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189-108
• STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑✓ • Suspended❑ 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑✓ WAG❑ WDSPL❑ No.of Completions: Service ❑✓ Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 3/13/2017 189-108/316-560 • 3.Address: 7.Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 10/24/1989 50-103-20117-00 • 4a.Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 194'FNL,94'FEL,Sec 11,T1ON,R8E, UM 11/2/1989 KRU 2K-18 • Top of Productive Interval: 9. Ref Elevations: KB: 154 17. Field/Pool(s): 1467'FSL,949'FWL,Sec 12,T1ON,R8E, UM GL: BF: Kuparuk River Field/Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1191'FSL, 1036'FWL,Sec 12,T1ON, R8E, UM 7918/6550 ADL 25588 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 498311 y- 5938110 Zone- 4 7960/6582 ALK 2674 TPI: x- 499355 y- 5934491 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 499442 y- 5934215 Zone- 4 1808/1768 1400/1397 5.Directional or Inclination Survey: Yes ❑(attached) No Q 13.Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary N/A RECEIVED AFP 2 F.Z017 APR 0 7 2017 AOGCC 23. CASING,LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 62.5 H-40 Surface 115' Surface 115' 24" 170 sx AS II 10" 36 J-55 Surface 3359' Surface 2970' 12-1/4" 1100 sx AS II,450 sx Class G 7" 26 J-55 Surface 7463' Surface 7463' 8-1/2" 250 sx Class G 5-3/4" 18 L-80 7121 7134 5922 5932 6" 5" 18 L-80 7134 7918 5932 6550 6" 157 sx Class G 24.Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5 7143 7094/5900 Perforations Plugged: 7504-7515 MD 6225-6233 TVD, "010f'Lr i ,',..m: 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. 7566-7576 MD 6274-6282 TVD, %='C, !3)0, Was hydraulic fracturing used during completion? Yes ❑ No E7602-7642 MD 6302-6334 TVD 1." 1 Per 20 AAC 25.283(i)(2)attach electronic and printed information VERUFIEr DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED TOC=7125 KB 21.8 bbl Class G(liner,perfs,tubing) TOC IA=565'KB 207 bbl Class G(tubing x IA) TOC tubing=1600 KB TOC ©Surface 60 bbl Permafrost cement(tubing, IA,OA) 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A PLUGGED OFF Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period — Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate — Form 10-407 Revised 11/ 015 CONTINUE ON PAGE 2 Submit ORIGINIAL only Ci, 913 yiz �— VTI- 4141-// - , p.b . RBDMS \,.IAPR - 7 2017 28.CORE'DATA Conventional Cot: Yes ❑ No Q Sidewall Cores:es ❑ No ❑., If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Yes ❑ No ❑✓ Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1400' 1394' Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval N/A N/A information,including reports,per 20 AAC 25.071. Formation at total depth: 31. List of Attachments: Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true 0.nd re to th est of my