomey lines. Load coil and surface lines with seawater. 00:00 06:00 6.00 0 0 MIRU MOVE MOB P Continue to rig up new BOP stack lines, RU interconnect,steam, landings,tiger tank lines,and load pits. 06:00 18:00 12.00 0 0 MIRU WHDBO NUND P Complete post rig move checklist, Nipple up stack, MP Line. Install new choke line,API Spec, Plumb BOP to Koomy unit, Plumb HCR's, 18:00 00:00 6.00 0 0 MIRU WHDBO NUND P Continue install of Koomey lines. Load coil and surface lines with SW. Rig Accept @ 1800 hrs 02/06/2014 Found mutiple leaks during shell test, make repairs and continue test. Perform initial BOPE test,waived by AOGCC,test tiger tank line. Pull BPV,test PDL's, perform lack management, start install of coil connector. 00:00 02:00 2.00 0 0 MIRU WHDBO PRTS T Load coil, perform shell test,found mutiple leaks, made repairs, complete shell test. 02:00 14:00 12.00 0 0 MIRU WHDBO BOPE P Perform initial BOPE test 250/4,800 psi, annular 2,500 psi.Test waived by AOGCC(Lou Grimaldi)C-09 was fail pass with change out of valve 14:00 15:00 1.00 0 0 MIRU WHDBO PRTS P BOPE test complete, PT TT line. 15:00 19:51 4.85 0 0 MIRU WHDBO PULL P FMC here to pull BPV, suspend PDL PT ops, PJSM to pull valve, LD lubricator assembly, WHP=450 psi, attemp to bleed WHP down, pressure returns to 450 psi, perform closure test on SS SV, good test. 19:51 20:51 1.00 0 0 MIRU WHDBO PRTS P PJSM. PT PDL's 20:51 23:33 2.70 0 0 SLOT WELLPF CTOP P Perform slack management, meg test E-Line. 23:33 00:00 0.45 0 0 SLOT WELLPF CTOP P Install coil connector 02/07/2014 Complete coil connector, install UQC and test. MU BHA#1, TIH w/4.5"Whipstock assembly, release from whipstock @ 9,353', PUH, swap hole to used 9.8 ppg drilling mud.TOOH and LD BHA#1, PU/MU BHA#2, TIH w/milling assembly to 9,190'. 00:00 03:00 3.00 0 0 SLOT WELLPF CTOP P Complete coil connector, install UQC and test to 4,000 psi, install elevators. Page 2 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 05:15 2.25 0 0 PROD1 RPEQP1 PULD P PJSM. MU BHA#1,4.5"Whipstock assembly 05:15 12:15 7.00 0 9,130 PROD1 RPEQP1TRIP P TIH w/Whipstock assembly, pumping @ min. rate,open SCSSV. 12:15 12:51 0.60 9,130 9,402 PROD1 RPEQP1 DLOG P Log tie into K-1 for+3'correction, run CCL 12:51 13:27 0.60 9,402 9,370 PROD1 RPEQPITRIP P Move to setting depth while correlating logs 13:27 13:39 0.20 9,370 9,270 PROD1 RPEQP1WPST P At set depth,TOWS=9353, HS orientation,Shut EDC, See setting tool shift @ 4K, Set down 4K 13:39 16:39 3.00 9,270 85 PROD1 RPEQP1TRIP P Swap hole to 9.8 PPG used mud to mill window,Trip out 16:39 18:00 1.35 85 0 PROD1 RPEQP1PULD P At surface, PJSM, 150 PSI SIP, Shut SSSV, Bleed off, SSSV holding, Lay down BHA#1 18:00 21:36 3.60 0 105 PROD1 WHPST PULD P Crew change, check areas, install CTES counter,flow check. PJSM. PU/MU BHA#2, test MWD,stab on well. 21:36 00:00 2.40 105 9,190 PROD1 WHPST TRIP P TIH w/BHA#2 milling assembly, stop @ 100',open SSSV. Continue in hole for tie-in, K1 @ 9119', correction of+3.5'. RIH. 02/08/2014 Start milling casing exit @ 9,359'as per well plan to TD @ 9,371', make three ream passes, dry drift window. POOH w/BHA#2, PU BHA#3, high bend motor assembly. RIH w/BHA to 9,371',drill build section to 9,487', swap hole to new 10.0 ppg FloPro system @ 9,437',drilling build section in progress. 00:00 00:30 0.50 9,190 9,359 PROD1 WHPST TRIP P Continue in hole, close EDC,tag pinch point WS @ 9,359', TOWS= 9,355'. PUW=40K 00:30 02:57 2.45 9,359 9,362 PROD1 WHPST MILL P Start milling @ 1 fph, pumping 2.72 bpm @ 2865 psi, BHP=3670 psi, DHWOB=0.1 K 02:57 03:27 0.50 9,362 9,362 PROD1 WHPST MILL P Start time milling @ 1 fph,pumping 2.73 bpm @ 2915 psi, BHP=3670 psi, DHWOB=0.7K 03:27 06:15 2.80 9,362 9,365 PROD1 WHPST MILL P Begin Auto milling,call BOW at 9365,continue control milling for string reamer, 1FPH, 06:15 08:33 2.30 9,365 9,371 PROD1 WHPST MILL P Mill rathole to 9371.0,2.73 BPM @ 2773 PSI FS, BHP=3670 08:33 10:15 1.70 9,371 9,371 PROD1 WHPST REAM P Make 3 reaming passes, HS, 30R and 30L. Dry drift window, looks good 10:15 12:27 2.20 9,371 110 PROD1 WHPST TRIP P Trip out of well, PUW=40K following MP schedule 12:27 13:27 1.00 110 0 PROD1 WHPST PULD P At surface,S/I SSSV with 695 PSI WHP, PJSM lay down BHA on dead well, Mill out @ 3.79 No go,string mill out @ 2.79 no go 13:27 14:03 0.60 0 0 PROD1 DRILL SVRG P Service injector, reel, choke, and mud pump screens. Trouble shoot orian network to drillers computer 14:03 16:21 2.30 0 72 PROD1 DRILL PULD P P/U BHA#3, 3.8°AKO motor and 4.125"bi center. M/U to coil and surface test Page 3 of 21 Hunt, Jennifer L (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, April 08, 2014 11:20 AM To: Ferguson, Victoria L (DOA) Cc: Eller, J Gary (J.Gary.Eller@conocophillips.com); Roby, David S (DOA); Bettis, Patricia K (DOA); Hunt, Jennifer L (DOA) Subject: RE: 3Q-03(PTD 191-126); 3Q-03A(PTD 213-016); 3Q-03AL1(PTD 213-017); 3Q-03AL 1-01(PTD 213-027) Victoria, To document this unusual situation,the following note and email messages have been placed in AOGCC's well history files for KRU 3Q-03 (PTD 191-126), 3Q-03A(PTD 213-016), 3Q-03AL1(PTD 213-017), and 3Q-03AL1-01(PTD 213-027) and in AOGCC's RBDMS database for each of these well branches. ConocoPhillips Alaska Inc. (ConocoPhillips)failed to notify the AOGCC before making a change to proposed plug-for- redrill operations in KRU 3Q-03 (PTD 191-126). Rather than plugging existing perforations in KRU 30-03 prior to redrilling the well, ConocoPhillips instead installed a flow-around whipstock. The result of this unapproved change is that the KRU 3Q-03A, 3Q-03AL1 and 3Q-03AL1-01 well branches are all improperly named and have been assigned incorrect API numbers. To change the names and API numbers for these well branches after-the-fact would be unduly confusing, so AOGCC has decided to administratively abandon KRU 3Q-03 (even though it is still contributing to production) and to report all future production from these well branches against KRU 3Q-03A, Permit Number 213-016, API Number 50-029-22221-01-00. Accordingly, the current status of KRU 3Q-03 has been changed in AOGCC's RBDMS database to Administratively Abandoned (Code ADMA) effective 4/8/2014 as documented in the attached email messages. Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 SCANNED APR 2 5 2014 Fax: 907-276-7542 From: Ferguson, Victoria L (DOA) Sent: Tuesday, April 08, 2014 10:04 AM To: Roby, David S (DOA); Davies, Stephen F (DOA); Bettis, Patricia K (DOA) Cc: Eller, J Gary (J.Gary.EllerOconocophillips.com) Subject: FW: 3Q-03(PTD 191-126); 3Q-03A(PTD 213-016); 3Q-03AL1(PTD 213-017); 3Q-03AL1-01(PTD 213-027) This note is to document that we will administratively abandon well 3Q-03 and no production will be allocated to 3Q- 03. Instead production will be allocated to 3Q-03A. Please note that physically 30-03 is actually open to production. Please make a note in RBDMS. Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferquson(a alaska.gov 1 From: Ferguson, Victoria L (DOA) Sent: Tuesday, April 08, 2014 9:21 AM To: Eller, J Gary (J.Gary.Eller@conocophillips.com) Subject: 3Q-03(PTD 191-126); 3Q-03A(PTD 213-016); 3Q-03AL1(PTD 213-017); 3Q-03AL1-01(PTD 213-027) Gary, We have reviewed the following sundry/PTDs and work completed: 3Q-03 plug for redrill 191-126 313-042 2/8/13 30-03 workover to change completion/pkr 191-126 no sundry required na 3Q-03A drill lateral 213-016 2/8/13, 1/17/14 3Q-03AL1 drill lateral 213-017 2/8/13, 1/17/14 3Q-03AL1-01 drill lateral 213-027 2/28/13, 1/17/14 The scope of the plug for redrill on 3Q-03 changed from a plugging of the perforations to a flow around whipstock after the workover was completed. Prior to drilling 30-03A, a new sundry for 3Q-03 was required for the change in scope. Since 30-03 was planned to remain open to production, the numbering/names of the laterals would have changed.The change in whipstock type for 3Q-03 was not approved.The naming and numbering of the laterals will not change in our system. Continue to use the current naming/numbering. Notes will be made to each of the well files outlining the situation. This oversight causes difficulty with our record keeping system including the production reporting system and well files and should not be repeated. Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave, Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferquson(a7alaska.gov 2 f t STATE OF ALKA RECEIVED AL.A OIL AND GAS CONSEV ATIONCOMItION REPORT OF SUNDRY WELL OPERATIONS OCT 15 2013 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other ]""" (� Alter Casing r Pull Tubing P Stimulate-Frac r Waiver Time Extension °�+ Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development j Exploratory r 191-126 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic "' Service 50-029-22221-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25512,373301 3Q-03 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9640 feet Plugs(measured) 9223 true vertical 6756 feet Junk(measured) none Effective Depth measured 9516 feet Packer(measured) 9172 true vertical 6664 feet (true vertical) 6403 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16" 120' 120' SURFACE 5170' 9.625 5210' 3906 PRODUCTION 6573' 7" 9605' 6732 r Perforation depth: Measured depth: 9361'-9401' SCANNED NOV 1 3 2013 True Vertical Depth: 6548-6578' Tubing(size,grade,MD,and TVD) 4.5, L-80, 9163 MD,6396 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PACKER @ 9172 MD and 6403 TVD SSSV-CAMCO DB SSSV @ 1927 MD and 1792 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation 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 shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil j7 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND 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: none Contact Brett Packer aa,265-6845 Email J.Brett.Packeraconocophillips.com Printed Name Brett Packer Title Wells Engineer Signature '7e/'' . 7( 4.L— Phone:265-6845 Date AV/V43 VW— (1V RBDMS OCT 17 /o// //3 Form 10-404 Revised 10/2012 Submit Original Only KUP PROD • 3Q-03 ConocoPhiilips s Y' , wen Attributes Max angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(RKB) Act Btm(ftKB) ,„,,,,,,,,,,,p, 500292222100 KUPARUK RIVER UNIT PROD l 54.83 6,700.00 9,640.0 °°• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED-30-03,10/4/2013 AM SSSV:NIPPLE I 1801 12/24/2012 Last WO: 9/15/2013 40.99 1/28/1992 Ven�cal scnematc(aclualj Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,457.0 2/20/2013 Rev Reason:WORKOVER haggea 9/27/2013 J HANGER'38.0--°��t Casing Strings rig .... Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 42.2 5,210.0 3,903.5 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 42.2 9,614.4 6,736.6 26.00 J-55 BTC MOD Tubing Strings Tubing Description String Ma...ID(in) Top(RKB) Set Depth(R..i Set Depth(ND)(...Wt(lb/ft) Grade Top Connection I TUBING WO 4 1/2 3.9581 38.0 9,163.1 6,396.3 12.60 L-80 IBT M I. CONDUCTOR;43.0-121.0 Completion Details N in IID Top(RKB) Top(ND)(RKB) Top Inc/(°)_ Item Des Corn (in) NIPPLE;1,926.8 38.0 38.0 0.00 HANGER TUBING HANGER 3.958 - � 1,926.8 1,791.7 37.97 NIPPLE SCSSSV,TRM-4PE-CF w/3.813""DB"NIPPLE 3.813 9,145.1 6,382.6 40.13 LOCATOR BAKER LOCATOR 3.870 9,146.4 6,383.5 40.09 SEAL ASSY BAKER SEAL ASSY 3.870 Illim Tubing Description String Ma...I ID(in) I Top(RKB) I Set Depth(ft..J Set Depth(ND)(...I Wt lb/R) I Grade I Top Connection GAS LIFT,3,1174 STACK PACKER 41/2 3.958 9,152.1 9300.3 6,500.3 12.60 L-80 IBT-M Completion Details TM Nominal ID Top(RKB) Top(ND)(RKB) Top Inc/(°) (tern Des Com (in) 9,152.1 6,387.9 39.98 PBR BAKER 80-47 PBR 3.870 9,172.0 6,403.1 40.14 PACKER BAKER PREMIER PACKER 3.870 GAS LIFT;5,045.6 9,223.2 6,442.0 40.40 NIPPLE "X"PROFILE NIPPLE 3.813 w/"XX"PLUG INSTALLED 3.813 9,296.7 6,497.5, 40.85 WLEG WIRELINE GUIDE 3.958 Other in Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Inc! Top(RKB) (ftKB) F) Des Com Run Date ID(in) I 9,223.2 6,442.0 40.40 XX PLUG XX plug installed before Nipple run in lower 9/11/2013 0.000 completion SURFACE;422-5,210.0 Perforations&Slots Shot.. 111 Den Top(ND) Btm(ND) )NhotnR Top(RKB) Btm(RK8) (RKB) (RK8) Zone Date t) Type Com GAS LIFT;6,523.3 , 9,361.0 9,368.0 6,546.1 6,551.4 C-1,A-1,3Q- 2/15/1992 4.0 IPERF 4 1/2"Csg Gun;180 lsi 03 deg.phasing 9,368.0 9,401.0 6,551.4 6,576.4 C-1,A-1,30- 2/15/1992 4.0 IPERF 4 1/2"Csg Gun;180 k 03 deg.phasing Mandrel Details GAS LIFT;7,690.2 _ St _ ati C IR on Top(ND) Valve Latch Port Size TRO Run No Top(RKB) (RKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m Si 3,117.4 2,606.8 CAMCO KBG-2- 1 GAS LIFT DMY BK-5 0.000 0.0 9/13/2013 1R 2 5,045.6 3,801.5 CAMCO KBG-2- 1 GAS LIFT DMY BK-5 0.000 0.0 9/13/2013 GAS LIFT:5,642.1 'i, 1 R ' 3 6,523.3 4,702.1 CAMCO KBG-2- 1 GAS LIFT DMY BK-5 0.000 0.0 9/13/2013 lin 1R 4 7,690.2 5,408.4 CAMCO KBG-2- 1 GAS LIFT SOV BEK 0.000 0.0 9/13/2013 lis 1R DCK-2 5 8,642.1 6,022.7 CAMCO KBG-2- 1 GAS LIFT DMY BK-5 0.000 0.0 9/13/2013 GAS LIFT;9,094.9 4 6 9,094.9 6,344.3 CAMCO KBG-2- 1 GAS LIFT DMY BK-5 0.000 0.0 9/15/2013 II1R 111 Notes"General&Safety End Data Annotation II 11/29/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 LOCATOR 9,145.1 III SEAL ASSY,9,146.4 ( :I", NI PACKER 9,172.0 e. in %X PLUG;9,223.2 NIPPLE,9,223.2, a IPERF;9,361.0-9,368.0- IPERF;9,368.0-9,401.0 PRODUCTION;42.2-9,614.4 343 Pre-Rig Well Work • DATE SUMMARY 2/2/2013 GAUGED TBG TO 2.78"; BRUSHED & FLUSHED TBG TO 9276' RKB. JOB SUSPENDED FOR HIGH WINDS. IN PROGRESS. 2/3/2013 HIGH WINDS DELAYED START. PULLED OV @ 8712' RKB. LAY DOWN DUE TO WINDS. IN PROGRESS. 2/4/2013 PULLED GLVs @ 8239', 7490', 5953', 3264'; REPLACED WITH DVs. STATION 5 OPEN. IN PROGRESS. 2/9/2013 SET 2.75 CA-2 PLUG @ 9276' RKB; LOAD TBG & IA W/DIESEL. LRS CMIT T X IA TO 2500 PSI (PASSED ) . IN PROGRESS. 