knowledge. Contact: Jill Simek @ 263-4131 Email: Jill.Simek©conocophillips.com Printed Name: G.L.Alvord Title: Alaska Drilling Manager - Signature: . . � Phone: 265-6120 Date: 4'(6(toy? INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item lb: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and ND for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only . • • SUNDRY NOTICE 10-407 ConocoPhillips Well 2K-18 Plug and Abandonment April 5, 2017 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 2K-18, commencing operations on November 11, 2016 and completing the Plug and Abandonment on March 13, 2017. Operations involved pumping 21.8 bbls of Class "G" cement in the 5" liner, across the Kuparuk perforations, and up into the 3-1/2"tubing. Top of Cement(TOC) was tagged at 7,125' KB. Tubing was then punched at 7,062' - 7,066' KB and 207 bbls of Class "G" cement was pumped down the tubing and up the tubing x production casing annulus (IA). TOC in the tubing was tagged at 1,600' KB and a cement bond log indicated TOC in the IA to be at 565' KB. Tubing was punched at 548' - 553' KB and 60 bbls of Permafrost cement was pumped down the tubing and up the IA and the production casing x surface casing annulus (OA) with returns to surface. The well was then excavated and wellhead and cellar removed. The State Inspector determined that cement was in good condition and the well was capped and excavation backfilled. Pictures below show cement to surface in all annuli, marker plate installed, and final site condition after backfill. The fieldWell Service Report is attached. t,:w ,r - ,iviti;.,.2.4,..iicir .*0741., , - - .-,-,-. +F 44 Y Nt I 2K-18 18� `10:' t, 4 "Co q ,4. . x._. This photdgr. t , 4' �. AOGCC with pe , r• ' own use. Copy ' - rM . » purpose or by a '' x.. .ir` 3 , �•-«i prohibited wits �.�p consent of }''` *►. sr'.i,." S 0 - s., mol :_ . .' •,•,-,,,,, • - 3,... ,iitimpro I.:.:'...: 4•*'-'4''''' ' „4, , t 1 - ' • sgrmtiteserVed. " opyitight . -..„..., ___T - ,,,. ' t ,... ......- -"Or likt: This photika• Is P mig. - '" ",,,„ ''''" -. i T. TuN its owri cottiFF , -,.,,, .., purpose or by,ony.iglettarbi is,''.-- ' t ,:-.: V.., _„. . j- P471 1 b ititi-'il'nOtliti 4.4"...AASIr. ''' ..' ' ' -Alt° -.4 1, consentOf CtitilkipPtniPaAlwr,...."' l'. ',,.:*' t.t. ''-„.„ •y ' '`...".'",, •*".. .. . ' .q.. ,.. , .,.. . -", ...i. , ,, . • :,, I',, , , - 4, .,. „ i _ - (.•... , .c.:-, il f K 1 I , '''•: - - -*"''* ..'' - • ,,, ,.. , „ ..,. -, 4i,1,,,- , kt„, Ale it,-,..'t ••'-,...- •-------,71 it t,-- ' - '• • '1 , s -,,. '.,--f','; -••'i' - - ,,,,'„. / ' 4 4 ,,,,:,,, , A ., . 1...,A,..1. ,,A..... . ,,,,,,..., •. ,,, -. .. . .,..,,t,-- -...t ... , f • yr- . • ° ',,t. ' 'A'. * ' :it` ' ' • . 4 ,,At, , l'''' 'Ai. • ' 9.1111163111 1331111111614 „„_ _ - \ *-- , W ell.ow-.,est.lb i MI IP, ,- -.. ' - - — - / - - i illiarl-''""Mantii I':' ,i i'' . , • 2K-18 P&A Work Summary Start Date Last 24hr Sum 3/13/2017 (P&A)WELD CAP ON CONDUCTOR,REMOVE EXCAVATION EQUIPMENT(COMPLETE) 3/11/2017 (P&A):CUT&REMOVE WELLHEAD. 