2/10/2013 SET DV @ 8712' RKB; MITIA TO 2500 PSI ( PASS ) . BAIL SCALE AND PULL CA-2 PLUG @ 9276' RKB. READY FOR E-LINE. 2/12/2013 ATTEMPTED TO PERFORM SBHP AND PERF TUBING. CABLE HEAD SHORTED WHILE RUNNING IN HOLE @ 5950'. REPAIRED SHORT AND WILL BE BACK AT WELL ASAP TO COMPLETE JOB. ***IN PROGRESS*** 2/13/2013 PERFORMED SBHP AND PERFORATED TUBING TAIL. PERFORMED SBHP SURVEYS AT 9242'AND 9400'. STATS ARE AS FOLLOWS: 9242: 4105 PSI AT 160 DEG 9400': 4137 PSI AT 163 DEG PERFORATED 9272'-9274' IN 6' PUP JOINT ABOVE XN-NIPPLE. 2.5"GUN HAD BIG HOLE PROSPECTOR CHARGES, 3 SPF, 120 DEG PHASING. 2/20/2013 TAGGED @ 9457' SLM, EST. 56' RATHOLE. MEASURED BHP @ 9400' RKB: 4367 PSI. READY FOR CTU. 2/27/2013 MEASURED BHP @ 9400' RKB: 4492 PSI (ON 2/20/13:4367 PSI). RDMO. 3/13/2013 SET CATCHER; PULL DV AND SET OV @ 5953' RKB. IN PROGRESS 3/14/2013 PULLED DV AND SET GLV @ 3264' RKB; PULLED CATCHER SUB. COMPLETE 3/31/2013 (PRE-CTD): RIG WORK-MITOA(PASSED)@ 1800 PSI, T POT(PASSED), T PPPOT(PASSED), IC POT(PASSED), IC PPPOT (PASSED), FUNCTION TEST LDS (ALL FUNCTIONED PROPERLY). 4/15/2013 MEASURED BHP @ 9400' RKB (2928 psi ) . WILL RETURN TO SET DV'S 4/19/2013 TBG OPEN TO 2.77"TO 6300' SLM. PULLED GLV @ 3264' RKB, SET DV @ SAME. PULLED OV @ 5953' RKB. PUMPED 175 BBL DSL DOWN IA, SET DV @ SAME. ATTEMPTED MIT IA; PRESSURE FELL OFF TO 550 PSI WITHIN 15 MIN, UNABLE TO PRESSURE IA BACK UP. IN PROGRESS. 4/20/2013 CHECK SET DVs @ 3264' &5953' RKB. GOOD TBG TEST WITH HOLE FINDER @ 9217' RKB. INJECTIVITY TEST ON IA: 10 BBL DSL @ 1 BPM, 1450 PSI. WITH 6' EXT. BELOW HOLEFINDER, LANDED TEST TOOL IN D NIPPLE PLACING SEALING ELEMENT JUST BELOW PACKER @ 9262' RKB. ATTEMPTED TEST, TBG & IA COMMUNICATING. IN PROGRESS. 4/22/2013 LOG LEAK DETECT W/PRES, TEMP, SPIN,AND CALIPER. PUMPING DOWN IA INTO FORMATION AT 1 BPM AND 1500 PSI. PACKER HAS SLID DOWN 16' CREATING A 6' GAP IN TUBING OPEN TO CASING FROM 9260'- 9266'. TUBING TAIL NOW LOCATED AT 9300'. LOG CALIPER FROM 9330'TO SURFACE, DATA SENT TO ANCHORAGE FOR FURTHER PROCESSING. 6/10/2013 DRIFT TBG W/2.50"CENT, TAG FILL @ 9440 (EST. 39'OF RAT HOLE), MEASURE BHP (4163 psi)@ 9398' RKB. JOB COMPLETE 8/16/2013 RAN FLAPPER CHECKER DOWN TO SSSV @ 1887' RKB. FIRST RUN, SHEAR PIN APPEARS BROKEN, NOT SHEARED. INCONCLUSIVE. REATTEMPT IN AM. IN PROGRESS. 8/17/2013 RUN FLAPPER CHECKE TO SSSV @ 188T RKB. SSSV SEIZED ND NO LOCK OUT REQUIR� UP A JOB COMPLETE 8/18/2013 Load TBG and IA with 11#inhibited CaCl2 brine. Freeze protect TBG w bbls diesel. Job complete. • Conocoiillips Time Log & Summary W iewWebRepo , Report ' ���'ib' 'i�P i i t� i �i�tl"h�. I� Well Name: 3Q-03 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 9/8/2013 3:00:00 AM Rig Release: pp 11,#i,l ac - i, "'h iI1 GI4' r k Iliiii i�i l� ig r�� # F� a: GiG16R � iii a Date 5 "i°'i'i om§Iu iGTo m w 3Dur S..Deoth E.Deoth:Thase Qode 4 ubiroae 1T ''knaomment o s,,t 09/07/2013 24 hr summary Move Rig from 1A pad to 3Q pad,laying mats and plywood as required. 00:00 04:00 4.00 0 0 MIRU MOVE DMOB P Arrange rig mats over culverts and prepare to move first 4 modules to 3Q. 04:00 07:30 3.50 0 0 MIRU MOVE MOB P Move Boiler, Motor, Pit and Rockwasher modules from 1A pad to CPF-3, pull over for change out. Continue to 3Q pad,pull modules on pad. 07:30 12:00 4.50 0 0 MIRU MOVE MOB P Spot mods @ 3Q, return trucks to 1A for Sub-structure, pipe sheds and ancilliary equipment. Prepare mods for road. 12:00 15:00 3.00 0 0 MIRU MOVE MOB P Move Sub-structure and pipe sheds off of 1A, pipe sheds spotted at 3Q pad. Sub sank in road at 3Q access road,just at EM NOC area. Secure sub on mats. 15:00 18:00 3.00 0 0 MIRU MOVE MOB P Move plywood and rig mats on to access road for rig support. 18:00 20:00 2.00 0 0 MIRU MOVE MOB P Move Sub-Structure down access road onto 3Q pad. 20:00 00:00 4.00 0 0 MIRU MOVE MOB P Spot sub over well 3Q-03,begin mating up modules.Troubleshoot pit module cold start generator. 09/08/2013 MIRU and accept at 03:00. R/U and kill well w/13.0 ppg mud. N/D tree, N/U stack R/U to test,witness wavied by AOGCC. 00:00 02:00 2.00 0 0 MIRU MOVE MOB P PJSM,spot pits, pump complex, boiler complex and rockwasher. 02:00 03:00 1.00 0 0 MIRU MOVE RURD P Hook up electrical lines and inner connects. Calibrate gas alarms, complete rig acceptance checklist. Rig accepted at 03:00. 03:00 08:00 5.00 0 0 MIRU MOVE RURD P R/U line to kill well, load 13.0 ppg mud into rig pits. (waiting on tiger tank, choke skid and hardline) 08:00 11:00 3.00 0 0 MIRU MOVE RURD P ASRC rig up tiger tank,skid, hardline. Build scaffolding in cellar. 11:00 13:00 2.00 0 0 MIRU WHDBO MPSP P P/U and R/U lubricator,test to 1500 psi for 10 min and pull BPV per Cameron rep. Tubing=750 psi, IA=1250 psi, OA=200 psi. 13:00 14:15 1.25 0 0 MIRU WELCTL RURD P Continue rigging up,checking lines and taking on mud. Blow air through lines to tank. Pagel ofg ,i � D� N i" we NCam nt ,bthe Lade From 'Our po beath tE:Death_Phase _Co a Subeode :(. 14:15 17:00 2.75 0 0 MIRU WELCTL KLWL P PT lines to 3500 psi, Kill well @ 3 bpm, ICP=990 psi, FCP= 1000 psi, pumped 396 bbl 15 bbl past good mud weight back to tank. 17:00 17:15 0.25 0 0 MIRU WELCTL KLWL P Shut in tubing and bullhead additional 15 bbl 13.0 ppg mud to formation via IA @ 1 bpm,780-880 psi. 17:15 18:30 1.25 0 0 MIRU WELCTL OWFF P Bleed pressures, monitor well for 10 min @ tiger tank,slight flow but reducing. Line up to monitor flow in trip tank and monitor additional 30 minutes-Static. 18:30 19:45 1.25 0 0 MIRU WHDBO MPSP P PJSM,set BPV per Cameron rep. Blow down and rig down lines. Remove scaffolding from cellar, organize cellar for N/D of tree.Take pictures of tree orientation. 19:45 20:45 1.00 0 0 MIRU WHDBO NUND P PJSM, N/D Tree and adapter flange, terminate control line. Break LDS to ensure free. 20:45 23:15 2.50 0 0 MIRU WHDBO NUND P N/U BOPE and DSA, rig up to test with 3-1/2"and 4-1/2"test joints. AOGCC witness waived by Jeff Turkington @ 18:00. 23:15 00:00 0.75 0 0 MIRU WHDBO RURD P Fill stack and rig up test equipment. 09/09/2013 Test BOP's, pull hanger to floor. CBU and start losing fluid. Pump LCM and repair losses, condition mud and POOH laying down 78 jts 3-1/2"tubing and SSSV. 00:00 00:15 0.25 0 0 MIRU WHDBO RURD P PJSM-R/U to test BOPE 00:15 05:15 5.00 0 0 MIRU WHDBO BOPE P Test BOPE w/3-1/2"and 4."test joints to 250/3500 psi 5 minute each on chart.#1-Upper pipe rams,valve 1,12,13,14 and manual kill.#2-Upper IBOP, HCR kill,valves 9,11. #3-Lower IBOP,valves 5,8 and 10. #4-Dart valve,valves 4,6,7.#5-Floor valve&valve 2.#6-HCR Choke,4" kill line Demco valve.#7-Manual choke valve, HCR kill.#8-Annular preventer,#9-lower pipe rams, #10-Blind rams. 05:15 05:45 0.50 0 0 MIRU WHDBO BOPE P Accumulator test,system pressure=3000 psi, pressure after closing=1725 psi,200 psi gained=42 seconds,full pressure attained=198 seconds. N2 bottle average=2000 psi. State witness waived by AOGCC Jeff Turkington. 05:45 06:15 0.50 0 0 MIRU WHDBO RURD P Drain stack, blow down choke, choke line,kill line and top drive. 06:15 06:45 0.50 0 0 COMPZ RPCOM MPSP P PJSM, R/U and pull blanking plug per Cameron rep. Page 2of9-s; Tithe LdgS iopiy 7 iii qii ia��R � i��p � ��IWNioo Nisi �'111�I�I�(400� Date ;> Frorml To Oury .Debth E.<Death Phase bode tuboode T Cornnien � 06:45 07:30 0.75 0 9,260 COMPZ RPCOM PULL P PJSM, M/U landing jt to hanger, back out lock downs and pull free @ 115k,string wt=105k with blocks. Fill hole, monitor well static. 07:30 08:15 0.75 9,260 9,231 COMPZ RPCOM RURD P Disconnect control line, L/D landing jt, R/U power tongs, L/D hanger. SIMOPS, rig up to circulate. 08:15 08:30 0.25 9,231 9,231 COMPZ RPCOM CIRC P Establish circulation @ 3 bpm, 1050 psi,40%flow. Started losing fluid to formation, reduce pump rate to 2 bpm,950 psi started losing flow. Pumping away 1.5-2 bpm. Ordered out some LCM and start mixing pill. 08:30 14:00 5.50 9,231 9,231 COMPZ RPCOM OWFF T Observe well while waiting on LCM. SIMOPS-bleed off OA=450 psi. Mix LCM pill, 50 ppb Safe-Garb/Nut Plug blend. 14:00 15:30 1.50 9,231 9,231 COMPZ RPCOM CIRC P Establish circulation and pump 28 bbl LCM pill @ 1-2 bpm, 800-1025 psi.Shut down pump and let soak for 15 minutes. (Monitor well,slight loss observed) 15:30 16:00 0.50 9,231 9,231 COMPZ RPCOM OWFF P Establish circulation,stage pump up from 1 bpm-750 psi to 5 bpm-1450 psi,61%flow out. 16:00 19:00 3.00 9,231 9,231 COMPZ RPCOM CIRC P Circulate and condition mud @ 5 bpm, 1450 psi,57%flow, no losses observed. 19:00 19:30 0.50 9,231 9,231 COMPZ RPCOM OWFF P Shut down and monitor well, slight flow at first,static in 10 minutes then slight loss. 19:30 20:00 0.50 9,231 9,231 COMPZ RPCOM OWFF P Continue to monitor well for 30 minutes total static(slight loss). Mix and pump 15 bbl, 15 ppg slug and let fall. Blow and rig down circ lines. 20:00 22:30 2.50 9,231 7,344 COMPZ RPCOM PULL P POOH w/3-1/2"tubing comp and control line to SSSV. 22:30 22:45 0.25 7,344 7,344 COMPZ RPCOM RURD P PJSM, R/U and L/D control line spooler.29 SS bands recovered,5 bands unaccounted for. 22:45 00:00 1.25 7,344 4,926 COMPZ RPCOM PULL P Continue L/D 78 jts 3-1/2"tubing completion and SSSV. Total mud lost to formation 23 bbl. Upper tubing had mild corrosion. 09/10/2013 Pull and L/D 3.5"completion. P/U Fishing assembly and SIH with DP to fish packer and tailpipe. 00:00 06:15 6.25 4,926 0 COMPZ RPCOM PULL P PJSM, L/D 3.5"tubing,292 joints. Act fill=29.30, Calc fill=22.70. 06:15 07:00 0.75 0 0 COMPZ RPCOM PULD P LD casing equipment, clean and clear rig floor. SIMOPS strap old tubing. 07:00 09:30 2.50 0 0 COMPZ RPCOM PULD P PJSM, Unload old 3.5"tubing from pipe shed, load 4"drill pipe and drill collars in ipe shed and strap. 09:30 09:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM on P/U and M/U BHA#1. Page 3of9 .4 li iv . Grp a `S '. �6i61i� .9P h ,oinlil��i81 — !�696ii ,�� From o. .,uDu� ��� .S.Death �E."beoth Phase Code ula delf[. '`obmment 09:45 12:00 2.25 0 148 COMPZ RPCOM PULD P P/U and M/U spear bha#1 as per Baker rep.(Install 6.25"wwear bushing) 12:00 12:30 0.50 148 303 COMPZ RPCOM PULD P PJSM, Continue M/U BHA#1, P/U 4.75"collars,X-O,CIO elevators to 4". 12:30 14:15 1.75 303 2,768 COMPZ RPCOM PULD P P/U 4"Drill Pipe, SIH to 2768'MD. 14:15 14:45 0.50 2,768 2,768 COMPZ RPCOM SVRG P Lubricate Rig Service Top Drive 14:45 15:45 1.00 2,768 4,092 COMPZ RPCOM PULD P Continue SIH w/4"DP to 4092'MD, observed slight flow out DP and flow line,decision made to circulate well through open choke. 15:45 18:45 3.00 4,092 4,092 COMPZ RPCOM CIRC P Circ surface to surface strokes @ 2 bpm,550 psi, no gas observed, bleed pressures, monitor well (STATIC), pump 12 bbl of 14.2 ppg down DP, B/D top Drive B/D choke lines and manifold. 18:45 22:00 3.25 4,092 9,247 COMPZ RPCOM PULD P Cont SIH w/4"DP from 4092'MD to 9247'MD,establish parameters, P/U 177k, S/O 85k,Cal 56.02 bbl,Act= 55.65 bbl 22:00 22:30 0.50 9,247 9,175 COMPZ RPCOM FISH P RIH,tag @ 9235'MD, No-Go @ 9258'MD,set 15k down, P/U observed 10-15k overpull, RIH&set 20k down, P/U observed 10-15k overpull, racked back 1 stand. 22:30 00:00 1.50 9,175 9,175 COMPZ RPCOM CIRC P CBU @ 9175'MD,stage pumps from 1 bpm,950 psi,to 3.5 bpm, 1550 psi,59%F/O. 09/11/2013 POOH with Packer and tail assembly. UD fish. P/U, M/U and RIH with Cleanout Assembly. POOH. M/U Scraper Assembly and RIH. 00:00 00:15 0.25 9,175 9,175 COMPZ RPCOM OWFF P PJSM, Monitor well(STATIC) 00:15 00:45 0.50 9,175 9,215 COMPZ RPCOM FISH P RIH from 9184'MD to 9257'MD,Tag up,set 10k down, P/U 220k, let jars bleed open.Pull to 250k,wt fell of to 220k then to 155k. P/U with 10-12k drag over string wt. P/U wt= 180k, S/O wt=85k. 00:45 01:45 1.00 9,215 9,215 COMPZ RPCOM CIRC P CBU @ 5 bpm,200 psi,60%flow. (Blow down TD) 01:45 02:30 0.75 9,215 9,215 COMPZ RPCOM OWFF P Monitor well: slight flow down to static. 02:30 07:00 4.50 9,215 302 COMPZ RPCOM TRIP P POOH from 9215'MD to 302'MD. Act Fill=57.90, Cal fill=54.30 07:00 07:30 0.50 302 302 COMPZ RPCOM OWFF P Monitor well at last stand of Drill Pipe (STATIC),SIMOPS PJSM on UD BHA 07:30 08:30 1.00 302 0 COMPZ RPCOM PULD P Rack back 3 stands of drills collars, UD BHA and fish as per Baker Rep. (Fish 36.04') 08:30 09:00 0.50 0 0 COMPZ RPCOM RURD P Clean and clear rig floor. 09:00 09:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM, P/U and M/U Cleanout run BHA. =Page 4 of 9l itll LOgs ' **A'"" j pus, ;IN.40' pii(ii Date From.To ° Our ..Depth E.Deoth l,Phase „Code _Subcbde ,T _ tiiiirri tit u' 09:15 09:45 0.50 0 0 COMPZ WELLPF PULD P Mobilize Baker clean out tools to Rig Floor. 09:45 11:00 1.25 0 345 COMPZ WELLPF PULD P P/U and M/U Clean out BHA as per Baker Rep. (BHA#2) 11:00 12:00 1.00 345 912 COMPZ WELLPF PULD P SIH from 345'MD to 912'MD. 12:00 14:15 2.25 912 9,382 COMPZ WELLPF TRIP P PJSM, RIH from 912'MD to 9382' MD,tag w/10k(x2),est para: P/U= 180k, S/O=85k, Rot= 114k,TQ= 8-9k, Cal fill=57.5 bbls,Act=58.1 bbls. 14:15 15:15 1.00 9,382 9,500 COMPZ WELLPF REAM P Make T/D connection, Ream from 9383'MD to 9505'MD. Ream @ 3 bpm, 1300 psi,55%flow out, 50 rpm, 8-9k TQ. 15:15 16:15 1.00 9,500 9,500 COMPZ WELLPF CIRC P CBU @ 5 bpm, 1750 psi, 9500'MD. 16:15 16:45 0.50 9,500 9,500 COMPZ WELLPF OWFF P Monitor well(slight flow to static), Pump dry job, B/D Top drive. 16:45 20:15 3.50 9,500 340 COMPZ WELLPF TRIP P PJSM, POOH from 9500'MD to 340' MD. 20:15 20:30 0.25 340 340 COMPZ WELLPF OWFF P Monitor well(SLight flow to static), Pump dry job, B/D top Drive. 20:30 21:00 - 0.50 340 0 COMPZ WELLPF PULD P PJSM, UD BHA per Baker Rep, Clean Boot basket&magnets. 21:00 21:15 0.25 0 0 COMPZ WELLPF PULD Clean and Clear rig floor. 21:15 21:30 0.25 0 325 COMPZ WELLPF PULD P PJSM, M/U Scraper BHA(BHA#3) per Baker Rep. 21:30 00:00 2.50 325 6,679 COMPZ WELLPF TRIP P RIH w/4"DP from 325'MD to 6679' MD. Cal fill=39.92 bbls,Act fill= 41.3 bbls 39/12/2013 POOH Scraper assembly, P/U, RIH and set Storm Packer. N/D BOP. Change wellhead, N/U BOP,Test BOP w/4.5"test joint,test packoff, pull storm packer. 00:00 00:15 0.25 6,679 9,505 COMPZ WELLPF TRIP P PJSM, RIH 6679'MD to 9505'MD. (No Problems)P/U wt= 185k, 5/0 wt=85k.Act fill= 17.6 bbls, Calc fill = 16.2 bbls 00:15 02:00 1.75 9,505 9,505 COMPZ WELLPF CIRC P CBU @ 5 bpm, 1500 psi,57%flow, FCP= 1450 psi. 02:00 02:15 0.25 9,505 9,505 COMPZ WELLPF OWFF P Monitor well(STATIC) 02:15 02:45 0.50 9,505 9,295 COMPZ WELLPF TRIP P POOH from 9505'MD to 9295'MD, L/D single jt of DP. 02:45 03:00 0.25 9,295 9,295 COMPZ WELLPF RURD P R/U to Rev Circ 03:00 03:45 0.75 9,295 9,295 COMPZ WELLPF CIRC P Rev Circ Drill Pipe volume @ 3 bpm, 925 psi 03:45 04:00 0.25 9,295 9,295 COMPZ WELLPF SFTY P PJSM for Spotting CI mud balanced pill. 04:00 04:45 0.75 9,295 9,295 COMPZ WELLPF CIRC P Spot 25 bbls inhibitted mud and chase with 92 bls mud @ 5 bpm, 1500 psi, 57%flow. 04:45 05:15 0.50 9,295 9,295 COMPZ WELLPF OWFF P Monitor well. (STATIC) 05:15 06:15 1.00 9,295 8,384 COMPZ WELLPF TRIP P P/U single jt DP. POOH from 9295' MD to 8384'MD. 06:15 06:30 0.25 8,384 8,384 COMPZ WELLPF CIRC P Pump slug, B/D Top Drive. Page 6 o19 jithe Logs:— q� x E J 7""""1,-<,,,7 . '1 1 -Date " From To—FFxr Dur S.Depth tE,5ebthk,Pbase Code w.4ttibcode 'T °tbmment 16 06:30 09:00 2.50 8,384 515 COMPZ WELLPF TRIP P POOH from 8384'MD to 515'MD. Act fill=57.1 bbls, Calc fill=50.2 bbls. 09:00 09:15 0.25 515 515 COMPZ WELLPF SFTY P PJSM on P/U storm packer. 09:15 10:00 0.75 515 515 COMPZ WELLPF PULD P P/U storm packer and M/U as per Baker Rep. 10:00 11:00 1.00 515 593 COMPZ WELLPF TRIP P RIH and set storm packer, center of element @ 78'MD 11:00 11:15 0.25 593 593 COMPZ WELLPF PRTS P Test storm packer to 3000 psi for 10 min(charted). 11:15 12:00 0.75 593 593 COMPZ WELLPF PACK P Attempt to release from storm packer as per Baker Rep. 12:00 13:30 1.50 593 593 COMPZ WELLPF TRIP T PJSM, Pull storm packer to rig floor, inspect elements&loosen connections, re-run storm packer, attempt to test(x3),decision made to L/D packer, P/U 9 stands 4"DP. 13:30 15:15 1.75 593 1,433 COMPZ WELLPF TRIP T RIH 9 stands 4"DP, P/U storm packer, RIH to 108'MD(center of element), pressure test packer,test packer to 3000 psi for 10 minutes (charted) 15:15 17:00 1.75 1,433 0 COMPZ WHDBO NUND P PJSM-N/D BOPE&tubing spool. 17:00 20:30 3.50 0 0 COMPZ WHDBO NUND P PJSM, N/U tubing spool,test tubing spool void to 250 psi&3000 psi for 10 min each, cont N/U BOPE. 20:30 22:45 2.25 0 0 COMPZ WHDBO RURD P PJSM, R/U to test BOPE. 22:45 00:00 1.25 0 0 COMPZ WHDBO BOPE P PJSM,Test breaks on BOPE and choke line,test w 4.5"test joint,test upper and lower VBR,annular preventer and choke valves 1,3,4,5. Test to 250 psi and 3000 psi for 5 min(charted) 39/13/2013 Retrieve Storm Packer and L/D BHA. P/U, M/U and RIH Lower completion on DP.Circulate well clean, POOH. 00:00 01:00 1.00 0 0 COMPZ WHDBO RURD P PJSM, R/D test eqpt, blow down choke,choke line and kill line.set 6.75"wear bushing. 01:00 02:15 1.25 0 1,474 COMPZ WELLPF PACK P PJSM, M/U storm packer retrieval tool, RIH, latch on to storm packer and L/D 02:15 02:45 0.50 1,474 325 COMPZ WELLPF TRIP P POOH from 1474'MD to 325'MD. Act fill= 11.6 bbls,Cal fill= 11.3 bbls 02:45 03:45 1.00 325 0 COMPZ WELLPF PULD P L/D 9 joints drill collar and scraper BHA assembly as per Baker Rep. 03:45 04:30 0.75 0 0 COMPZ WELLPF RURD P Clear and clean rig floor. 04:30 05:00 0.50 0 0 COMPZ RPCOM RURD P R/U 4.5"casing eqpt. 05:00 05:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM on P/U and M/U packer.Test plug(good). 05:15 06:45 1.50 0 155 COMPZ RPCOM PULD P P/U and M/U packer and tailpipe as per Baker Rep. Page 6 of 9 � nm:w'�d;Aiik ski _ Hi al9p •,G V� spi o ioi !�Jubcode Tom. omment ; ilUq @giltyiq agi Ipidi, uif date ,= ryFrom= To` �0i`� `i S.Deqt� rDepth,wPhase Code i_ 06:45 12:00 5.25 155 6,492 COMPZ RPCOM TRIP P RIH from 155 MD w/4"DP from Derrick to 6492'MD.Act disp= 42.95 bbls, Cal disp=42.00 bbls. 12:00 14:00 2.00 6,492 9,285 COMPZ RPCOM TRIP P RIH from 6492'MD to 9285'MD. Total Cal disp=54.06 bbls,Act disp= 58.7 bbls 14:00 15:30 1.50 9,285 9,157 COMPZ RPCOM PACK P R/U hoses to set packer,set packer per Baker Rep. P/U= 177k, S/O 86k.Set packer w/4000 psi, hold for 10 min. R/U to test backside to 1500 psi for 10 min(charted), Packer set @ 9157'MD Rig 141 RKB,9170'MD rig 245 RKB. 15:30 16:00 0.50 9,157 9,135 COMPZ RPCOM CIRC P R/U to reverse circulate mud displacement. 16:00 20:00 4.00 9,135 9,135 COMPZ RPCOM CIRC P PJSM, Dsiplace well from 13 ppg mud to 9.6 ppg brine per MI Swaco 20:00 20:45 0.75 9,135 9,030 COMPZ RPCOM RURD P Flush circ lines and stack, UD single, rack back stand, P/U single and breeak circ head pin, UD single, B/D Kill line and circ lines 20:45 21:45 1.00 9,030 9,030 COMPZ RPCOM SLPC P PJSM, Slip&Cut Drilling line(65'- 10 wraps),adjust brakes,monitor well via trip tank(STATIC). 21:45 22:15 0.50 9,030 9,030 COMPZ RPCOM SVRG P Service Rig: Grease T/D&dwks, monitor well via trip tank(STATIC) 22:15 00:00 1.75 9,030 6,157 COMPZ RPCOM TRIP P PJSM, POOH from 9030'MD to 6157'MD. Cal fill= 16.2 bbls,act fill 17.68 bbls. P/U 115 S/0 82k. X9/14/2013 POOH, repair seal assembly, RIH with 4.5"tubing upper completion. Space out completion. 00:00 01:45 1.75 6,157 24 COMPZ RPCOM TRIP P PJSM, POOH from 6157'MD to 24' MD.Act fill=39.1 bbls, Calc fill= 35.1 bbls. 01:45 02:15 0.50 24 0 COMPZ RPCOM RCST P Pull Seal assembly to rig floor, observe scratches on Seal assembly.Take picture of seal assembly and call Baker Rep. Decision made to send seal assembly to baker shop for rebuild. 02:15 03:15 1.00 0 0 COMPZ RPCOM RURD P Pull wear bushing, R/U 4.5"casing tools. 03:15 08:30 5.25 0 0 COMPZ RPCOM RCST T Wait on Seal assembly.Work on MP2s and clean rig. 08:30 08:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM on running 4.5"tubing. 08:45 12:00 3.25 0 2,270 COMPZ RPCOM RCST P P/U seal assembly.RIH w/4.5" completion(total joints run=60).Act disp=8.84 bbls, Cal disp=8.68 bbls. 12:00 16:45 4.75 2,270 7,220 COMPZ RPCOM RCST P PJSM, Cont RIH w/4.5"completion per detail to joint 229, (SSSV)7220' MD. Calc disp=32.55 bbls,Act disp =28.9 bbls. 16:45 18:15 1.50 7,220 7,220 COMPZ RPCOM RURD P PJSM, R/U SSSV w/control line spool,Tie in to control line and test to 7200 psi for 15 min,bleed control line to 6000 psi and hold for 15 min. geTef9 TimeXogs ' 1' iii M1 �1 qi tiii6 Ste Fi-otxi�o bur S.aDeoth E.zDeoth Phase Code'Subcode'` '''''Comment -c T ' 18:15 22:30 4.25 7,220 9,121 COMPZ RPCOM RCST P Cont RIH w/4.5"completion to joint 290 at 9122'MD, M/U circ equip on jt 291, break circ at 1 bpm,60 psi, RIH tag seals @ 9140'MD, Bleed pressure,cont RIH, M/U circ eqpt on jt 292, RIH tag No-Go at 9157'MD, test seals w/500 psi(good), P/U to up wt+5',space out, L/D jt 292& 291, M/U landing jt&tubing hanger, P/U wt= 123k, S/O wt=82k, Cal disp=42.67 bbls,Act disp=37.57 bbls. 22:30 00:00 1.50 9,121 9,121 COMPZ RPCOM RCST P Tie in control line to tubing hanger, test hanger swedge to 5000 psi for 5 min,test control line to 6000 psi, 15 min,66 total S/S bands. 09/15/2013 Circ CI brine. Land hanger. N/D BOPE, N/U tree,freeze protect. L/D DP. Release rig. 00:00 01:00 1.00 9,121 9,121 COMPZ RPCOM CIRC P PJSM, Circ wellbore over to 9.6 ppg inhibitted brine @ 4 bpm,400 psi. 01:00 01:15 0.25 9,121 9,121 COMPZ RPCOM RURD P Blow down kill line and choke. 01:15 01:45 0.50 9,121 0 COMPZ RPCOM RCST P Land hanger and RILD as per FMC Rep. (string wt. =90k) 01:45 03:30 1.75 0 0 COMPZ RPCOM PRTS P Test tubing to 3000 psi for 10 min. Monitor IA(charted)bleed tubing, pressure down toi 2500 psi and shut in. Pressure test IA to 3500 psi for 30 min(charted), bleed IA pressure off and then tubing pressure off. Line up to IA and quickly ramp up pressure to shear out, S.O.V. sheared at 2550 psi. 03:30 04:00 0.50 0 0 COMPZ WHDBO OWFF P Monitor well(STATIC). SIMOPS: R/D test eqpt and pull landing jt. 04:00 04:30 0.50 0 0 COMPZ WHDBO PRTS P Set BPV and test down IA to 1000 psi for 10 min. (charted) 04:30 05:15 0.75 0 0 COMPZ WHDBO RURD P PJSM, close SSSV and disconnect control line. Blow down test lines, rinse out stack, clean and clear rig floor. 05:15 05:30 0.25 0 0 COMPZ WHDBO SFTY P PJSM on N/D BOPE. 05:30 06:30 1.00 0 0 COMPZ WHDBO NUND P N/D BOPE. 06:30 08:45 2.25 0 0 COMPZ WHDBO RURD P Terminate control line and M/U to tubing spool as per SLB Rep. 08:45 11:00 2.25 0 0 COMPZ WHDBO NUND P N/U tree adapter,test seals on neck and SBMS to 250 psi/5000 psi for 10 min as per FMC Rep. 11:00 11:15 0.25 0 0 COMPZ WHDBO NUND P N/U FMC tree. 11:15 12:00 0.75 0 0 COMPZ WHDBO RURD P Pull BPV and install two way check as per FMC Rep. 12:00 13:15 1.25 0 0 COMPZ WHDBO RURD P PJSM, Fill tree w/diesel, R/U and test tree to 250 psi/5000 psi for 5 min each. (charted) Page 8 of=9 rv? 1 f 'tithe o S' 'i 9) . Date,F ° From To Dut S Depth E.;Depth Phase' Code. _Subcode „.T1I ,Comrr'i n . ..i; ma4li 13:15 14:15 1.00 0 0 COMPZ WHDBO PRTS P Pull tree test plug per FMC, R/U to Circ freeze protect. SIMOPS, install mouse hole R/U to L/D 4"DP. Open SCSSSV per SWS, Pressure test to 5000 psi for 30 min. 14:15 15:45 1.50 0 0 COMPZ WHDBO FRZP P PJSM, Pressure test lines to 2500 psi,check for leaks, reverse circ 80 bbls diesel freeze protect via LRS, 1.5 bpm,700 psi, FCP 600 psi. SIMOPS: PJSM L/D DP from derrick. 15:45 17:00 1.25 0 0 COMPZ WHDBO PULD P B/D line and put tubing in communication to U-Tube well. Continue L/D 4"DP. 17:00 18:30 1.50 0 0 COMPZ WHDBO RURD P PJSM-B/D and R/D freeze protect lines, remove 1502 flanges, install blanking flanges on tree,secure well and cellar. 18:30 22:00 3.50 0 0 DEMOB MOVE PULD P Continue to L/D 4"DP via mouse hole. 22:00 00:00 2.00 0 0 DEMOB MOVE PULD P Blow down water and steam, Remove pipe shed Tioga,envirovac, ensure ready for release and rig move. Finish cleaning pits. RIG RELEASED at midnight. gage 9 of • 1 F ti prR WELL LOG TRANSMITTAL MAY 10 2013 To: Alaska Oil and Gas Conservation Comm. April 30, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 `-V2--(c) Anchorage, Alaska 99501 RE: Multi Finger Caliper(MFC)/Leak Detection Log: 3Q-03 Run Date: 4/22/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage,AK 99518 matthew.cook@halliburton.com 30-03 Digital Data(LAS), Digital Log file,Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22221-00 SCANNED MAR 1 3 2014 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: 1/lc& Signed: Y1/ 1/) &M iT t -\ZG • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 15, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Shut In Bottom Hole Pressure/ Perforation Record: 3Q -03 Run Date: 2/13/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 30 -03 Digital Data in LAS format, Digital Log Image files 1 CD Rom 50- 029 - 22221 -00 Shut In Bottom Hole Pressure 1 Color Log 50- 029 - 22221 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating SCANNED JUL 1 0 2013 Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com •te: 3 / 2 - -\ /.3 Signed: ' • • ,,i)",1///,/ s THE STATE Alaska Oil and Gas °' 1 L1 S Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Q. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1 433 Fax: 907.276.7542 J. Gary Eller CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 _1 I Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3Q -03 Sundry Number: 313 -042 Dear Mr. Eller: 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. Sincerely, Cathy P Foerster Chair DATED this 8 day of February, 2013. Encl. SCANNED MAR 14 2013 STATE OF ALASKA 'k' ' AIWA OIL AND GAS CONSERVATION COMOION V APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r • Perforate New Pool r Repair w ell r° Change Approved Program E Suspend r"` Rug Perforations I✓ . P E Pull Tubing r Time Extension f Operational Shutdow n r Re -enter Susp. Well E Stimulate f"" Alter casing i Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development I• • Exploratory r 191 -126 . 3. Address: Stratigraphic j °""' Service F 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 22221 - 00• 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes r ' No 1: 3Q • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25512, 373301 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9640 6758 9516' 6664' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16 120' 120' SURFACE 5170' 9.625 5210' 3906' PRODUCTION 6573' 7 9605' 6732' RECEIVED JAN 2 9 2013 AOGCC Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): ' 9361' - 9401' 6548' - 6578' 3.5 J - 9285 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - CAMCO HRP-1SP PACKER MD= 9262 TVD= 6473 • SSSV - CAMCO TRDP -4A MD =1887 TVD =1759 . 12. Attachments: Description Summary of Proposal • R,7 13. Well Class after proposed work: Detailed Operations Program E BOP Sketch r` Exploratory E Stratigraphic r Development d� - Service E 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/15/2013 Oil E Gas E WDSPL r Suspended I✓ • 16. Verbal Approval: Date: WINJ r GINJ E WAG r Abandoned r Commission Representative: GSTOR (__ SPLUG I 17. I hereby certify that the foregoing is tru :correct to the est of my knowledge. Contact: Gary Eller © 263 -4172 Email: J .Garv.Eller(a�conocoohillios.com Printed Name J. Gary Elle \\ Title: CTD Engineer Signature c. ► ,1: Phone: 263 -4172 Date \ 12%1\3 m ission Use Only Sundry Number 1 `� ^/42 Conditions of approval: Notify Commission so that a representative may witness J lJ / Plug Integrity E BOP Test / Mechanical Integrity Test r — Location Clearance P Other: BOP re-1 t fi6 4 96 0 p 5 t 4/tcrliefz p 1 v r last rv f A-Nora ve'd pt .' aD ..<},,g - C 2 1IzCt Spacing Exception Required? Yes El No [f Subsequent Form Required: _ y RSDMS FEB Required: / � 11�tt APPROVED BY / Approved by: COMMISSIONER THE COMMISSION Date: Z b) - '-'�3 Approved application is valid for 12 months from the date of approval. &,› G cRl 0 's d�/ t2) ?