3/8/2017 P&A EXCAVATED TO 15'.SET SHORING. 3/7/2017 (P&A):CUT STANDING PLATE OFF WELLHEAD. EXCAVATE TO 13'(IN PROGRESS). 3/5/2017 (SEC)BLEED T/I/0 TO 0 PSI FOR P&A(COMPLETE) 3/4/2017 (SEC):P&A PREP,BLED ALL ANNULI TO 0 PSI. (SEC)P&A PREP-PLACE ALL ANNULI ON OPEN BLEED.UNABLE TO REMOVE IA VR PLUG FOR TOC.REMOVE TREE AND INSTALL BLIND 2/21/2017 FLANGE 2/19/2017 (SEC)P&A PREP-T DDT(PASS),IA DDT(PASS),OA DDT(PASS).T TOC 9'4"OA TOC 8'6"IN PROGRESS 2/18/2017 (SEC)T,IA,OA DDT AGAINST CEMENT IN PROGRESS. 2/17/2017 (SEC):P&A PREP-T DDT(IN PROGRESS),IA DDT(IN PROGRESS),OA DDT(IN PROGRESS). 2/16/2017 (SEC)P&A PREP,CYCLE ALL CASING VALVES TO VERIFY NO CEMENT IN VALVES,ALL OK,T,IA,OA DDT AGAINST CEMENT IN PROGRESS. 2/14/2017 PUMPED 60 BBLS 15.7 HES PERMAFROST CEMENT DOWN TUBING,GOOD CMT RTNS TO SURFACE AT 0/A AND I/A.READY FOR DHD. SHOOT SQUEEZE GUN OVER INTERVAL:548-553FT RKB CCL TO TOP SHOT=3.3FT,1SPF,5FT LOAD,0 DEG PHASING,POWERFLOW 2006 CHARGES,0.45IN ENT.HOLE SIZE LRS PERFORM CIRCULATION TEST: INITIAL PRESSURES T/I/0=0/0/0 PSI PUMP DOWN TUBING TAKING RETURNS FROM IA,T/I/0=350/350/400PSI AT 1BPM,8BBLS DIESEL TOTAL PUMP DOWN TUBING TAKING RETURNS FROM OA,T/I/0=1400/1350/600P51 AT 1BPM,8BBLS DIESEL TOTAL 2/1/2017 MIRU. RIH W/SCMT.TAGGED TOP OF CEMENT AT 1600'. PERFORM MAIN PASS OVER INTERVAL 1600'-SURFACE. PERFORM REPEAT 1/22/2017 PASS FROM 900'-300'. TOP OF CEMENT AT 565'.POOH TAGGED TOC @ 1582'SLM. PERFORM PASSING MIT-T TO 1500 PSI.&PERFORM PASSING DDT.E-LINE UP NEXT FOR TBG PUNCH,IN 1/18/2017 PROGRESS. DRIFT 2"COIL WITH 1.375"BALL,PERFORM WEEKLY BOP TEST,RIH AND PUMP 152 BBLS OF 15.8 CLASS G HES CEMENT INTO IA,LAY 55 BBLS 15.8 PPG CLASS G HES CEMENT IN THE TUBING. CLEAN OUT DOWN TO 1150'FREEZE PROTECT ON WAY OUT OF HOLE.READY FOR 1/15/2017 SLICKLINE TAG IN 24-48 HRS.(JOB IN PROGRESS) TAG TOC @ 7125.4FT RKB,PERFORM CORRELATION PASS,CORRELATE TO PKR AT 7093.7FT RKB SHOOT PUNCHER OVER INTERVAL:7062-7066FT RKB CCL TO TOP SHOT=4.3FT,4SPF,0 DEG,4FT LOAD,CHARGE 1606S,0.301N HOLE SIZE LRS PERFORM INJECTIVITY TEST: INITIALT/IA/0=50/80/60 PUMP DOWN TBG @ 2BPM TAKING RETURNS TO FLOW BACK TANK FROM IA AT 3BBLS PUMPED=500/80/60 AT 10BBLS PUMPED=150/80/60 AT 20BBLS PUMPED=275/120/60 1/12/2017 RETURNS SEEN AT FLOWBACK TANK. 1/7/2017 (MISC):T,IA&OA DDT TO 0 PSI(PASSED). (GUY COOK STATE WITNESS)TAG CEMENT(HARD TAG)W/2.5"BAILER @ 7087'SLM/7107'RKB(OBTAIN SAMPLE OF CEMENT); CMIT TBG X IA(PASS/6 BBLS PUMPED); RE-TAG CEMENT @ SAME(OBTAINED SAMPLE W/NO MARKS ON BAILER BOTTOM). DRAW DOWN TBG X IA DOWN TO 200 PSI AND SUSPEND DDT DUE TO WEATHER(RECOVERED 9 BBLS FROM TBG&1 BBLS FROM IA). TURN OVER TO 1/4/2017 DHD. P&A CEMENT PLUG 1:CORRELATE DEPTH AT PIPE FLAG FROM PREVIOUS JOB AT XN-NIPPLE,7110'RKB. RIH AND SET CEMENT RETAINER