//. )= Submit Form and Attachments in Duplicate � 2/7-1/3 • • KRU 30 -03 CTD Summary for Plugging Sundry (10 -403) Summary of Operations: In well KRU 3Q -03, the 7" casing below the 3 tubing tail will be filled with 17 ppg cement to facilitate a cement pilot exit of the 7" casing. This cement will also effectively plug the existing perfs in 3Q -03, but there is insufficient room to plug the perfs in accordance with 20 AAC 25.112 (c). ConocoPhillips requests a variance from 20 AAC 25.112 (c) to plug the perfs in 3Q -03 in this manner. The proposed plugging procedure meets the overall objective of this section, providing an equally effective plugging of the well to prevent migration of fluids to other hydrocarbon zones or freshwater. The 3Q -03A sidetrack will be drilled west of 3Q -03 to increase reservoir exposure and improve waterflood sweep in the Al sand. After milling a pilot hole in the cement inside the 7" casing, a whipstock will be set and a window milled at 9357' MD to exit the 7" casing. The sidetrack will target the Al sand west of the existing well with a 4493' lateral. The hole will be completed with a 2%" slotted liner to the TD of 13,850' MD with an aluminum billet placed at 9445' MD. The 3Q -03AL1 lateral will be drilled north /west of 3Q -03 targeting the Al sand with a 3057' lateral. After kicking off the aluminum billet at 9445' MD, the lateral will be drilled to a TD of 12,500' MD. The hole will be completed with a 2%" slotted liner to TD with the final liner top located inside the 3'/2" tubing tail at 9270' MD. CTD Drill and Complete 3Q -03 Laterals: March 2013 Pre -CTD Work 1. MIRU slickline. Dummy all GLMs. Run whipstock dummy inside 3'/2" tubing. 2. MIRU a -line. Shoot circulating holes in the 3W tubing tail at 9273'. 3. MIRU coiled tubing. Mill out the 2.75" XN nipple at 9276' to 2.80" ID. 4. Lay in a 17 ppg cement plug inside the 7" casing from PBTD up to the circulating holes at 9273', squeezing off all existing perfs. Apply squeeze pressure. Wait on cement to set. 5. MIRU slickline. Tag top of cement and pressure test to 1500 psi. 6. Prep site for Nabors CDR2 -AC, including setting BPV Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. 2. 3Q -03A Sidetrack (Al sand, west) a. Mill cement pilot hole inside 7" casing to 9387' MD b. Set whipstock in the cement pilot hole at 9357' MD c. Mill 2.80" window through 7" casing at 9357' MD d. Drill 2.70" x 3" bi- center sidetrack to TD of 13,850' MD e. Run 2%" slotted liner with an aluminum billet from TD up to 9445'. go /f s (G24G / �t e y��ye�f wel ( /�rUd�L''�f leSlr lJV /f `P Ct/t f / p i 17; 7`J �+-� /( K , y / r' ' �,� q dl/ / /4/PA , kv6 q / /o� -�Vr r'/� //�Y (c co1 �ru 4t 141'5 Q G �� ° it Page 1 of 2 /,;/- l 3 i j J 25, 2013 • • 3. 3Q -03AL1 Lateral (Al sand, north /west) a. Kick off from aluminum billet at 9445' b. Drill 2.70" x 3" bi- center sidetrack to TD of 12,500' MD c. Run 2%" slotted liner from TD up to 9270' inside the 3 %" tubing tail. 4. Freeze protect. 5. Set BPV, ND BOPE. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Pull BPV 2. MIRU slickline. Install gas lift design. Perform static BHP survey. 3. Put well on production. Page 2 of 2 January 25, 2013 a KUP 3Q -03 ConocoPhil6ps A Well Attributes Max Angle & MD TD Alaska. Inc Wel!bore API/DWI Field Name Well Status Inc! (1 MD (ftKB) Act Btm (ftKB) 500292222100 KUPARUK RIVER UNIT PROD 54.35 , 6,700.00 9,640.0 `"' Comment IH2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "• WellConflp :- 30- 03,12/5f20121100.t6 AM - SSSV: TRDP 170 12/16/2011 Last WO: 40.99 1/28/1992 Schematb - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 9,430.0 12/4/2012 Rev Reason: TAG ninam 12/5/2012 -- - - - - -- Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (WO) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 43.0 121.0 121.0 62.50 H HANGER, 38 �'.,• -'� I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f-.. Set Depth (TVD) ... String Wt... String ... String Top Thrd _ _ SURFACE 95/8 8.835 42.2 5,210.0 3,905.8 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 32.7 9,604.9 6,731.7 26.00 J -55 BTC MOD Tubing Strings 1 Tubing Description String 0... String ID .., Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I TUBING I 31/2 2.992 I 37.9 9 ,284.7 6,490.1 9.30 I J -55 EUE8r4ABMOD Completion Details 1 Top Depth '-- (TVD) Top Intl NOmI-.- Top (ftKB) (ftKB) (1 item Deectiptlon comment ID (in) 37.9 37.9 -0.15 HANGER WKM TUBING HANGER w/ PUP 3.500 1,887.1 1,759.1 35.75 SAFETY VLV CAMCO TRDP -4A MODIFIED SAFETY VALVE 2.812 CONDUCTOR, 9 ,248.5 6,463.0 41.31 PBR CAMCO PBR 3.5" x 10' 3.000 43 - 121 9,261.9 6,473.0 41.28 PACKER CAMCO HRP1 -SP PACKER 2.867 9,276.4 6,483.9 41.24 NIPPLE CAMCO D NIPPLE w/ 2.750 NO GO 2.750 9,283.9 6,489.5 41.22 SOS CAMCO PE 500 SHEAR OUT SUB 2.992 SAFETY VLV, �- Q� 1,887 Perforations & Slots I Shot I _ Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (FN... Type Comment I 9,361 9,368 6,547.6 6,552.9 C -1, A -1, 30-03 2/15/1992 4.0 IPERF 4 1/2" Csg Gun; 180 deg. phasing GAS LIFT. o-- 9,368 9,401 6,552.9 6,577.9 C -1, A -1, 30 -03 2/15/1992 4.0 IPERF 4 1/2" Csg Gun; 180 deg. phasing 3.264 I I Notes: General & Safety End Date Annotation IJ 11/29/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9 0 SURFACE,' 1 42 -5,210 MIN GAS LIFT. 5.954 GAS LIFT, . 490 7,490 t1 GAS LIFT. p _ -_.. -- L 8,239 P GAS LIFT, C r 8,712 H GAS LIFT, 9.194 t ..1 . PBR. 9.249 PACKER, 9,262 NIPPLE, 9,276 - 1 . U 505, 9,284 - Mandrel Details Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (1 Make Model (i8) Sery Type Type (IN (psi) Run Date Com... 1 3,264.2 2, 5312 MACCO SPM - 1A 1 GAS LIFT GLV BK - 2 0.156 1,293.0 3/30/2007 4:00 IPERF, 9,361 - 9,368 2 5,953.5 4,368.1 52.99 MACCO SPM -1A 1 GAS LIFT GLV BK -2 0.156 1,293.0 3/30/2007 11:00 IPERF, 3 7,490.1 5,285.5 50.93 MACCO SPM - 1 GAS LIFT GLV BK -2 0.156 1,285.0 3/30/2007 1:00 9,368 - 9,401 4 8,239.4 5,759.6 48.60 MACCO SPM - 1 GAS LIFT GLV BK -2 0.188 1,307.0 3/29/2007 8:00 5 ' 8,712.0 6,071.9 47.21 MACCO SPM - 1 GAS LIFT OV BK -2 0.250 0.0 5/1/2007 11:30 6 9,194.0 6,421.5 40.66 OTIS LB 1 1/2 GAS LIFT DMY RM 0.000 0.0 6/20/1998 8:00 PRODUCTION. 33 -9,605 . ■ TD, 9,640 3Q -03 Proposed CTD Sidetrack Last Updated: 25- Jan -13 3 -1/2" Camco TRDP -4A SSSV @ 1887' MD 3 -1/2" 9.3# J -55 EUE 8rd Tubing to surface 16" 62# H-40 Boo■ shoe @ 121' MD 3 -1/2" Macco SPM -1A gas lift mandrels @ 3264, 5953, 7490, 8239, 8712, 9194 9 -5/8" 36# J -55 shoe @5210'MD CD Camco 3 -1/2" PBR @ 9248' MD (3" ID) Camco HRP -1 -SP packer @ 9339' MD (3.5" ID) **��;� "' Perfs to be shot in tubing tail at 9273' °°' • .:'"„f 3 -1/2" Camco D landing nipple at 9276' MD ``'� (2.75" min ID, No -Go) "` To be milled out to 2.80" ID "" a.a1 .✓ 3 1/2" tubing tail at 9284' MD o i ii 'Tubing tail perfs at 9273' 2.80" pilot hole r7 Nipple milled out to 2.80" ID through cement . , ".«1 ::w KOP @ 9357' MD {; Top of Whipstock @ - • 9357 MD . • A-sand perfs rfs (q ) ' (sqz'd) 3Q -03AL 1 9361' - 9401 MD �' ,��� TD - 12,500 MD —� \ Liner top @ 9270' MD 1-) a. _____ _____ ___ 1 < (----. 3" openhole, — 2 -3/8" slotted liner 3Q -03A 7" 26# J -55 shoe @ 9605' MD — TD = 13,850' MD Liner top @ 9445' MD Page l of l Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10 :52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art / or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 26, 2011 NE Commissioner Dan Seamount V a 9011 Alaska Oil and Gas Commission q . 333 West 7 Avenue, Suite 100 tin t�tas,,r;�iS Anchorage, AK 99501 / r•,,c r g� me ° i I 1 t0 Commissioner Dan Seamount: 3 g - 0 3 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped 10/18, 10/19 and, 10/21, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, ._#I,. U - 1 32Q1 g i14 )1 V `)G %&g Martin Walters ConocoPhillips Well Integrity Projects Supervisor • . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 10/26/11 2L, 3K, 3M & 3Q PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 2L -301 50103205880000 2081920 10" N/A 10" N/A 1.7 10/18/2011 3K -20 50029230190000 2010880 SF N/A 14" N/A 1.7 10/19/2011 3K -24 50029229350000 1982490 SF N/A 24" N/A 3.5 10/19/2011 3M -01 50029216600000 1870120 SF N/A 12" N/A 5.95 10/21/2011 3M -03A 50029216960100 2081790 SF N/A 18" N/A 5.1 10/21/2011 3M -08 50029217090000 1870280 SF N/A 17" N/A 2.85 10/21/2011 3M -11 50029217180000 1870380 SF N/A 26" N/A 4.25 10/21/2011 3M -21 50029217390000 1870660 SF N/A 15" N/A 3.4 10/21/2011 3Q -03 50029222210000 1911260 SF N/A 18" N/A 3.45 10/19/2011 r 3Q -07 50029216820000 1861940 SF N/A 17" N/A 4.68 10/21/2011 3Q 08A 50029216810100 1971930 SF N/A 15" N/A 3.55 10/21/2011 3Q -09 50029216740000 1861860 SF N/A 13" N/A 4.4 10/21/2011 C~ ~-' . . ConocoPh~llips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 18, 2009 , ;~; ,~ ~ ~;; -.,. . - ~ ,,~ ~,+~1~'~~;,,; ~ ~d - ;a:.~ Mr. Tom Maunder Alaska. Oil & Gas Coxnmission 333 West 7'~ Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~ ~~ C~~~ r v~ ~ ~~ Enclosed please find a spreadsheet with a list of wells from the Kupanik field (KRin. Each of these wells was found.to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the a.nnular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped June 26~', 2009. The corrosion inhibitor/sealant was pumped June 30~' & July 16~', 2009. The atta.ched spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. - Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Repart of Sundry Operations (10~04) Kuparuk Field Date 7/18/09 3H, 31 & 3Q PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhbitod sealant date ft bbls ft ~ al 31-Q7 500292154900 1860390 3' NA 3' NA 8.92 7/16/2009 3H-04 501032007600 1870760 30" NA 30" NA 13.6 7/16/2009 3H-08 501032008000 1870800 17" NA 17" NA 3.4 7/16/2009 3H-11 501032009100 1871240 27" NA 27" NA 6.37 7/16/2009 3H-19 501032009000 1871330 17" NA 17" NA 5.95 7/16/2009 3H-21 501032009400 1880080 8" NA 8" NA 1.27 7/16/2009 3H-23A 501032020401 1961860 6" NA 6" NA 1.27 , 7/16/2009 3H-24 50103202350U 1960150 6" NA 6" NA 1.27 7/16/2009 3H-31 501032020500 1940190 13" NA 13" NA • 2.97 7i16/2009 3H-33 501032057800 2081130 19" NA 19" NA 5.52 7/16/2009 3Q-03 500292222100 191126Q SF NA 5" NA 0.9 6/30/2009 3Q-06 500292168300 1861950 43' 6.30 26" 6/26/2009 6.8 6/30/2009 3Q-08A 500292168101 1971930 SF NA 6" NA 1 6/30/2009 3Q-09 500292167400 1861860 SF NA 6" NA 1 6/80/2009 3Q-10 500292167500 1861570 15' 2.50 18" 6/26/2009 6.8 6/30/2009 3Q-11 500292167600 1861880 37' 4.30 23" 6/26/2009 7 6/30/2009 3Q-14 500292166500 1861770 46' 5.10 23" 6/26/2009 7 6/30/2009 3Q-22 500292262500 1951860 SF NA 19" 6/26/2009 6 6/30/2009 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a short list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. The top-fill operation was completed on August 24, 2003. Dowell-Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender for each well. The cement was pumped from the bottom of the void to the top Of the conductor on each well via high pressure hose. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call Nina Woods or me at 907-659-7224, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Problem Well Supervisor Attachment SOA qtNEE' SE? O 8 20113 ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field WELLS PTD# TOC VOLUME TYPE SACKS ft BBLS Cement 1 H-01 1930060 18.0 3.74 Prod 22.6 1 H-21 1930460 21.0 3.66 Prod 22.1 2K-08 1890830 6.0 1.8 Prod 10.9 3M-09 1870290 46.0 8.32 Prod 50.2 3M-10 1870350 52.0 10.1 Inj 61.0 .~ 3Q-03 1911260 14.5 3.44 Prod 20.8 PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS 91-126 CBT L 8585-9592 5 CDN L 5090-9640~ LWD 2&5 91-126 91-126 CDR L 5090-9640, LWD 2&5 91-126 CET 5 91-126 407 91-126 8585-9512 COMP DATE: 02/16/92 01/20/92-02/17/92 91-126 91-126 DAILY WELL OP 5188 T 5090-9640, OH-CDR/CDN Are dry ditch samples required? yes~d received? Was the well cored? ye & description received? Are well tests require~~.ved? Well is in compliance I~itiai Comments Page- 1 Date' 01/18/94 SCALE DATE_RECVD 02/14/92 02/11/92 02/11/92 02/14/92 04/01/92 04/01/92 03/31/92 02/28/92 ~ STATE OF ALASKA 0 I~ 16 I 1. AI..~or',A OIL AND GAS CONSERVATION COMMi,b~ON REPORT OF SUNDRY WELL OPERATIONS 1, Operations Performed: Operation Shutdown ~ Pull tubing Alter casing Stimulate X Plugging Perforate _ Repair well ~ Other 2. Name of Operator ARCO Alaska. Ins. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2211' FNL, 2328' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 1303' FNL, 1951' FWL, Sec. 8, T13N, R9E, UM At effective depth 1303' FNL, 1951' FWL, Sec. 8, T13N, R9E, UM At total depth 1122' FNL, 1912' FWL, Sec. 8, T13N, R9E, UM 12. Present well condition summary Total Depth' measured true vertical 9640' feet Plugs (measured) 6758' feet 6. Datum elevation (DF or KB) .. 63' RKB 7. Unit or Property name .Kuparuk River Unit 8. Well number 3Q-03 9. Permit number/approval number (31-126 10. APl number 50-029-22221 '11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 9516' feet Junk (measured) true vertical 6664' feet Casing Length Size Cemented Measured depth Conductor 1 20' 1 6" 1875 Sx Pole Set 1 2 0' Surface 52 1 0' 9 5/8" 1240 SX PF E & 521 0' 495 Sx Class G True vertical depth 120' 3906' Production 9605' 7" 212 Sx Class G & 9605' Perforation depth: measured 9361 '-9401' true vertical 6547'-6577' Tubing (size, grade, and measured depth) 3-1/2" 9.3# J-55, EUE 8 RD, ABMOD, Tail @ 9285' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-4A MOD, 1887', Packer: Camco HRP-1-SP, 9262' 6731' Aiast4a 0it & Gas Cons. Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) Perforated interval. Treatment description including volumes used and final pressure Refractured A Sand w/125 M LBS proppant & 711 BBL gelled sea water. Final pressure 6500 psi. 14. ,Representative Daily A. yerage Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 140 30 0 1350 153 Subsequent to operation 1104 432 0 60 166 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector __ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Title Operations Engineer Date SUBMIT I~ DOI~LICATE ~RCO Alaska, Inc. --~,. --. WELL SERVICE REPORT Sub,!diary of Atlantic Richfiel0 Company ~ WELL ,/--- ~ PBD~ _., / ~PIELD- DISTRICT. STATE -' ~DAYS DATE~ ~ ~ ,. CONTRACTOR "'~~ OPERATION AT REP~RTT~ME ..... ~ ~ -. ..... ~ ~ .' v~,, ' - _ ..... . , ~~,.~:.' -~ z~//z ~ · ¢ ~: ........ .¢ - -- .._ ,'- -., ~--' ~~ .... ,.,,% ~¢ .X .~-_ ~J ~-~'-~- ' ' - ' ¢.~4-~ _., ...... _%:/=. , .... :"- ;,..~.. ~ ~,/ .