WITH MID-ELEMENT AT 7126'RKB. CONDUCT INJECTIVITY TEST,THEN PUMP 21.8 BBL 15.8#CLASS G CEMENT WITH FRESHWATER SPACERS. UN-STING FROM RETAINER WITH 20.8 BBL BELOW,LAY IN LAST 1 BBL ON TOP OF RETAINER. CIRCULATE 20 BBL POWERVIS TO 1/1/2017 CLEAN COIL AND TUBING AND POOH,FREEZE PROTECT COIL AND WELL. READY FOR SLICKLINE TAG,JOB IN PROGRESS. CONDUCT WEEKLY BOPE TEST. RIH WITH 2.80"NOZZLE TO CORRELATE FOR CEMENT RETAINER. TAG 2.75"XN-NIPPLE AT 7060'CTMD (7110'RKB)AND FLAG PIPE. POOH,MAKE UP WEATHERFORD BHA AND CEMENT RETAINER. WEATHER PHASE 1 AND WORSENING--WILL 12/30/2016 RETURN FOR CEMENTING,JOB IN PROGRESS. RIH WITH 2.80"NOZZLE TO TAG 2.75"XN NIPPLE AT 7110'RKB AND FLAG CT FOR DEPTH CORRELATION.POOH.PINHOLE IN CT STRING AT 710'WHILE PUH.CONTINUE POOH.SI SWAB.BLEED OFF CT AND WHP.CALL FOR N2.PURGE CT WITH N2 TO FLOWBACK TANK.RDMO 12/10/2016 RETURNING TO PRUDHOE TO SPOOL OFF STRING#34356.INCOMPLETE JOB. 11/12/2016 RAN 2.75"X 15'DMY CEMENT RETAINER DRIFT TO 7126'RKB. READY FOR CTU 11/11/2016 PULLED 2.81"XXN PLUG @ 7110'RKB. IN PROGRESS. KUP I 2K-18 Conoco Phillips Well Attribut Max Angle TD Alaska,It ll:. Wellbore API/UWI Field Name Wellbore Status 'nal Cl MD(ftKB) Act Btm(ftKB) conocoNlillips 501032011700 KUPARUK RIVER UNIT INJ 42.28 2,500.00 7,960.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2K-18,4/5/20173-.06.59 PM SSSV:Flapper Locked Out Last WO: 39.99 11/3/1989 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date uuaaubalaurtral corp 1;0 0-.--•..•-.--,••--•- •-•••••••••Lest Tag:SLM 7,768.0 7/31/2014 Rev Reason:P&A WELL pproven 3/30/2017 Casing Sings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 51.0 130.0 130.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WVLen(I...Grade Top Thread -A-A.CONDUCTOR;51.0-130.0 SURFACE 95/8 8.921 51.0 3,371.7 2,9804 36.00 J-55 BTC Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 51.0 7,481.3 6,206.8 26.00 J-55 BTC APERF;516.0-553.0-e Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(TVD)... Wt/Len(I...Grade Top Thread CEMENT;51.0RK8 , , - LINER TOP 53/4 5.250 7,121.1 7,134.0 5,931.9 Liner Details Cement Plug-Tubing;51.0 ftKB Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com No(^nal ID 7,121.1 5,921.7 37.88 TIEBACK •BAKER 5"TIEBACK SLEEVE(NEW TOL) 5.250 7,128.4 5,927.5 37.84 PACKER BAKER BOT LINER TIEBACK PACKER(3.08' 4.250 SAFETY VLV;1923.4 SEALS&1'HALF MULESHOE BELOW PACKER STUNG INTO OLD TIEBACK SLEEVE) Casing Description 100(in) IID(in) -Top(ftKB) ISet Depth(ftKB) 'Set Depth(ND)...I WtlLen(I...I Grade Top Thread GAS LIFT;2,548.1 LINER BTM 5 4.276 7,134.0 7,918.2 6,549.7 18.001L-80 LTC Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl CI Item Des Corn (in) 7,134.0 5,931.9 37.81 TIEBACK BAKER BOT 5"TIEBACK SLEEVE 5.250 7,141.3 5,937.7 37.78 HANGER BAKER BOT HYFLO II LINER HANGER 5.000 SURFACE;51.0-3,371.7 v"�h1 Tubing Strings =..