__..cz' ./--.z~_--' / -" "/~ · '"'""'~"~'""% t' ,//,-',~': ,t ~ .' , .. ~/t~' ~ L .,,,: ~.'.~ ......... " ' .... /.,,'~ / ~' -~ ~-4~~ ...... ..... ~ ~- -... ~~ ..~-/'~v ~ ~¢A .... ~~ .... _~ ~s...~. ¢~:-/ ....... '¢1.; ~ ~/~ ' ~-' ................. .' ,; ) ,/~ ~/~/ ~ :__~_ CHECK-f HiS BLOCKIF SUMMARY OONTINUED ON BACK Weather i emi:). Chtil Facter Visibility I Wlnd Vel. Report i ~F ', °F miles [ ~EMAR, KS CONT!NUED; CAMCO OTIS SCHLUMBERGER DRESSE R,ATLA'S DESCRIPTION DOWELL HALLIBURTON ARC-ftC COiL TUBING FRACMASTER B, d. HUGHES Sungry~s~o..q Pre-Job Satety TOTAL'FIELD ESTIMATE DAILY ACCUM, TOTAL .? ' ' '- STATE OF ALASKA "~- ALASKA OIL AND GAS CONSERVATION COMMISSION :~"~ ~ ~:~' '~:~ ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Sewice Well OIL ~] GAS [] SUSPENDED ['--'] ABANDONED D SERVICE [~ 2 Name of Operator 7 Permil Number ARCO Alaska, Inc 91-126 3 Address 8 APl Number P.O. Box 100360, Anchora~e, AK 99510-0360 ...... ~- 50-029-2,'~21 ~ ~;~?;~! ~':~;i:i~'~? 9 Unit or Lease Name 4 Location of well at surface ~ ...... .,~,~, ~ ! ~'~'"'" ~ .... "~ KUPARUK RIVER AtTop Producing Interval ' '~ '" !?"~;~ i ! ~;~.~:..,~;::~ 10 Well Number ''~" ~ ? 30-03 At Total Depth ....................... ;~; 11 Field and Pool 1122' FNL, 1912' FVVL, SEC 8, T13N, R9E KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No, KUPARUK RIVER OIL POOL RKB 63', PAD 22' GLI ADL 373301, ALK 4162 12 Date Spudded01/20/92. 13 Date T.D. Reached01/26/92. 14 Date Comp. , Susp. or Aband.02/16/92. J 15 Water Depth, if ofishOmN A feet MSL J16 No. of Comple'ionsl 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost MD,6758' TVD 9516' MD, 6664' TVD YES [~ NO [-'] 1887' feet MD 1700' APPROX 9640' 22 Type Electric or Other Logs Run CDN/CDR/GR/CET/CBT/GCT 23 CASING, LINER AND CEMENTING RECORD I SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16' 62.5# H-40 SURF 120' 24" 1875 SX POLE SET(foam type) 1986 conductor 9-5/8" 36# J-55 SURF 5210' 12-1/4" 1240 sx PF E, 495 SX CLASS G 7" 26# J-55 SURF 9605' 8" 212 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and !25 TUBING RECORD intewal, size and number) SIZE DEPTH SET (MD) PACKER SET IMDI 9361'-9401' W/ 4-1/2 "CSG GUN @ 4 SPF MD 6547'-6577' TVD 3-1/2" 9.3# 9285' 9262' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE · .... 28 CORE DATA E ~ ~ ~ r' ~'~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. REt tV Alaska 0il & t3as Cons. 'Anch0rago Form 10-407 Submil in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .~9. 130' GECIOGIC MA~ERS FORMATION TESTS ,, Include interval tested, pressure data, all fluids recoverd and gravily, ,, Nrc. AS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. NA KUPARUK C TOP 9357' 6544' (UPARUK C BOTTOM 9368' 6552' (UPARUK A TOP 9368' 6552' KUPARUK A BOTTOM 9430' 6599' , 31. LIST OF ATTACHMENTS GYRO, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cOres taken, indicate "none". Form 10-407 ~ARCO ALASKA INC. ~ DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 3Q-03 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 373301 ALK 4162 50-029-22221 91-126 ACCEPT: 01/19/92 SPUD: 01/20/92 RELEASE: 01/28/92 OPERATION: DRILLING RIG: PARKER 245 AFE: AK6217 WI: 55.252072 01/20/92 ( 1) TD: 0'( SUPV:SMS o) REPAIR DIVERTER MW: 8.7 VIS: 84 MOVE RIG FROM 3Q-4 TO 3Q-3. ACCEPT RIG 2000 1/19/92. NU DIVERTER & TEST. REPAIR LEAKING DIVERTER VALVE. DAILY:S27,669 CUM:$27,669 ETD:SO EFC:$1,527,669 01/21/92 (2) TD: 2000'(2000) SUPV:SMS DRILLING AT 2000' MW: 8.9 VIS: 70 CONT WORK ON DIVERTER. SPUDDED AT 09:30. DRILLED TO 210', CHANGE BHA. DRILL FROM 210' TO 2000' DAILY:S74,002 CUM:$101,671 ETD:SO EFC:$1,601,671 01/22/92 (3) TD: 5290'(3290) SUPV:CTD DRILLING DRILLED FROM 2000' TO 5290' DAILY:S60,748 CUM:$162,419 ETD:SO MW: 9.1 VIS: 48 EFC:$1,662,419 01/23/92 ( 4) TD: 5313'( 23) SUPV:CTD RUNNING 9-5/8" CASING MW: 9.5 VIS: 43 DRILLED FROM 5290' TO 5313' CBU, SHORT TRIP, CIRC AND COND MUD FOR CASING. LOST 1000 PSI, POH, ONE NOZZLE WASHED OUT OF BIT. LEFT NOZZLE IN HOLE. RU AND RUN 9-5/8" CASING. DAILY:S161,000 CUM:$323,419 ETD:SO EFC:$1,823,419 01/24/92 ( 5) TD: 5313'( SUPV:CTD o) MU BHA MW: 9.4 VIS: 46 RAN 131 JTS 9-5/8" CASING. TAGGED BOTTOM AT 5240', SET SHOE AT 5209' CIRC C~SING, PUMP 100 BBL WATER SPACER, 1240 SX TYPE E LEAD CEMENT, 495 SX CLASS G TAIL CEMENT. DISPLACED WITH 402 BBL MUD, BUMPED PLUG TO 2000 PSI. 90 BBL CEMENT TO SURFACE. FLOATS HELD. ND DIVERTER, MU W/<M CASING HEAD, NU BOPE, TEST SAME. MU BHA. DAILY:S167,865 CUM:$491,284 ETD:SO EFC:$1,991,284 01/25/92 (6) TD: 7770'(2457) SUPV:CTD DRLG MW: 9.2 VIS: 36 MU BHA. RIH. DRLD CMT, FC, FS, 10' NEW HOLE. TEST FORM TO 12.5 EMW. DRLD 5323'-7770' -- DAILY:S57,487 CUM:$548,771 ETD:SO EFC:$2,048,771 01/26/92 (7) TD: 9393'(1623) SUPV:CTD DRLG DRLD 7770'-9393' DAILY:S75,798 CUM:$624,569 ETD:SO MW:10.2 VIS: 36 EFC:$2,124,569 01/27/92 (8) TD: 9640'( 247) SUPV:CTD POH FOR 7" CSG MW:ll.1 VIS: 42 DRLD 9393'-9640' TD. SHORT TRIP. INCREASE MW TO 11.1 PPG. POH FOR 7" CSG. DAILY:S75,667 CUM:$700,236 ETD:SO EFC:$2,200,236 1/28/92 ( 9) TD: 9516'( SUPV:CTD o) SET SLIPS 7" CSG 7"~ 9604' MW: 0.0 VIS: 0 POH. RAN 7" CSG. CMTD W/17 SX CL G LEAD SLURRY & 195 SX CL G TAIL. HOWCO SURGE TANK PLUGGED ON LEAD SLURRY. ND BOP. DAILY:S297,017 CUM:$997,253 ETD:SO EFC:$2,497,253 01/29/92 (10) RIG RLSD 7"~ 9604' MW: 0.0 VIS: 0 TD: 9516'( 0) SET SLIPS. NU TBG HD. RLSD RIG 2200 1/28/92. SUPV:CTD DAILY:S90,877 CUM:$1,088,130 ETD:SO EFC:$2,588,13 SIGNATURE: ~-~ ~ DATE: ~/2 7/~ 7,_ DRILLING SU~ERINTEND~ ARCO ~LASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 3Q-03 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 373301 ALK 4162 50-029-22221 91-126 ACCEPT: 02/14/92 SPUD: RELEASE: 02/16/92 OPERATION: DRILLING RIG: COMPLETION AFE: AK6217 WI: 55.252072 02/15/92 (11) TD: 9516 PB: 9516 SUPV:GB/SB 02/16/92 (12) TD: 9516 PB: 9516 SUPV:GB/SB PERFORATE 'A' AND 'C' SAND 7"~ 9604' MW:ll.4 NaC1/Br MOVE RIG F/3Q-04 TO 3Q-03,ACCEPT RIG AT 1700 HRS 2/14/92,ND TREE,NU BOPE,TEST BOPE TO 3000 PSI,OK, RU SWS,TEST LUBRICATOR TO 1000 PSI,MU GUN #1,RIH,TAG OBSTRUCTION AT ll8',POH,RD SWS LOAD AND STRAP DC,SET WEAR RING,MU 6-1/8" BIT AND SCRAPER RIH W/SAME,TAG ICE PLUG AT ll8',RU CIRC HD,WASH DN THRU ICE TO 150 CIRC F/10 MIN, CONT RIH W/DC TO 379',CIRC F/15 MIN, POH LD DC AND BHA, PULL WEAR RING, TEST 7" CSG TO 2500 PSI F/15 MIN, OK, RU SWS,TEST LUBRICATOR, RIH AND PERF F/9381-9401',4 SPF, 180 DEG, ORIENTED, POH,MU GUN #2,RIH DAILY:S31,008 CUM:$1,119,138 ETD:SO EFC:$2,619,138 ND BOPE 7"~ 9604' MW:ll.7 NaCl/Br CONT RIH W/PERF GUN#2,PERF F/9361-9381',4 SPF, 180 DEG ORIENTED, POH,RD SWS,LOAD PIPE SHED W/COMP TBG/JEWELRY TALLY/DRIFT/STRAP SAME, INSTALL SEAL RINGS,RIH W/ 3-1/2" SINGLE COMP AS PER PROCEDURE, PU SSSV,MU C-LINE,TEST SAME TO 5K,OK, CONT RIH,MU HGR AND C-LINE,TEST SAME TO 5K, OK,LAND TBG RILDS,SET PKR W/2500 PSI ON TBG, PRESS ANN TO 1000 PSI TO CHECK SEALS,OK, BLEED PRESS,BOLDS,PU AND SHEAR PBR PBR ALREADY SHEARED, RELAND TBG, RILDS,TEST SSSV W/500 PSI DIFF SSSV FAILED, OPEN AND CLOSE SSSV, CIRC,CHECK SURFACE LINES RETEST SSSV, FAILED, PUMP DRY JOB, POH W/ TBG TO SSSV, C/O SSSV MU C-LINE,TEST SAME TO 5K, OK, LOST 7 C-LINE BANDS POH,RIH W/TBG,MU HGR AND C-LINE, TEST SAME TO 5K,OK, LAND TBG,RILDS TEST SSSV W/500 PSI DIFF,OK,TEST ANN TO 2500 PSI F/15 MIN, OK PRESS TO 4200 PSI AND SHEAR SOS,BLEED OFF PRESS,PULL LJ,SET BPV, ND BOPE DAILY:S180,104 CUM:$1,299,242 ETD:SO EFC:$2,799,242 02/17/92 (13) TD: 9516 PB: 9516 SUPV:GB/SB RELEASE RIG 7"~ 9604' MW:ll.7 NaCl/Br ND BOPE,NU TREE,TEST PACKOFF AND FLANGE TO 5K,OK,?ULL BPV SET TEST PLUG,TEST TREE TO 250/5000 PSI,OK, PULL TEST PLUG DISPLACE ANN W/12 BBLS DIESEL,BULLHEAD 4 BBLS DIESEL DN TBG SITP=600,SICP=100,SECURE WELL, TRANSFER 125 BBLS BRINE F/ PITS TO BRINE TANK,RELEASE RIG AT 0900 HRS 2/16/92,MOVE RIG TO 3Q-01 DAILY:S13,958 CUM:$1,313,200 ETD:SO EFC:$2,813,200 SIGNATURE: DRILLING S~ERINTEND~T RECEIVED APR - 1 1992 Alaska Oil & Gas Co,~s. Commission Anchorage SUB - S URFA CE DIRECTIONAL SURVEY ~'J UIDANCE [~'~ ONTINUOUS ~ OOL RECEIVED APR - 1 199~ Alaska Oil & Gas Cons. Commission ~Anchorage Company ARCO ALASKA, INC. Well Name 3Q-3(2211'FNL,Z328'FEL,SEC 17,T13N,R9E) Field/Location KUPARUK RIVER, NORTH SLOPE, ALASKA Job Reference No. 92114 Logqed BV: T. WEST Date 31-JAN- 1992 Computed By: R. KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEV CUSTOMER LISTING FOR ARCO ALASKA, INC. 3Q - 3 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE: 31-JAN-1992 METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: ENGINEER: T. WEST TANGENTIAL- Averaged deviation and azimuth LINEAR HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 9 DEG 42 MIN WEST COMPUTATION DATE: 22-MAR-92 PAGE 1 ARCO ALASKA, INC. 3Q - 3 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 31-JAN-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTZCAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 100 O0 100 O0 37 200 O0 199 99 136 300 O0 299 96 236 400 O0 399 82 336 500 O0 499 39 436 600 O0 598 45 535 700,00 696,62 633 800,00 793,70 730 0 O0 -63 O0 0 0 N 0 0 E O0 0 17 N 9 27 W 99 0 58 N 16 16 W 96 1 57 N 15 1W 82 4 1 N 7 26 W 39 6 40 N 0 43 E 45 9 0 N 0 23 E 62 12 22 N 1 55 W 70 15 28 N 1 40 W 0 O0 0 22 1 20 3 58 8 92 17 89 31,28 50.05 73,77 900,00 889,74 826,74 16 42 N 1 36 W 101,32 0 O0 0 40 0 9O 2 88 0 69 2 73 4 29 2 06 2 39 0 84 0,00 N 0,22 N 1,17 N 3.48 N 8,71 N 17,75 N 31,37 N 50,34 N 74.27 N 102, 10 N 0.00 E 0.00 N 0 0 E 0.01 W 0.22 N 2 0 W 0.26 W 1.20 N 12 45 W 0.91 W 3.60 N 14 44 W 1,96 W 8,93 N 12 42 W 2.34 W 17.90 N 7 30 W 2,14 W 31.45 N 3 54 W 2,58 W 50.41 N 2 56 W 3.30 W 74.35 N 2 33 W 4,05 W 102,18 N 2 16 W 1000.00 984,84 921,84 20 4 N 4 12 W 131,96 1100,00 1077,07 1014,07 25 20 N 8 48 W 170,45 1200,00 1166,27 1103,27 28 7 N 8 35 W 215.61 1300,00 1254,03 1191,03 29 8 N 6 19 W 263,52 1400,00 1341,26 1278,26 29 32 N 3 6 W 312,22 1500,00 1428,02 1365,02 29 54 N 1 50 W 361.54 1600,00 1514,58 1451,58 30 14 N 1 25 W 411,10 1700,00 1600,88 1537,88 30 33 N 2 1 W 461,13 1800,00 1686,66 1623,66 31 33 N 3 57 W 512,16 1900,00 1769,93 1706,93 36 12 N 7 7 W 567,30 5.47 4,66 1 ,2O 1 ,29 1 ,56 O, 68 0,29 0,77 2,56 6,58 132.96 N 5.35 W 133.06 N 2 18 W 171.24 N 9.87 W 171.52 N 3 18 W 215.83 N 17.01 W 216.50 N 4 30 W 263.37 N 23.25 W 264.40 N 5 3 W 312.10 N 27.20 W 313.29 N 4 59 W 361.77 N 29.30 W 362.96 N 4 38 W 411.83 N 30.61 W 412.97 N 4 15 W 462.33 N 32.09 W 463.45 N 3 58 W 513.67 N 34.67 W 514.84 N 3 52 W 568.71 N 39.90 W 570.11 N 4 1 W 2000,00 1848,23 1785,23 39 37 N 8 50 W 629,45 2100,00 1925,70 1862 70 39 15 N 7 33 W 692,66 2200,00 2002,07 1939 2300,00 2076,25 2013 2400,00 2146.54 2083 2500,00 2213,73 2150 2600,00 2279,00 2216 2700,00 2343,60 2280 2800,00 2407,30 2344 2900,00 2470,74 2407 07 41 8 N 6 25 W 757,14 25 43 29 N 5 32 W 824.04 54 46 54 N 5 40 W 894.95 73 48 49 N 6 9 W 968,83 O0 49 31 N 6 41 W 1044.48 60 50 1 N 6 23 W 1120,70 30 50 48 N 7 15 W 1197,68 74 50 31 N 6 59 W 1274,90 0 46 1 1 3 1 2 0 0 0 0 630,23 N 48,90 W 632,12 N 4 26 W 19 692,82 N 57,85 W 695.23 N 4 46 W 61 756.88 N 65.73 W 759.73 N 4 58 W 20 823.57 N 72.63 W 826.77 N 5 '2 W 65 894.34 N 79.51 W 897.87 N 5 5 W 20 968.02 N 86.95 W 971.92 N 5 8 W 58 1043.29 N 95.57 W 1047.66 N 5 14 W 62 1119,13 N 104,23 W 1123,98 N 5 19 W .43 1195,67 N 113,33 W 1201.03 N 5 25 W 51 1272,38 N 122,93 W 1278,31 N 5 31 W 3000,00 2533,81 2470,81 51 18 N 7 12 W 1352,42 3100 O0 2596,40 2533,40 51 11 N 6 44 W 1430,32 32OO 3300 3400 3500 3600 37OO 3800 3900 O0 2658.83 2595.83 51 41 N 6 29 W 1508.32 O0 2719.59 2656.59 53 20 N 7 57 W 1587.66 O0 2778.89 2715.89 53 55 N 10 6 W 1668.16 O0 2837.63 2774.63 54 3 N 10 43 W 1749.08 O0 2896.52 2833.52 53 40 N 10 7 W 1829.89 O0 2956.01 2893.01 53 16 N 9 46 W 1910.27 O0 3015.93 2952.93 53 10 N 9 17 W 1990.33 O0 3076.15 3013.15 52 34 N 7 31 W 2070.14 0.46 1349.39 N 132.43 W 1355.88 N 5 36 W 0.61 1426.80 N 141.96 W 1433.85 N 5 41 W 1.32 1504.42 N 150.83 W 1511.96 N 5 44 W 0 95 1583.21 N 160.76 W 1591.35 N 5 48 W 2 91 1662.79 N 172.97 W 1671.76 N 5 56 W 0 08 1742.32 N 187.93 W 1752.43 N 6 9 W 0 88 1821,80 N 202,61 W 1833,03 N 6 21 W 0 50 1900,99 N 216,38 W 1913,26 N 6 30 W 1 31 1979,91 N 229.81 W 1993,21 N 6 37 W 1 56 2058,90 N 241.45 W 2073,00 N 6 41 W COMPUTATION DATE: 22-MAR-92 PAGE 2 ARCO ALASKA, [NC. 3Q - 3 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 31-JAN-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORD[NATES HORIZ. DEPARTURE MEASURED VERT[CAL VERTICAL DEVIATION AZZMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZZMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 4000.00 3137.50 3074.50 51 48 N 6 2 W 2149.00 4100.00 3199.75 3136.75 51 10 N 5 7 W 2227.04 4200.00 3262.46 3199.46 51 11 N 7 40 W 2304.78 4300.00 3325.56 3262.56 50 30 N 8 15 W 2382.33 4400.00 3389.59 3326.59 50 6 N 8 4 W 2459.12 4500.00 3454.04 3391.04 49 36 N 7 45 W 2535.54 4600.00 3519.17 3456.17 49 19 N 9 3 W 2611.38 4700.00 3583.68 3520.68 50 8 N 12 40 W 2687.75 4800.00 3648.14 3585.14 49 24 N 13 1 W 2764.08 4900.00 3713.21 3650.21 50 10 N 13 7 W 2839.88 1.57 2137.30 N 250.82 W 2151.96 N 6 42 W 1.04 2215.21 N 258.19 W 2230.20 N 6 39 W 1.70 2292.64 N 266.62 W 2308.09 N 6 38 W 1.38 2369.44 N 277.58 W 2385 64 N 6 41 W 0.21 2445.48 N 288.47 W 2462 43 N 6 44 W 0.54 2521.22 N 298.90 W 2538 88 N 6 46 W 3.49 2596.35 N 309.51 W 2614 74 N 6 48 W 0.94 2671.28 N 324.41 W 2690 91 N 6 55 W 1.10 2745.79 N 341.53 W 2766 95 N 7 5 W 3.84 2819.76 N 358.68 W 2842 48 N 7 15 W 5000.00 3775.66 3712.66 51 41 N 13 20 W 2917.83 5100.00 3837,69 3774.69 51 40 N 13 51 W 2996.09 5200.00 3899.79 3836.79 51 29 N 14 1 W 3074.25 5300.00 3962.51 3899,51 50 48 N 13 59 W 3151.93 5400.00 4025.50 3962.50 51 5 N 13 58 W 3229,37 5500.00 4088.28 4025.28 51 12 N 13 52 W 3307.00 5600.00 4150.93 4087.93 51 11 N 13 47 W 3384.74 5700.00 4213.32 4150.32 51 54 N 12 48 W 3462.72 5800.00 4274.47 4211.47 52 27 N 12 0 W 3541.77 5900.00 4335.40 4272.40 52 30 N 12 2 W 3621.00 0.42 2895 78 N 376.56 W 2920.16 N 7 25 W 0.00 2972 02 N 395.00 W 2998.16 N 7 34 W 0.40 3048 10 N 413,83 W 3076.07 N 7 44 W 