� Tubing DescriptionString Ma... ID(in) Top(ftKB) Set Depth ..Set Depth ITVD)(...Wt(16/ft) Grade Top Connection GAS LIFT;4,569.6 TUBING Description ' 31/21 2.9921 51 .01 (tt 7,158.81 5,951. 51 9.301 J-55 I EUE-MOD ;. Completion Details ( 1°":\ Nominal ID GAS LIFT;5,951.0 Top(ftKB) Top(TVD)(ftKB) Top Mel(°) Item Des Com (in) 1,823.4 1,781.8 30.07 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE(FLAPPER 2.812 LOCKED OUT 4/15/93) 7,095.7 5,901.7 37.98 PBR BAKER 80-40 PBR w/10'STROKE w/4"SEAL BORE 3.000 GAS LIFT;6,843.4 7,109.4 5,912.5 37.93 PACKER BAKER HB RETRIEVABLE PACKER 2.890 7,125.7 5,925.3 37.85 NIPPLE OTIS 2.813"XN NIPPLE 2.75"NO GO 2.750 7,158.2 5,951.1 37.69 WLEG TUBING w/MULE SHOE/WIRELINE GUIDE CUT ON 3.000 BOTTOM Perforations&Slots GAS LIFT;7,050.9 Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (78(B) (ftKB) Zone Date ft) Type Com APERF;7,082.0-7,066.0-....___- 548.0 553.0 548.0 553.0 Puncher,2K- 2/1/2017 1.0 APERF Perfs of P&A-CEMENT Cement Plug;565.0 RKB 1 18 JOB Cement Plug;1,600.0 RKB 7,062.0 7,066.0 5,875.1 5,878.3 Puncher,2K- 1/12/2017 4.0 APERF Perrs of P&A-CEMENT ' 'N 18 JOB PBR,70857 7,504.0 7,515.0 6,224.7 6,233.4 C-4,UNIT B, 5/26/1997 6.0 APERF 60 deg.Phasing;2.5" PACKER;7,109.4 "' 2K-18 HSD DP • 7,566.0 7,576.0 6,273.7 6,281.6 A-5,2K-18 5/26/1997 6.0 APERF 60 deg.Phasing;2.5" HSD DP 7,602.0 7,642.0 6,302.3 6,334.0 A-4,2K-18 4/26/1990 4.0 IPERF 180 deg.Phasing'3 3/8" HLS Casing Gun NIPPLE;7,125.7 ill Cement Squeezes ";„n,. l Top(TVD) Btm(TVD) Ili Top(ftKB) Btm(IBB) (ftKB) (ftKB) Des Start Date Corn 7,504.0 7,742.0 6,224.7 6,412.7 Cement 1/1/2017 Plug 1: Pumped 21.8 bbl 15.89 class G to isolate LINER TOP;7,121.1-7,134.0Irw' I Squeeze perforations.TOC tagged at 7125.46 RKB Ix 'I 7,158.2 7,742.0 5,951.0 6,412.7 Cement Plug- 1/1/2017 Plug 1: Pumped 21.8 bbl 15.88 class G to isolate TUBING;7,126.9 Tubing perofrations.TOC tagged at 7125.46 RKB 7,125.4 7,158.2 5,925.1 5,951.0 Cement Plug- 1/1/2017 Plug 1: Pumped 21.8 bbl 15.8#class G to isolate Liner perforations.TOC tagged at 7125.4ft RKB Cement Plug;7,125.418(5 565.0 7,066.0 565.0 5,878.3 Cement Plug-IA 1/15/2017 Plug 2: PUMP 152 BBLS OF 15.8 CLASS G HES - WLEG;7,158.2 CEMENT INTO IA,LAY 55 BBLS 15.8 PPG CLASS G HES CEMENT IN THE TUBING. 1,600.0 7,066.0 1,582.2 5,878.3 Cement Plug- 1/15/2017 Plug 2: PUMP 152 BBLS OF 15.8 CLASS G HES Tubing CEMENT INTO IA,LAY 55 BBLS 15.8 PPG CLASS G HES CEMENT IN THE TUBING. 51.0 1,600.0 51.0 1,582.2 Cement Plug- 3/2/2017 PLUG 3: PUMPED 60 BBLS 15.7 HES Tubing PERMAFROST CEMENT DOWN TUBING,GOOD PRODUCTION;51.47,481.3 - CMT RTNS TO SURFACE AT 0/A AND I/A 51.0 553.0 51.0 553.0 Cement Plug-IA 3/2/2017 PLUG 3: PUMPED 60 BBLS 15.7 HES &OA PERMAFROST CEMENT DOWN TUBING,GOOD APERF;7,wb.o-7sls.o Y.: % CMT RTNS TO SURFACE AT 0/A AND I/A /.: rt Mandrel Inserts 4' % st k kl all on Top(TVD) Valve Latch Port Size TRO Run APERF;7,588.0-7,576.0iri, Top(ftKB) (ftKB) Make Model OD(in) Seen Type Type (in) (psi) Run Date Corn Z 1 2,546.1 2,349.3 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/17/1994 IPERF;7,602.0-7,642.0 % 2 4,669.6 3,996.