0.42 3123 69 N 432.62 W 3153 51 N 7 53 W 0.10 3199 06 N 451 39 W 3230 74 N 8 2 W 0,11 3274 61 N 470 12 W 3308 18 N 8 10 W 0.10 3350 30 N 488 71 W 3385 75 N 8 18 W 2.23 3426 30 N 506 91 W 3463 59 N 8 25 W 0.05 3503.63 N 523 64 W 3542 55 N 8 30 W 0.35 3581.19 N 540 15 W 3621 69 N 8 35 W 6000.00 4395.79 4332.79 53 25 N 11 58 W 3700,64 6100,00 4455.18 4392.18 53 36 N 11 50 W 3781.04 6200.00 4514.37 4451.37 53 45 N 11 51 W 3861.58 6300.00 4573.46 4510.46 53 48 N 11 56 W 3942.19 6400.00 4632.40 4569.40 53 54 N 12 1 W 4022.92 6500.00 4691.18 4628.18 54 4 N 12 3 W 4103.75 6600,00 4749.76 4686.76 54 12 N 11 58 W 4184.73 6700.00 4808.14 4745.14 54 21 N 11 55 W 4265.86 6800.00 4866.42 4803.42 54 7 N 11 38 W 4347.06 6900.00 4925.83 4862.83 53 19 N 9 44 W 4427.49 0.92 3659.14 N 556.75 W 3701 26 N 8 39 W 0.84 3737.89 N 573.25 W 3781 0.47 3816.78 N 589.75 W 3862 1.72 3895.73 N 606.34 W 3942 0.26 3974.76 N 623.11 W 4023 0.17 4053.88 N 639.98 W 4104 0.21 4133.15 N 656.86 W 4185 0.18 4212.59 N 673.62 W 4266 2.26 4292.11 N 690.34 W 4347 0.48 4371.21 N 704.94 W 4427 59 N 8 43 W 07 N 8 47 W 63 N 8 51W 3O N 8 55 W O8 N 8 58 W 02 N 9 2 W 10 N 9 5 W 27 N 9 8 W 69 N 9 10 W 7000,00 4985.61 4922.61 52 58 N 9 59 W 4507.65 7100.00 5046.44 4983.44 52 28 N 9 50 W 4587.02 7200,00 5107.17 5044.17 52 44 N 9 52 W 4666.47 7300.00 5167.56 5104.56 52 56 N 9 58 W 4746.17 7400.00 5228.35 5165.35 51 36 N 9 10 W 4825.57 7500.00 5291.20 5228.20 50 57 N 8 13 W 4903.34 7600.00 5354.06 5291.06 51 9 N 8 19 W 4981.08 7700.00 5416.66 5353.66 51 17 N 8 15 W 5059.04 7800,00 5479.10 5416.10 51 26 N 8 14 W 5137.12 7900.00 5541.19 5478.19 51 48 N 8 26 W 5215.49 1 87 4450.19 N 718.61 W 4507.84 N 9 10 W 0 23 4528.38 N 732.28 W 4587.21 N 9 11 W 0 30 4606.66 N 745.85 W 4666.65 N 9 12 W 0 25 4685.17 N 759.61 W 4746 34 N 9 13 W 3 42 4763.42 N 773.08 W 4825 74 N 9 13 W 0 19 4840.35 N 784.54 W 4903 52 N 9 12 W 0.33 4917.31 N 795.71 W 4981 27 N 9 12 W 0.30 4994.47 N 806.98 W 5059 25 N 9 11 W 0.31, 5071.79 N 818.10 W 5137 35 N 9 10 W 0.56 5149.35 N 829.47 W 5215 73 N 9 9 W COMPUTATION DATE: 22-MAR-92 PAGE 3 ARCO ALASKA, INC. 3Q - 3 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 31-JAN-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T, WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 8000.00 5603 27 5540.27 51 19 N 8 39 W 5293.87 8100.00 5667 8200.00 5733 8300.00 5799 8400.00 5865 8500.00 5931 8600.00 5996 8700.00 6062 8800.00 6132 8900.00 6202 66 5604 66 48 54 N 8 14 W 5370.35 35 567O 2O 5736 36 5802 38 5868 93 5933 70 5999 O7 6069 91 6139 35 48 58 N 8 11 W 5445,72 20 48 36 N B 0 W 5520.95 36 48 36 N 7 58 W 5595.90 38 48 49 N 8 4 W 5670.98 93 49 15 N 8 12 W 5746,47 70 47 29 N 9 6 W 5821.77 07 45 12 N 9 46 W 5893.78 91 44 45 N 9 37 W 5964.36 1 79 5226.88 N 841 11 W 5294.12 N 9 8 W 0 22 5302.54 N 852 38 W 5370.62 N 9 8 W 0 23 5377.17 N 863 13 W 5446.00 N 9 7 W 0 25 5451.68 N 873 69 W 5521.24 N 9 6 W 0 02 5525.94 N 884 og W 5596.22 N 9 5 W 0 30 5600.32 N 894 55 W 5671.32 N 9 5 W 0 43 5675.08 N 905.22 W 5746.83 N 9 4 W 5.23 5749.58 N 916.29 W 5822.14 N 9 3 W 1,02 5820.58 N 928.29 W 5894.14 N 9 4 W 0.23 5890.16 N 940.16 W 5964.72 N 9 4 W 9000.00 6274 74 6211 74 42 53 N 10 33 W 6033.93 9100.00 6349 33 6286 33 40 44 N 12 12 W 6100'.49 9200.00 6425 35 6362 35 40 39 N 12 29 W 6165.38 9300.00 6500 87 6437 87 41 11 N 12 0 W 6230.87 9400,00 6576 34 6513 34 40 55 N 12 9 W 6296.42 9500.00 6651 92 6588 92 41 1 N 12 11 W 6361.83 9600.00 6727 38 6664 38 41 1 N 12 11 W 6427.39 9640,00 6757 56 6694 56 41 1 N 12 11 W 6453,62 3.63 5958.70 N 952.07 W 6034.28 N 9 5 W 2 09 6023.98 N 965.21 W 6100.82 N 9 6 W 1 02 6087.42 N 979.24 W 6165.68 N 9 8 W 0 85 6151.48 N 993.15 W 6231.13 N 9 10 W 0 21 6215.65 N 1006.78 W 6296,66 N 9 12 W 0 O0 6279.65 N 1020.56 W 6362,04 N 9 14 W 0 O0 6343.80 N 1034.40 W 6427.58 N 9 16 W 0 O0 6369.46 N 1039.94 W 6453.80 N 9 16 W COMPUTATION DATE: 22-MAR-92 PAGE 4 ARCO ALASKA, INC. 3Q - 3 KUPARUK RIVER NORTH 5LOPE, ALASKA DATE OF SURVEY: 31-JAN-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE ,MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 20O0 3000 coo0 5000 6000 7000 8000 9000 0.00 -63.00 0 0 N 0 0 E 0.00 O0 984.84 921.84 20 4 N 4 12 W 131.96 5 O0 1848.23 1785.23 39 37 N 8 50 W 629.45 0 O0 2533.81 2470.81 51 18 N 7 12 W 1352.42 0 O0 3137.50 3074.50 51 48 N 6 2 W 2149.00 1 O0 3775.66 3712.66 51 41 N 13 20 W 2917.83 0 O0 4395.79 4332.79 53 25 N 11 58 W 3700.64 0 O0 4985.61 4922.6t 52 58 N 9 59 W 4507.65 1 O0 5603.27 5540.27 51 19 N 8 39 W 5293.87 1 O0 6274.74 6211.74 42 53 N 10 33 W 6033.93 3 0 O0 47 46 63O 46 1349 57 2137 42 2895 92 3659 87 445O 79 5226 63 5958 132 96 N 5 35 W 133 23 N 48 9O W 632 39 N 132 43 W 1355 30 N 250 82 W 2151 78 N 376 56 W 2920 14 N 556.75 W 3701 19 N 718.61 W 4507 88 N 841.11 W 5294 70 N 952.07 W 6034 0.00 N 0 O0 E 0 O0 N 0 0 E O6 N 2 !8 W 12 N 4 26 W 88 N 5 36 W 96 N 6 42 W 16 N 7 25 W 26 N 8 39 W 84 N 9 10 W 12 N 9 8 W 28 N 9 5 W 9640.00 6757.56 6694.56 41 1 N 12 11 W 6453.62 0.00 6369.46 N 1039.94 W 6453.80 N 9 16 W COMPUTATION DATE: 22-MAR-92 PAGE ARCO ALASKA, INC. 3Q - 3 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 31-JAN-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVZATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 0.00 0.00 -63.00 0 0 N 0 0 E 63.00 63 O0 0.00 0 12 N 15 49 W 163.00 163 O0 100,00 0 37 N 16 24 W 263.02 263 O0 200.00 1 26 N 15 32 W 363.10 363 O0 300.00 3 23 N 10 31 W 463.39 463 O0 400.00 5 37 N 1 10 W 564.15 563 O0 500.00 8 9 N 0 48 E 665.63 663.00 600.00 11 32 N 1 55 W 768.21 763.00 700.00 14 33 N t 39 W 872.10 863.00 800.00 t6 24 N 1 36 W 0.00 0.07 0.69 2.55 6.49 14.03 26.07 42.99 65.59 93.45 0.00 0.25 0.84 0 24 2 94 4 17 1 64 2 27 ,4 47 1 .08 0.00 N ' 0.08 N 0.68 N 2.48 N 6.31 N 13.81 N 26. O7 N 43.21 N 66.02 N 94.15 N 0 O0 E 0.00 N 0 0 E 0 03 E 0.08 N 19 9 E 0 12 W 0.69 N 10 18 W 0 64 W 2.56 N 14 33 W 1 60 W 6.5'1 N 14 14 iN 2 34 W 14.01 N 9 36, W 2 21 W 26.16 N 4 50 W 2 34 W 43.27 N 3 6 iN 3 06 iN 66.09 N 2 39 iN 3.83 W 94.23 N 2 20 iN 976.83 963.00 900 O0 18 56 N 2 56 W 124.27 1084.49 1063.00 1000 O0 24 34 N 8 13 W 163.92 1196.29 1163.00 1100 O0 28 5 N 8 39 iN 213.86 1310.27 1263.00 1200 O0 29 11 N 6 1 W 268.51 1425.02 1363.00 1300 O0 29 45 N 2 43 iN 324.51 1540.37 1463.00 1400 O0 30 0 N 1 29 W 381.49 1656.07 1563.00 1500 O0 30 20 N 1 43 iN 439.09 1772.31 1663.00 1600 O0 31 4 N 3 19 iN 497.86 1891.43 1763.00 1700.00 35 40 N 6 47 W 562.28 2019.15 1863.00 1800.00 39 25 N 8 37 W 641.63 5.27 5.69 .164.78 N 1.12 1.38 0.84 0.52 0.57 1.79 6.50 1.99 8.91W 165 214.10 N 16.75 W 214 268.34 N 23.78 W 269 324.46 N 27.83 W 325 381.91 N 29.87 iN 383 440.10 N 31.37 W 441 499.31 N 33.76 W 500 563.71 N 39.29 W 565 642.26 N 50.75 W 644 125.24 N 4.86 iN 125 33 N 2 13 W 02 N 3 6 W 76 N 4 28 W 39 N 5 4 iN 65 N 4 54 W 08 N 4 28 iN 22 N 4 5 W 45 N 3 52 W O8 N 3 59 W 27 N 4 31W 2148.48 1963.00 1900.00 40 11 N 7 4 W 723.59 2281.84 2063.00 2000.00 42 53 N 5 38 iN 811.65 2424.17 2163.00 2100.00 47 17 N 5 40 W 912 61 2575.38 2263.00 2200.00 49 25 N 6 42 W 1025 79 2730.27 2363.00 2300.00 50 15 N 6 32 W 1143 89 2887.84 2463.00 2400.00 50 30 N 7 1 W 1265 53 3046.69 2563.00 2500.00 51 16 N 7 5 W 1388 83 3206.75 2663.00 2600.00 51 47 N 6 31 W 1513 61 3373.07 2763.00 2700.00 53 46 N 9 9 W 1646 42 3543.20 2863.00 2800.00 54 0 N 10 33 W 1784.04 2.57 3.39 811.22 N 71.42 W 814 1.40 911.95 N 81.25 W 915 0.37 1024.70 N 93.39 W 1028 1.38 1142.22 N 106.84 W 1147 0.46 1263.07 N 121.79 W 1268 0.75 1385.56 N 136.97 W 1392 1.58 1509.68 N 151.43 W 1517 2.91 1641.36 N 169.33 W 1650 0.63 1776.69 N 194.38 W 1787 723.53 N 61.78 W 726 16 N 4 53 W 36 N 5 2 W 57 N 5 5 iN 95 N 5 12 iN 20 N 5 21W 92 N 5 30 iN 31 N 5 39 W 26 N 5 44 W 07 N 5 53 iN 29 N 6 15 W 3711.68 2963.00 2900.00 53 13 N 9 46 W 1919.63 3878.30 3063.00 3000.00 52 48 N 7 53 iN 2052.89 4041.12 3163.00 3100.00 51 35 N 5 25 W 2181.19 4200.86 3263.00 3200.00 51 10 N 7 41 W 2305.45 4358.54 3363.00 3300 O0 50 7 N 8 8 iN 2427.32 4513.81 3463.00 3400 O0 49 31 N 7 45 iN 2546.05 4667.76 3563.00 3500 O0 50 4 N 12 8 iN 2663.04 4822.79 3663.00 3600 O0 49 12 N 13 2 W 2781.32 4979.56 3763.00 3700 O0 51 45 N 13 19 W 2901.81 5140.81 3863.00 3800 O0 51 39 N 13 53 W 3028.01 0.31 1910.21 N 217.97 W 1922.61 N 6 31 iN 1.83 2041.79 N 239.13 W 2055.74 N 6 41 W 1.04 2169.40 N 254.02 W 2184.23 N 6 41 W 1.68 2293.30 N 266.71 W 2308.76 N 6 38 iN 0.09 2413.98 N 283.99 W 2430.63 N 6 43 W 0.59 2531.64 N 300.32 W 2549.39 N 6 46 W 1.91 2647.12 N 319.09 W 2666.29 N 6 52 iN 0.72 2762.62 N 345.42 W 2784.t3 N 7 8 W 0.31 2880.16 N 372.87 W 2904.20 N 7 23 W 0.13 3003.10 N 402.67 W 3029.97 N 7 38 iN COMPUTATION DATE: 22-MAR-92 PAGE 6 ARCO ALASKA, INC. 3Q - 3 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 31-JAN-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECT[ON SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG M[N DEG MIN FEET DEG/IO0 FEET FEET FEET DEG M[N 5300 78 3963 O0 3900.00 50 48 N 13 59 W 3152.53 5459 5619 5781 5945 6113 6282 6452 6622 6794 70 4063 O0 4000.00 51 6 N 13 56 W 3275.70 25 4163 O0 4100 O0 51 12 N 13 46 W 3399 70 ~9 4263 O0 4200 O0 52 27 N 11 59 W 3526 87 44 4363 O0 4300 O0 52 43 N 12 2 W 3657 06 !9 4463 O0 4400 O0 53 37 N 11 50 W 3791 64 30 4563 O0 4500 O0 53 42 N 11 54 W 3927 92 01 4663 O0 4600 O0 54 0 N 12 3 W 4064 94 65 4763.00 4700 O0 54 14 N 11 56 W 4203 10 14 4863.00 4800 O0 54 11 N 11 43 W 4342 31 0.39 3124.28 N 432.77 W 3154.11 N 7 53 W 0.32 3244.14 N 462.58 W 3276.95 N 8 7 W 0.33 3364.87 N 492.28 W 3400.69 N 8 19 W 0.05 3489.05 N 520.54 W 3527.66 N 8 29 W 0.82 3616,49 N 547.67 W 3657.72 N 8 37 W 0.78 3748.28 N 575.42 W 3792.19 N 8 44 W 0.84 3881.75 N 603.39 W 3928.37 N 8 50 W 0.28 4015.89 N 631.87 W 4065.30 N 8 57 W 0.27 4151.13 N 660.66 W 4203.37 N 9 3 W 1.79 4287.46 N 689.38 W 4342.52 N 9 8 W 6962.27 4963.00 4900.00 53 20 N 9 51 W 4477.45 7127.21 5063.00 5000.00 52 33 N 9 50 W 4608.62 7292.43 5163.00 5100.00 52 55 N 9 58 W 4740.13 7455.26 5263.00 5200.00 50 56 N 8 20 W 4868.61 7614.26 5363.00 5300.00 51 12 N 8 20 W 4992.18 7774.18 5463.00 5400.00 51 23 N 8 10 W 5116.95 7935.22 5563.00 5500.00 51 41 N 8 30 W 5243.14 8092.91 5663.00 5600.00 48 55 N 8 15 W 5365.01 8245.12 5763.00 5700.00 48 51 N 8 4 W 5479.72 8396.43 5863.00 5800.00 48 36 N 7 58 W 5593.22 0.37 4420.45 N 713 42 W 4477.65 N 9 10 W 0.24 4549.66 N 735 97 W 4608.80 N 9 11 W 0,21 4679.22 N 758 56 W 4740.31 N 9 12 W 0.56 4805.97 N 779 55 W 4868.79 N 9 13 W 0.31 4928.30 N 797 32 W 4992.38 N 9 11 W 0.19 5051.81 N 815 22 W 5117.17 N 9 10 W 0.70 5176.71 N 833.54 W 5243.38 N 9 9 W 0.31 5297.26 N 851.61 W 5365.27 N 9 8 W 0.42 5410.84 N 867.93 W 5480.01 N 9 7 W 0.00 5523.29 N 883.72 W 5593.54 N 9 5 W 8548 13 5963 O0 5900 O0 49 3 N 8 8 W 5707 25 8700 45 6063 8843 75 6163 8983 95 6263 9118 O3 6363 9249 77 6463 9382 35 6563 9514.68 6663 9640.00 6757 O0 6000 O0 6100 O0 6200 O0 6300 O0 6400 O0 6500 O0 6600 56 6694 O0 47 28 N 9 6 W 5822 O0 44 53 N 9 43 W 5924 O0 43 22 N 10 11 W 6022 O0 40 30 N 12 27 W 6112 O0 40'58 N 12 17 W '6197 O0 40 54 N 12 6 W 6284 O0 41 1 N 12 11 W 6371 56 41 1 N 12 11 W 6453 10 72 98 23 89 88 45 62 0.49 5636.24 N 899.65 W 5707.59 N 9 4 W 5 23 5749.91 N 916.34 W 5822.47 N 9 3 W 0 51 5851.08 N 933.52 W 5925.08 N 9 4 W 4 19 5947.93 N 950.08 W 6023.34 N 9 5 W 1 24 6035.47 N 967.71 W 6112.56 N 9 7 W 0 58 6119.21 N 986.21 W 6198.17 N 9 9 W 0 30 6204.35 N 1004.35 W 6285.12 N 9 12 W 0 O0 6289.07 N 1022.59 W 6371.66 N 9 14 W 0 O0 6369.46 N 1039.94 W 6453.80 N 9 16 W ARCO ALASKA, INC. 30 - 3 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD ?" CASING TD COMPUTATION DATE: 22-MAR-92 PAGE 7 DATE OF SURVEY: 31-JAN-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 2211' FNL & 2328' FEL, SEC17 T13N R9E UM MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COOED[NATES NORTH/SOUTH EAST/WEST 5210.00 3906.03 3843.03 9357.00 6543.84 6480.84 9368.00 6552.15 6489.15 9368.00 6552.15 6489.15 9430.00 6599.02 6536.02 9472.04 6630.83 6567.83 9516.00 6664.00 6601.00 9.605.00 6731.15 6668.15 9640.00 6757.56 6694.56 3055 69 N 6188 11N 6195 16 N 6195 16 N 6234 84 N 6261 71N 6289.92 N 6347.01N 6369.46 N 415.72 1000.89 1002.39 1002.39 1010.91 1016.70 1022.77 1035.09 1039.94 COMPUTATION DATE; 22-MAR-92 PAGE ARCO ALASKA, INC. 3Q - 3 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD 7" CASING TD DATE OF SURVEY: 31-JAN-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. 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I .I ,," :' i ...... , :.. ' ....... ; ............... ; ..... : t - : i [ i .: ; i ! !'";"".'"'r" "';"'r";'"; ...... ?"?..'"'~ ..... F";"';'": ..... ':'",-'+--:'---'+"+-.t-? ,-.-J--.~-+-.: ...... !-...~.-i.--.1 ...... "--:.-.i ..... i i...i. . i.: .-.:.--:-.-:.--: ..... :--..-.:--b-- ..-b.+.-.:.--.: ...... b.-h-..: ......... ~ ..................... :...:. .... L.L.i ...... r-.,-,---~ ..... HH- ::-!-: :: :" ' ..-,..-,-.....-..,.--:::i: :::: ::: ?=";'~'"'"'"'"'"""? :::i:" ::: ::: :::Lii~...i...~...~... ::: = ...... ,-.-.:.--i...i.- ::]ZZ:i::: ..~...i.-i...~ ..... :...;...:...! ...... :...;...:...: ................. "T,i'T"i ..... ~'"'~"':'"~-"i-?'F'~" "'?';'"!'"~ ..... i"TT"!'" "i'i"i-i'" : :,,...i.-:...-.?~ !~-~ r"r"r"~'" AOGCC GFOLOGICAL MATFI~IALS INVFNI'OFI¥ LIST COMPLE11ON DATE I I~ CO. CONTACT & NO. form ...... re'ccive~I received date ' comments .... , , , , _.~ ........ · iL _ , , completion repo[t 403 yes no sund~ applicallon ,, '404 yes " no .... report of sund~ applicalion ~ , , , ---6p~n --, required 're~ived .... ~,sseij- r~q~i~ti-'-~ecei-ve-~' ~rb~-~iim, requhe~- received ,,ImlC_l~g' ' ' holelog ~ , Io9 .... MUD GCf ~ ' ' ' 1EMP 'DI~sFL ' 'CNL ~~ PHoD D~L ' ' COl'' ~ "'~ PHESS BHC/SL CET ~ './" S~I~iNER .... , ,~ ~ , ,,,,, LSS PFRF HEC :SSS " PACKER - ,. '6igilai ..... Dala , , , Foe- weft CNI_ 7e~l~ FDC ~WD" rcqUi~cd' [cccivcd:~AMPL~S requi[ed ~e'ceived MWD / , , LD~/CNL' CO~ ~ ~ d~ ditcl, i ...... , , , ,,,,- / / i , ",,, , LOOK Ap~lysis ...... ..... i , , . ,, , ,~ , . . , ,,, , , , , . , ,, , , . ,, ,, .........., , , , ARCO Alaska, Inc. Date: March 27, 1992 Transmittal #: 8392 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Records Clerk ATO-111 9 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~//~'! ~// 2M-03 ~/... / > .¢'"' 3 O. 01 ~ {~1~ 3Q-04 ,~/..-/;'"'~ O/3Q-03 '"~Sub-Surface Directional I - 2 7 - 9 2 9 21 01 Survey Sub-Surface Directional 1 - 3 1 - 9 2 9 2 1 1 2 Survey Sub-Surface Directional 2 - 1 - 9 2 9 21 1 3 Survey Sub-Surface Directional 1 - 3 1 - 9 2 Survey Receipt Acknowledged: D&M 92114 RECEIVED Date' State of Alaska (2 copies) Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: February 21, 1992 Transmittal #: 8369 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 4)~;~ 3Q-03 LIS Tape and Listing 1 -27-92 92095 3 R- 1 2 D LIS Tape and Listing 2 - 4 - 9 2 9 21 1 5 THE FOLLOWING LIS TAPES ARE STAMPED WITH A CORRECTED COPY STAMP. PLEASE REPLACE THE PREVIOUS COPY THAT YOU HAVE ALREADY RECEIVED WITH THIS ONE. THANK YOU. ,?/'"-//~ I R- 1 7 ?/ -'/'~' 1 R-20 ~/_//.~ 1R-21 ~/-/o?' 1R-22 ~,/_/o/ 1R-23 ~/..-~,$ 1R-24 ,~/...-~'~. 1 R-26 ~/.../,~- 1 R-27 f,/- ?~' 1R-29 ? / ---,~/ 1R-19 ?/-/~ 2M-21 ¢/--"/~2 LM -2139 1Lo24 ¢/_?o 1 L-25 ¢'/""~¢ 1 L-26 Receipt LIS Tape and Listing 9 - 1 9 - 9 1 9 2 0 2 6 LIS Tape and Listing 9 - 9 - 9 1 9 2 0 2 6 LIS Tape and Listing 1 0 - 6 - 9 1 9 2 0 2 6 LIS Tape and Listing 9 - 2 4 - 9 1 9 2 0 2 6 LIS Tape and Listing 1 0 - 2 2 - 9 1 9 2 0 2 6 LIS Tape and Listing 7 - 3 0 - 9 1 9 2 0 2 6 LIS Tape and Listing 7 - 1 8 - 9 1 9 2 0 2 6 LIS Tape and Listing 8 - 3 1 - 9 1 9 2 0 2 6 LIS Tape and Listing 8 - 1 4 - 9 1 9 2 0 2 6 LIS Tape and Listing 6 - 1 9 - 9 1 9 2 0 2 6 LIS Tape and Listing 1 1 - 1 1 - 91 9 2 0 2 6 LIS Tape and Listing I 1 - 1 7 - 9 1 9 2 0 2 6 LIS Tape and Listing 5 - 9 - 9 1 9 2 0 2 6 LIS Tape and Listing 5 - 1 9 - 9 1 9 2 0 2 6 LIS Tape and Listing 5 - 2 6 - 9 1 9 2 0 2 6 LIS Tape and Listing 6 - 3 - 9 1 9 2 0 2 6 Acknowledged: R-EC-EtVED DISTRIBUTION: Lynn Goettinger FEB 2 8 1992 Alaska 0il & Gas Cons. Commission Anchorage State of Alaska ARCO Alaska, Inc. Date' February 13, 1992 Transmittal 8': 8361 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of lhis transmitt .~ Cement Bond Log ~ Cement Evaluation Log Cement Evaluationog ,--'" Cement Bond LOg L...~ Cement Bond Log J Cement Evaluation Log Please acknowledge receipt and 1 -31 -92 2-01 -92 2-01 -92 1 -31 -92 1 -31 -92 6395-7905 1-31-92 6690-7628 6690-7610 8585-9592 8585-9512 Receipt Drilling Acknowledge' State of Alaska(+sepia) Date' NSK 6395 RECEIVED FEB 1 4 1992 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: February 7, 1992 Transmittal #: 8355 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return o_ne signed copy of this transmittal. Please acknowledge receipt 2M-10 Litho-Density & Casing Neutron 1 1 - 2 9 - 91 7 0 0 0 - 7 7 5 6 '~ Porosity Data & 12-29-91 7 0 0 0 7 6 6 9 2 M - 1 0 Litho-Density & Casing Neutron 1 1 - 2 9 - 91 7 0 0 0 7 7 5 6 Raw Data & 12-29-91 7 0 0 0 - 7 6 6 9 3Q-04 C[]N ~' 1-12-16-92 4517.7-7720 3Q-04 CDR ,~ 1-12-16-92 4517.7-7720 f3Q-03 CDN ~ 1-24-27-92 5090-9640 '' 13''~ 3Q-03 CDR ~ 1-24-27-92 5090-9640 ..~THE FOLLOWING LOGS ARE CORRECTED COPIES. IT HAS BEEN REQUES~""""""""~~ THAT YOU THROW OUT THE PREVIOUS (UNCORRECT) COPY OF THIS LOG. ~ ~, · _THANK YOU. . _.------------ .... ?/---~ 1L-26(~¢¢-~'''C[3q 6-3-6-91 5225-10065 ~t t-' I ~'c- 2M-19~/ CCN ' -.11-17-'91 3835-9250 ~.¢t 2M-21.¢// CCN 11-1 1-91 3914-10599 -t'"' .., 1R-17'~ C2:t4 9-15-19-91 5698-10345 ~ -"~...r (..lt,.,l~7'. ~ ..,,.,j~ .,,f 1,-,-~/ C[3q 6-19-23-91 - 5390-9841 ~t,.,.~ ~, 1R.20¢ (:2;t'4 9-9-91 5568-10080 ,,~'~ 1R-21~'/, CDN 10-6-11-91 5070-10180 /\ ~ t "~¢,o")1 R- 22 "// ~ 9--24-29-91 6001-10813 ~1,+~t 1R-23 '// . CCN 10-22-91 6330-12188 _~ q,~ 1R-24,/ ~ C[~ 7-30/8-5-91 6753-12972 ~',:q>l R-26 "~/ O[::N 7-18-21-91 5591-10218 l;~'yl R-27/ CI~ / 8-31 -91 6547-9250 ~,...~ 1R-29 .--'" CCIN// 8-14-91 6042-11368 ~, 1L-25 ~ CE~ ,/ 5-26-29-91 4978-9352 / RECEIVED FEB 1 1 992 Alaska 0il & 6as Gens. 6emmission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION October 30, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 re: Kuparuk River Unit 3Q-03 ARCO Alaska, Inc. Permit No. 91-126 Sur. Loc. 2211'FNL, 2328'FEL, Sec. 17, T13N, R9E, UM Btmhole Loc. 1033'FNL, 1848'FWL, Sec. 8, T13N, R9E, UM Dear Mr. McBride: 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. The Commission will advise you of those BOPE tests .that it wishes to witness. ~Sincer , David W. ~ohnst~n, Chairman Alaska Oi nd G s Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~) printed on recycled paper b y STATE OF ALASKA ALA,.,,,,A OIL AND GAS CONSERVATION COMMIb,.,ION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill -- I lb. Type of Well Exploratory~ Stratigraphic Test -- Development Oil X Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone X Multiple Zone . 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 63'. Pad Elev.: 22' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 373301 ALK 4162 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2211' FNL, 2328' FEL, Sec. 17, T13N, RgE, UM Kuoaruk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 1310' FNL, 1895' FWL, Sec. 8, T13N, RgE, UM 3Q-03 #U630610 At total depth 9. Approximate spud date Amount 1033' FNL, 1848' FWL, Sec 8, T13N, RgE, UM 15-Nov-91 $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 3Q-02 9623' MD 1033'@ TD feet 25' at 120' MD feet 677 6678' 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 an~lle 50° Maximum sudace 2328 psig At total depth (TVD) 3500psi9 @ 6678' 18. Casing program Setting Depth size Specification Top Bottom Quantity/ of cement Hole Casin~l Weight Grade Coupling Lenc~th ND TVD ND TVD linclude stage dataI 24 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25 9.625 36.0# J-55 BTC 5305' 41' 41' 5346' 3933' 1410Sx. PF E& HF-ERW 490 Sx. Class G 8.5 7" 26.0# J-55 BTC 9582 41' 41' 9623' 6678' 170SxClassG HF-ERW Top 500' above Kuj3aruk 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 CasingconductorStructural Length Size Cemented Measured depth True Vertical depth E DRECE~V Surface Intermediate Production 0CT 1 6 991 Liner Perforation depth: measured Alaska 0il & Gas Cons. C0mmiSS[~ 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 pict __ Refraction analysis _ Seabed report _20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~~, ,~~ '~ Title Area Drillin~ Engineer Date v ! Commission Use Only · Permit Number I APl number I Approval date . I See cover letter for ~;;,,/-./'..~' 50-O~__.~ ~'-.' 2..~.-Z~., // /"~-,~'~.~ "'~/~ I other recluirements Cor~ditions of approval Samples required ~Y e s ~ N o Mud Icg required ~ Ye s.,,,~' N o Hydrogen sulfide measures __YoS~2MNO ~Directional survey required ,~Yes __No Required working pressure for BOPE __ · 3 M' ~ 5M' ~ I 0M' ~ I 5 M ~ --~ by order of Approved Commissioner the commission Date Form 10-401 Rev. 7-2~:B9~, in triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 23, 1991 Mr. L. C. Smith Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: SUBJECT: Isolation of Significant Hydrocarbon Zones Kuparuk River Field Revisions to Permits to Drill for 3Q-1,3Q-3, 3Q-4, 2M-21 This letter is to clarify the Permits to Drill for Kuparuk River Unit Wells 3Q-1,3Q-3, 3Q-4 and 2M-21. The previously submitted General Procedures for the above referenced wells did not include any mention of the possibility of encountering significant hydrocarbon zones at shallower depths than the Kuparuk. If such zones are encountered, a sufficient volume of cement will be used to provide annular fill- up to a minimum of 500' above all significant hydrocarbon zones in accordance with Rule 20 AAC 25.030. Subsequent applications for Permits to Drill will include a statement in the General Procedure referencing the isolation of any significant hydrocarbon zones above the Kuparuk. Thank you for your consideration on this matter. If ARCO can furnish any further information, contact me at 265-6575. Sincerely, Senior Drilling Engineer TAB/mac A. W. McBrid~~-c,-~ ~ S. D. Bradley E. D. Fitzpatrick 3Q Pad General Wellfile RECEIVED OCT 2 ,~ 1991 Alaska 0il & Gas Cons. Commission ;Anchorage DRILLING FLUID PROGRAM WELL 3Q-03 Spud to 9-5/8" Drill out to 8urfa, ce casing weight uo Density 9.0-10.0 9.0-9.3 PV 15-35 5-15 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-15 2-4 10 Minute Gel 15-40 4-8 APl Filtrate 1 0-1 2 8- 1 0 pH 9-10 8.5-9 % Solids 10 +/- 4- 7 Weight up 10.5 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12 Drilling Fluid System: - Tandem Brandt Shale Shakers - Triple Derrick Shale Shakers - Solids Processing System to minimize drilling waste - Mud Cleaner, Centrifuges, Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators RECEIVED OCT 1 6 199~ Alaska 0ii & Gas Cons. (;omm~ss~Ot~ Anchorage Notes' Drilling fluid practices will be in accordance with the appropriate regulations stated ir 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2328 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3Q-03 will be 3Q-02. As designed, the minimum distance between the two wells would be 25' at 120' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (>4 hrs) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 sec/qt to drill gravel beds. ARCO ALASKA Structure · Pad 5Q Well',.5 Field · Kuparuk River Unit Location · North Slope, Alaska 2reated by : jones For: T BILLINGSLEY ;)ate plotted : 17-Sep-91 :lot Reference is .3 Version #4. 3oordinates are in feet reference slot [rue Vertical Depths are reference wellhead. /pEASTMAN IJCHRISTENSEN A Baker Hughe~ TD LOCATION: J 1200 1033' FNL, 1848' FWL I I SEC. 8, T13N, RgE N 9.70 DEC W 6271' (TO TARGET) TARGET LOCATION: 1310' FNL, 1895' FWL SEC. 8, T13N, R9E TARGET 1~D=6443 TMD=g256 DEP=8271 NORTH 6181 WEST 1057 0 0 0 · ' 400 _ -6 8oo - O0 _ 1200- _ 1600- - ~ 2000- _ ~ 2400- 4000- _ 4400- - 4800- -- 5200- 6400 - RKB ELEVATION: 63' KOP '[VD=300 TMD=300 DEP:O 6.00 12.00 18.00 24.00 BUILD ,3 BEG / 100' 50.00 .56.00 42.00 B/ PERMAFROST TVD=1595 TMD=1720 DEP=504 48.00 EOC TVD=1764 TMD=1969 DEP=684 T/ UGNU SNDS'rVD=2613 TMD=3291 DEP=1697 K-lC 'P',/D=3853 TMD=5222 DEP=5178 T/ W SAK SNDS1VD=3313 TMD=4381 DEP=2533 B/ W SAK SNDSR/D=3733 TMD=5035 DEP=5055 9 5/8"CSG PTTVD=3933 TMD=554-6 DEP=3273 AVERAGE ANGLE 50.06 DEC 0 400 800 Scale 1 ' 200.00 TARGET TVD=6445 TMD=9256 DEP=6271 T/ ZONE A TVD=6499 TMD=9343 DEP=6338 '~~ B/ KUP SNDS 1VD=6550 TMD=9423 DEP=6399 TD / LOGGING PT ~/D=6678 TMD=9623 DEP=6552 I I I I I I I I t I I I r I I I I I I I I I I I I I I 1200 1600 2000 2400 2800 5200 .:3600 4000 4400 4800 5200 5600 6000 6400 Vertical Section on .350.50 azimuth with reference 0.00 N, 0.00 F from slot <-- West .... 800 4000 I I I I I I 6800 ~6400 ~6000 5600 ~5200 ~4800 4000 _ -3200 2800 ~2400 ~2000 ~1600 ~1200 800 40O 0 A Z 0 SURFACE LOCATION: 2211' FNL, 2328' FELJ SEC. 17, T13N, RgE RECEIVED OCT 1 G t99' Alaska 0il & Bas Cons. 6ommiSs'to~ Anchorage I 6800 AI~UO ALAbI~A, 1 ~ZLc. Sfruc~ · Pad 5Q ~ 51 .-3-4 Fl'eld : Kuparuk RlYer Unit Location : North Slope, Alaska -- West Scale1 · 50.00 2550 I 2500 2450" I I I I 15OO 2400 2550 2500 2250 2200 I I I I I I I I , 1300 ~ 500 2150 I I I 1700 2100 1750 - 1 800 - 1850 - 1900 1300 ~300 1100 1100 1300 37O0 195o 2000 2050 900 500 300 700 .,.......~300 ,,oo RECEIVED OCT 1 6 1991 AJaska Oil & Gas Cons. CommissiO~ Anchorage ~OO 7OO 1500 300 2100 2150 O0 2250 2500 k/ o . o , , , , . , 10. 11. 12. 13. 14. 15. 16. 17. GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD Well 3Q-03 Move in and rig up Parker 245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5346') according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole logging while drilling to total depth (9623') according to directional plan. Run and cement 7" casing. Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. R' 'CEIYED OCT 1 6 399 Alaska Oil & Gas Cons. Commissio,~ Anchorage 13 5/8" 5000 , $1 BOP STACK 7 5 4 ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WiTH HYDRAUUC 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 LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 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 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3(XX) PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 30(X) PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BO'FrOM RAMS TO 250 PSI AND 3(X)0 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 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 DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 30(X) PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR RECEIVED T 1 199:1 Gas Cons. Commission SRE 8/22/89 · JPARUK RIVER UNI 20" DIVERTER SCHEMATIC I I 3 2 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. o OCT Alaska .Oil & Gas Cons. Commissim~ Anchorage 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** DATE ['2 thru 8]' ' 3. [10 & 13] (4) Casg [14 thru 22] (5) BOPE '~.~,~' /O-/~-el [23 thru 28] (6) Other. [~27 /~b/~fj thru 31] (6) Addl ~-~ io- z~-~l I en9 i nee r i nq,: MTM /" LC S BEW// RAD geology' DWJ 0 5 6 7 8 · 9. 10. 11. 12. 13. Company YES Is permit fee attached ............................................... ~. Is well to be located in a defined pool ............................... 2~_ Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... ~ Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Lease & We 1 1 ~ ,,~,~ ,.~ ,,~..~ ~0/, ' NO REMARKS Does operator have a bond in force ................................... ~_ Is a conservation order needed ....................................... ]~ I s admi n i st rat i ve approval needed .................................... Is lease n~nber appropriate .......................................... ~ Does well have a unique n~me & n~nber ................................ ~ ~ 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic $ list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~ooo psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... 32. INITIAL GE01UNIT ON/OFF POOLCLASS STATUS AREA SHORE 0 .-.I -rz ~0 U'~ -"1 Z rev 03/29/91 jo/6.011 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. o. ORIGINAL OllGIIIAi, . * AbASK~ COMP~ING CENTER * ******************************** ***************************** PANY NAMiE : I~,'0 ALASKA, b NA~E : 3 3 bD NAM,~i : KU!~.~UK RIVER P, OROUGH t NORTH SLOPE STATE : AL~A API NUMBER : 50-0~9-22221 REFERENCE NO INC, RECEIVED FEB 2 5 1992. Naska 011 & Gas Cons. Commission ,IS Tape Verification T,ist~g ~chlumberoer Alaska Computing Center 14-FE8-1992 ORIGIN : FbIC CONTINUATION # ~ PREVIOUS RE~L : COMMENT : ARC['; ALASKA IRC., 30-3, KUPARUK RIVER, 50-029-22~2~-00 **** TAPE NEAD~R SERVICE NAME DATE : 92/02/14 ORIGIN : FL!C TAPE MA~E : 92095 CONTINUATION ~ : PREVIOUS TAPE COMmEnT : ARCO ALASKA INC., 30-3, KUPARUK RIVER, 50-029-2222~-00 PAGE: **** FILM HEADER FILE NA~E : EDIT ,001 S~vICE : FLIC VERSION : O0~A06 DATE : q~/0~/14 ~AX RFC SIZE : 10~4 FTLF TYPE : LO bAST FILE ****************************************************************************** FILE ' ARCO ALASKA IRC, KUP~RUK RIVER 50-029-2222~ ~IW PASS bWD LOG DATA THE DE~i$1TY DATA PRESENTED ON THIS LIBRARY TAPE IS FROM 'RHOB MAX' D~TA SAMPLED EVERY -.5000 FEET DATA IMCLUDEb - TOOT. FXTEMSION TYPE USED ~G8 .L~D NDS TOOL NA~E w~IbE DRILLING RESISTIVITY/GR 5090' TO 9577' wHILE DRILLING ~JEUTRON/DEN$ITY 5090' TO 9507' ,IS Tape Veriflcatlon Listing ;cblumberger .~lasKa Computing Center I~-FEB-1992 06:20 PAGE: ThBLE TYPE ! CONS CN ARCO ALASKA, INC, Company Name FN KUPhRUK RIVER Field Name WN 30-3 Well Name APIN 50-o29-22221 API Serial Number FL 2211' FNL & 2328' FWL Field Location SECT 17 Section TOW~ 13N Township RANG 9E Range COUN NORTH SLOPE County STAT ALASKA State or Province NaTI USA Nation LATI Latlt~de LONG Longitude WIT~ Witness' Name SON 548984 Service Order Number PDAT MSL Permanent datum EPD FT 0 Elevat~on o~ Perm, Da L~F D~ Lo~ ~easured From APD FT 6~.8 ~B0VE PER~ANENT DATU~ EKB FT 61,8 Elevation of Kellv Bu EDF FT 61.8 Elevation of Derrick EGL FT 22 Elevation of Ground L T~D PT 96~0, Total Depth - Driller TDL FT 9640, Total Depth - Logger BLI WT 9640. Bottom Log Interval TLI FT 509~, TOP Log Interval DFT LSND Drilling Fluid Type DFD G/C3 10,2 Drilling Fluid Densit DFP. 9 5 Drilling Fluid P~ DFV CP 5'4gg Dril!ln~ FlUid Vi$COS DFI... F] Drilling Fluid Loss ~S o~ 3.36 Resistivity of Mud Sa ~ST DEGF 72 Mud..Sample Temperatur R"FS OH~ 2~4 Resistivity of mud fi MFST DE~F 7~. Mud. Filtrate Sample T R~C$ OHM~ Resistivity of Mud Ca ~CST nE~? Mud Ca~e SamPle Tempe STF~ OEGF 72, Surface Temperature BHT DEGF ~45. Bottom Hole Temperatu ZONE ZONE IS Tame Verification Listing cblumberger Alaska Computin~ Center 14-FEB-1992 06:20 TYPE ,' ZONE TABLE TyP~ ; CURV RHOB DRHn PEF DCAI, DP~I DPOR TNP~ ATR PSR DER G~ DEFI ROS~ SS R Density - LDT Bulk Density ~elta RHO Photoelectric Factor Di~ferenttal Caliper Oensit¥ Porosity Densltv Porosity Output ~rom an application Pro,ram ?hermal Neutron Porosity Gamma Ray ** DATA FORMAT SPECIFICATION RECf']RD ** SET TYPE - 64EB ** TYPE RED~CODE V~BUE 1 66 0 2 66 0 ~ 73 56 4 66 5 66 7 65 8 68 0.5 9 65 FT 11 66 12 t3 66 0 14 65 FT 15 66 68 16 66 0 66 18 Tape Verification Listing 14-FEB-1992 06120 CblUmberqer Alaska ComDutinq Center PAGEs DEPT FT 548984 00 000 00 0 I ~ 1 4 68 0000000000 ROS~ L~D G/C3 548994 O0 000 00 0 1 1 1 4 68 0000000000 RHOB LWD G/C3 548984 00 000 00 0 I 1, 1 4 68 0000000000 D~HO LW~ G/C3 548984 00 000 00 0 I 1 1 4 68 0000000000 P~F LWD 54~994 O0 000 O0 0 1 1, I 4 68 0000000000 DCA!, LWD IN 548984 00 000 00 0 I I 1 4 68 0000000000 DPH! LWD PU 54~984, 00 000 00 0 l 1 ! 4 68 0000000000 DPO~ LWD pi,) 548984 00 000 00 0 I ! I 4 68 00O0000000 TNP~ LWD PU 548994 00 000 00 0 I 1 I 4 68 0000000000 HTR LWD O~M~ 548q~4 00 000 00 0 I 1 1 4 68 00O0000000 PSR LWD ON~M 548984 00 000 00 0 i 1 1 4 68 0000000000 DER LWD OHM~ 548984 00 000 00 0 I I t 4 68 0000000000 ROPF LWD F/HR 548984 00 000 00 0 ~ ! I 4 68 0000000000 GR LWD GAPI 54~984 00 000 00 0 1 . 1 1 4 68 0000000000 PEF,LWD -999,250 DCA :LWD 99 , 50 DPHI,bWO -99950 DPOR,LWD TNP~,SWD '-999,250 ATR,LWD -999,~50 P$R,LWD -999~-250 DER,LWD ROPF,LWD ~7,8~3. GR,LWD -999,250 D~PT. 9600,000 ROS2.LWD -999.250 RHOB.LWD -999,~50 DRHO,LWD PEF.LWD -999,250 DCAL,LWD -999 250 DPHI.LWD -999.250 DPOR,LWD TNP~.bWD -999,250 ATR.LWD -999:250 P$R,LWD -999.250 DER,LWD ROPF.LWD 20.203 GR.I, WD -999,250 DF, PT. 9500.000 ROS2 bWD 2.500 RHOB.bWD 2 500 DRHO.LWD ~E~.bWD 5,596 DCAL:LWD 0'519 DP,I ~D 0:09, D~OR.LWD TNPH,LWD -999,250 HTR. LWD 2.556 PSR:LWD ~. 764 DER,LWD ROPF_. LWD 33,3?5 OR. LWD 81. 557 DEPT. 9400.000 ROS2.LWD 2.429 RHOB,bWD 2.429 DRHO.LWD PEF LWD 4,272 DCAL,LWD 0,464 DPHI.LWD 0.134 DPOR,LWD TNP~:LWD ]1.700 ATR.LWD 7.941 PSR.LWD 7.736 DER.LWD ROPF.LWD 45,663 GR,LWD 64.~58 D~PT. g3oo.00() ROS2.5WD 2.526 RHOB,bWD 2.526 DRHO.bWD PEF.LWD 4.450 DCHb. LWD ~'056 DPHI,LWD 0,075 DPOR.I~WD TNP~ LwD 31,900 ATR.LWD 3,416 PSR.LWD 3.273 DER.LWD ROpF~LW0 39,393 GR.LWD 10~.,244 DF. PT, 9200.(')00 F~OS2.LWD ~,384 RHOO.LWD 2,384 DRHO,LWD PE~ [,Wi) 4.187 DCAL.bWD 0.743 D~HI LWD 0.161 DPOR.LWD TNP~'LWD 44.800 ATR,LWD 1 652 SR:LWD 1,765 DER,LWD '999,~50 .999,. -999'250 -999,250 -999,250 7,792 0,002 0,075 3,320 -0 014 1,717 :IS Tape Verification Listing chlumberger AlasKa Computi~ Center DEPT, 9100,000 ROg2,LWD PEF,LWD 4 217 DCAh. L.:[) TNPH. BWD 42,200 ATR. LWD ROP~,L'WD 108,412 G~'LWD DEPT, 9000.000 ROS2,bWD PEF LWD 3.819 DCAL,LWD TNP~:[,WD 39,500 ATR,LWD ROPE,LWD 160,7~5 GR.LWD DEPT. 8900,000 ROS2.LWD PEF.LWD 4,685 DCAI.,,LWD TNPM,LWD 39,900 ATR,LWD ~OPF.BWD 193.003 G'R,LWD DEPT, 8800,000 ROS2.bWD PEF.L~{D 3,439 DCAL,LWD TNP~!.SWD 39.800 AT~,bWD ROPE,LWD 267.457 G~.LWD DpEW[LWD 2,847 DCAL.LWD TNP~ LWD 37,600 ATR.LWD ROPE' LWD ~ 42. 338 GR' 5WD DEPT 8600,000 PEW'LWD 3.161 DC~ ,LWD TNPH:DWD 35,70{) ATR,LWD ROP~,LWO 197,194 DEPT. 8500,000 ROS2.LWD PEF.LWD 3 003 DCAL.LWD TNPU,LWD 34:700 ATR.LWD ROPE.LWD 206.898 GR.hWD DEPT 8300,000 ~OS2.LWD PEW:LWD 3.234 DCAI,.LWD TNP~.LWD 44.600 ATR.I,WD ROPF.LWD 258.074 G~.LWD DEPT. 8200,000 ROS2.LWD PEF.LWD 3,163 OCAI,.LWD T~'P~.LWO 44,200 ATR.LWD ROPF,t.~D 336.0Q1 CR.LWD DEPT. 8100.000 ROS2.DWD PEF,LWD 3.514 DCAt. LWD TNPt!.LWD 38.000 ATR.LWD ROPE.LWD 145,()~7 GR.LWD 14-WE~-1992 06~20 2,152 RMOB.LWD O, .99 DPEI,bWD 1,926 PSR.LWD 96,~92 2,393 RHOB.LWD 0,242 DPHI,hWD 2,748 PSR,b~D 114,248 2.475 RMOB,LWD 0,275 DPBI,LWD I 699 PSR,LWD 206:597 2,459 RMOB,B~D 0.4~1 DPHI,BWD 3,2 2 P.$R,LWQ I18,103 2,448 RHOB,bWD 0,497 DPNI,BWD 3,501 PSR,bWD 91,329 2,5~6 RMDB,hWD 0,6 2 DP~I,tWD 3,588 PSR,LWD 93,407 2,430 RHOB.LWD 0,503 DPMI,LWD 3,572 PSR,LWD 93,619 ~.395 RHOB,tWD 0,577 DPHI,LWD 3 962 PSR.LWD 78:753 2,383 RHOB.LWD 0.350 DPHI,LWD 2 839 PSR,LWD 141~434 ~,284 RHOB,LWO 0,lb8 OPHI.hWD 2,O02 PSR,LWD 122,733 ~.495 RHOB.bWD 0.290 DPHI,LWD 2.183 PSR,LWD 101.307 452 1'937 2,393 0.156 2,671 2 475 0~106 1,793 249 o:I 2 448 3.551 2,430 0.133 3.549 2.398 0.153 4.379 2.383 0.162 3.053 2,284 0,222 3.149 2.495 0.094 2.963 [)RHO LWD DPOR!LWD DER LWD DRHO,DWD DPOR,LWD DER,I,WD DRHO,L~D DPOR,LWD DER,LWD DRHO bWD DPOR:LWD DER,LWD DRHO,LWD DPOR.LWD DER,LWD DRHO,LWD DPOR,LWD DRHO.LWD DPOR.LWD DER.LWD DRHO.LWD DPOR.bWD DMR.LWD DRHO.LWD DPOR.LWD DER,LWD DRHO.LWD DPOR,LWD DER.bWD DRHO.I, WD DPOR.BWD DER.LwD PAGE: O, 001 -0,012 0,156 2,698 -0,003 '0'0!1 0,1 ' 2 3,5 4 -0, 551. . '9,02 557 ,153 ,223 -0,030 0,222 2,472 -0,030 0,094 2,559 IS Tape Verification Listing 14-FEB-1992 chlumberoer Alaska Computlno Center O6:2O PAGE: DEPT. 8000.000 ROS2.LWD 2.355 PEF.LWD 2.834 DCAL.bWD 0.243 TNPH.LWD 37,900 ATR.LWD 1,750 ROPE,LWD 1~.5,380 GR.LW9 87,790 DEPT. 7900.000 ROS2.LWD 2,383 PEF.LWD 2,70t. DCAL.L~iO 0,510 TNPH.LWD 39.500 ATR.LWD 2,029 ROP~.LWD 166,673 GR,LWD 73.713 DEDT. 7800,000 ROS2.LWD 2,399 PEF.LWD 2,943 DCAL.LWD 0,34~ TNPH,LW~ 33,200 ATR.LWD 3 435 ROPE,LWD 1~2.402 GR.LW[) 103:728 DEPT. 7700,000 RO$2,LWD 2,388 3.o2 o TNP~,EW.~ 34,300 ATR,LWD 3:492 ROPE.Lw 346.985 GR,bWD 92,607 DEPT. 7600,000 ROS2.LWD 2,436 PEF LWD 3,010 DCAL.LWD 0,312 TNpH' ROpE,L~D 37.200 ATR.LWD 2,639 .LW{] 303.658 GR.LWD 9R,556 DEPT 7500.000 ROS2 LWD 2,400 PEF'LWD 2,975 DCAL:LWD 0.382 TNP~'LWD 36,300 ATR,LWD ~ 546 ROPE:LWD 220,2~9 G~.LWD 98:608 DPPT. 7400,000 ROS2.LWD 2,400 PEF.LWD 3.194 DCAL.bWD 0,295 T~Pg LWD 34.300 ATR.LWD 2,973 ROPF:L~D 340,703 GR.LWD 90.563 DE~T. 7300.000 ROS2.LWD 2.334 PEF,[.WD 3.055 DCAL.LWD 0.140 T~P~.LWD 33 900 ATR.LWD 3,068 ROpF.L~ 4~3:29g GR.LWD 86.858 DEPT. 7200.000 ROS~,LWD 2.439 PEW.LWD 3.141 DCAL.I. WD TNDH.LWD 36.700 AT~.LWO 2.9~9 ROPF.LW~ 180.00o GR.LWD 82.893 DFPT. 71no.0oo ~OS2.~wO 2.364 PE~.!.~D 3.0oo DCAL.LWD 0.244 TNP~.I.W~ 33.200 ATR.LWD 3.126 ROPF.LwD 2o5.317 GR.bWD 85.329 OrPT 70n0.0o() ROS2.LWD 2 294 PEF.' L~vD 2'649 DCAg. LWD 0:344 TMPM,LWD 36 ~]O0 ATR.[,WD 2,915 ROPF. Lw[, 247: ~7g G~. LWD 84,228 RHOB.LWD DPNI,LWD RHOB.LWD DPHI,LWD PSR,LWD RMOB,LWD DPHI,LWD PSR,LWD RHOB.hWD DPHI,bWD PSR,LWD RHOB.LWD DPHi'bWD PER,LWD RMOB,bWD DPHI,LWO PER,bWD RHOB.LWO DP~I,~WD PSR.LWD RHOB.LWD DPHI PSR:LWD RHOB.LWD DPHI.LWD PSR.bWD RHOB.LWD DPHI.LWD PSR,LWD RHOB.LWD DPHI.bWD PER,LWD 2.355 DRHO LWD 0.179 DPORiLWD !.756 DER LWD 2.383 DRHO.LWD 0 162 DPOR.bWD 2:tll DER.LWD 2,399 DRHO,~WD 0.152 DPOR,bWD 3.334 DER.hWD O, 9 3.247 DER,LWD 2.436 DRHO,LWD 0.130 DPOR,LWD 2.743 DER.LWD 2 400 DRHO 5WD 616 DER LWD 2.400 DRHO.LWD 0.!51 DPOR,LWD 3.101 DER,LWD 2 334 DRHO.LWD OilO 3 26 DER WD 2.439 DRHO.bWD 0.128 DPO~ LWD 2.957 DER:LWD 2.364 DRHO.LWD 0.173 DPOR.LWD 3.188 DER,LWD 2.294 DRHO.LWD 0.216 DPOR.LWD 2.948 DER,LWD '0'1 9 O, 1,754 '0,012 o.[ 2 .: '0,012 0,59 3,124 '0,003 ,130 ,703 '0,0~3 -0,006 :O$3 0,002 28 0'C~43 2, 166 -0,045 936 .IS Tape VerlficatJ. on LIstinO ,cblum. Serger Alaska ComDutj. no Center DEPT. 6900.000 ROS2.LWD PEF.LWD 3.128 DCAL.LWD TNPH,LWD 37,000 ATR.LwD ROPW,LWD 180,355 GR.LWD DgPT, 6800,000 ROS2,LWD PEW LWD 2,847 DCAb,LWD TNPH' LWD 34,900 AT~. LWD RODF]LWD 381,392 GR, LWD DEPT, 6700,000 ROS2,LWD PEF.LWD 3,0~ OCAL,LWD TMP~,LMD 37.900 ATR,LWD ROPE,LWD 474,100 GR,bWD DEPT. 6600,000 RO$2.LWD PEW,LMD 3,0~7 DCAL.bwD TNP~.bwD 36,!00 ATR,bWD ROPF,LWD 509,240 GR.LWD DEDT, 65o0.000 ROS2.LWD PEF.L~D 3,088 DCAL,LWD TNPH.LWD 38,600 ATR.LWD ROP~,LWD 58~,009 GR,LWD DEPT. 6400,000 ROS2.LWD PEF,LWD 2,982 DCAL.LWD TNP~,bWD 38,000 ATR,LWD ROPW.LWD 516.1~9 GR.LWD DEPT. 6300,000 ~O$2.LWD PEF.LWD 2.462 DCAL,bWD TNpH LWD 39,500 ATR,LWD ROPF~LWD 4~8.821 GR,LWD D~PT. 6200.000 ROS2.LWD PEF LWD 3 166 DCAL.LWD TNPM!LWD 40:100 ATR.LWD 707 GR LWD ROPE LWD 423. . DEPT, 6100,000 ROS~.LWD PEF.LWD 3.005 DCAL.LWD TNP~.LWD 43.700 ATR.LWD ROPF.LWD 535.959 GR.LWD DEPT. 6000.000 ROS2.LWD PEW.bwD 2.952 DCAb. LWD T~PM.LWD 43,000 ATR.LWD ROpF.LwD 428,267 GR,I, WD DEPT. 5900.000 OS2,L" PEF.LWD 3.016 .CAL.LWD TNPH.LWD 38.500 ATR,LWD 14-FEB-1992 06:20 2,364 RHOB,LWD 0,287 DPHI.LWD 2,533 PSR.LWD 81.406 2.355 RHOB,LWD 0,185 DP~!,LWD bWD 2,879 PSR,. 87,720 2.406 RHOB,bWD 0,318 DPHI,LWD 2.828 PSR.LWD 85.300 2,333 RHOB,bWD 0,139 DPHI.bWD 3.000 P'SR.LWD 74,090 2,~41 RMOB,hWD 0, O0 DPHI,hWD 3,560 PSR,LWD 75.999 2,275 RHOB,LWD 0,025 DPMI,LWD 3.268 PSR,LWD 85,770 2,250 RHOB,LWD 0,243 DPHI,LWD 2,788 PSR.LWD 77,833 2.309 RHOB.LWD 0,~78 DP~I,SWD 3, 55 PSR.LWD 77.638 ~,329 RHOB,hWD 0,068 DPMI,LWD 2,867 PSR,bWD 70.628 2,294 RHOB.LWD 0.000 DPHI,bWD 3 090 PSR,LWD 2.282 RHOB,bWD 0.000 DPWI.LWD 3.416 PSR.LWD 92.867 PAGE{ 2!364 DRHO.L~D '0'1 3 0 173 DPOR,LWD 0, 2 677 DER,LWD 2,621 2,355 DRHO.L~D -0,0~6 0,179 D. POR.LWD 0,~79 2.940 DER.LWD 2, ~8 2.333 DRHO.bWD -0,024 0,}92 DPOR,BWD 0,192 3. 26 DER.LWD 3,079 2 34 O0 Oil~~ DRHO!LWD -0.i8~ DPOR LWD O, 3 496 DER LWD 3,5t'7 0.242 DPOR WD ~ 2.770 DER.LWD :776 2.309 DRHO.LWD -0,026 0 207 DPOR LWD 0,207 3:069 DER:LWD 3.064 2.329 DRHO.LWD -0.007 0.194 DPOR.LWD 0,294 2.934 DER.LWD 2.909 294 DRHO.LWD -0.~02 0'216 DPOR LWD 0, {6 2.282 DRHO,LWD "0,026 .223 DPOR LWD 0,223 ,371 DER:LWD 3,386 IS Tape Verification Listing chlumberger Alaska Computino Center 14-FEB-1992 O6:2O PAGE: DEPT. 5800.000 ROS2. LwI"3 PEF.LWD 2.867 DCAL.LWD TNPN. LW D ~ 1.1. O0 AIR. LWD ROPE. LW [) 668. 278 ~R. LWD DEPT. 5600,00 PEF.LWD 2.85 TN'PE,LWD 41,40 ROPE.L~D 443,31 0 ROS2.LWD 0 ATR.bWD I GR.LWD 0 ROS2.LWD DCAL,LWD 0 ATR,LWD 6 GR,LWD DEPT. 5500.00 PEF.LWD 3.00 TNpH.LWD 44..40 ROPr. LWD 51.4,28 DEPT. 5400,00 PEF,LWD 3,02 TNPH,LW9 44.20 ROPE,LW0 0 ~OS2.hWD 0 .CAL.LWD 0 ATR,LWD 2 GR,LWD DEPT. 5300.000 PE~.I,,WD 2.096 NPH.LHD 52,500 IOPF.LWD -999,250 DFPT, 5200,000 PEW.t. WP 100.000 TNP,.I..~D :.9999,25.0 ROPE.L'~O 99.250 D~PT. !!73i500 PEW LWD 999 250 TNPH;L~D 999 250 ROPF.LWD -9~9.25~ END O~ BAT,% RO$2.BWD DCAL.L~D AIR LWD GR~LWD DCAL. AIR. ROS2. DCAL. ATR, LWD LwD LWD LWD [,WI.) LWD LWD 2,332 0,1.56 2.205 86,452 2,313 0,129 2,296 74.539 . 0, 3, 75, 2, O. O. 81. 0. 2, 79. 232 058 498 394 616 569 235 000 864 220 1,938 1,660 3.068 ~7.506 . 0. '999. '999. -999. -999, -999. -999. 43! 654 250 25O 50 5O 250 250 RHOB,LWD DPH!.LWD PSR.LWD RHOB.LWD DPHI,LWD PSR.LWD RHOB.GWD DPH!,LWD PSR.LWD RHOB,LWD DPMI.LWD PSR,GWD RHOB,hWD DPHI,LWD PSR.LWD RHOB.LWD DPHI,hWD PSR,LWD RHOB.LWD PSR.LWD RHOB,LWD DPHI,LWD PSR.LWD 2 332 2.455 2.313 0.204 2.721 2 .232 0i254 3,483 2.311 0.205 1.378 2,235 0,251 2.:680 !,938 0,431 3.057 2.431 0!132 -999 250 -999.250 -999.250 -999.250 DRHO LWD DPOR!LWD DRHO,LWD DPOR,LWD DER.LWD DRHO.LWD DPOR,LWD DER.I, WD DRHO,LWD DPOR,bWD DER.LWD DRHO.LWD DPOR.LWD DER.LWD DRHO LWD DPOR:LWD DER.LWD DRHO.LWD DPOR.LWD DER.LWD DRHO.LWD DPOR.LWD DER.LWD .o'oos 2 ~ 349 0,008 0,204 2,529 '0,:023 488 ~0,007 0,~05 0, 79 '0 o:lll 2,741 -0.288 O, -999, -999,250 -999,250 -999,2~0 **** FILE TRAILER FILE NA~E : EDIT .001 SERVICE : FLTC VFRSIO,~ : O01A06 DATE : 02/02/14 ~X RFC SIZE : 1024 FILE TYPE : LO LAST FILE .IS Tape Verlflcation List~mq .chlumberger Alaska Comput~..nq Center 14-FEB-1992 06:20 ***$ TAPE TRAILER S~RVlCE NA~E : EDIT DATe : 92/02/14 O~I~IN : FLIC TAPF NA~E : 92095 CONTINi~ATION # : pREVIO~3S TAPE : CO~ENT : ARCO ALASKA INC., 30-3, KUPARUK RIVER, ~ REEL TRAILER *~* SERVICE NAME : EDIT DATF : 92102114 RFEL NA~E : 9~095 CONTINUATION # : P~EVIOUS REEb CO~EWT : ARCO ALASKA INC., ]0-3, KUPARUK RIVER, 50-029-2222~-00