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/16/1994 Cement Squeeze;7,504.011KB * 3 5,951.0 5,006.3 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/16/1994 4 6,643.4 5,547.0 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/16/1994 Cement Plug;7,158.2 ftKB ' Notes:General&Safety End Date Annotation 8/30/2009 NOTE:HES LDL CONFIRMED LEAK @ 1154'MD(COLLAR) 11/4/2010 NOTE:View Schematic w/Alaska Schematic9.0 3/7/2017 NOTE:CUT STANDING PLATE OFF WELLHEAD. EXCAVATE TO 13'(IN PROGRESS). 3/11/2017 NOTE:CUT&REMOVE WELLHEAD. 3/14/2017 NOTE:WELD CAP ON CONDUCTOR,REMOVE EXCAVATION EQUIPMENT(COMPLETE) LINER BTM,7.134.0-7.9162 • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg / 5751(7 DATE: 3/17/17 P. I. Supervisor FROM: Bob Noble SUBJECT: Location Inspection Petroleum Inspector KRU 2K-18 ConocoPhillips Alaska PTD # 189-108 3/16/17: I received a notification from CPA rep Roger Winters for a location clearance inspection including verification of well cut off that they had done on KRU 2K-18. I gave Roger a call and went over the details of his location clearance and told him I would be out on 3/17/17 to take a look. 3/17/17: I traveled to KRU 2K-18 on 3/17/17 to inspect the location. The well was in the middle of 2K pad and had already been cut off and buried. There was about a 3 feet mound of good clean gravel over the well. I did not see any sign of trash or oil soaked gravel. Everything looked to have been well done. Summary: I performed a final abandonment/location inspection of the KRU 2K-18 well. The drillsite has active wells so this would not be the final location clearance inspection. Attachments: Photo as r `rte-•-�is ,� n,aF Vie*r, '. :. +46."+,. 2017-0317_Location_KRU2K-18_bn.docx Page 1 of 1 SCANNED SEP 1 52017, • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg -1.<Q11 1'4 0 DATE: 3/13/17 P. I. Supervisor FROM:Adam Earl SUBJECT: Surface Abandonment Petroleum Inspector Conoco/Phillips KRU 2K-18 PTD 189-108 Monday, March 13, 2017: Today I went out to KRU 2K pad to inspect a surface abandonment on well 2K-18. Conductor, both casing strings, and tubing string appeared to be full of set up, hard, cement. They were cut flush and looked to me to be around five feet below tundra grade. Attachments: Photo SCANNED SEP 1 8 201; o A • w , * ;$ °. .4 r • l p lit w ''rti s r" , , i ...::, ,.it . _ „ r ? y ,.r r i kit 73r- fi 2017-0313 Surface AbandonKRU_2K-13_ae.docx Page 1 of 1 40 1-1 • • 0 (5- a) t r � � , pe- l- l- l- l- N CO X • co � LL U p oj E n O ai c7 o Z o V- 'Q (O Q r j l O N 4ra O yO 0) IIIo a` a v C 0 W co C RI L Y 75 < It a r r r r r r wco O O 6 -j J N a 4 Q _6 _6 0 E - ate..+ -, F d wow 4 N LL LL C S C LL LL LL LL LL C co c) -c a) trl Vi N M W 01 r '4. O a'' u C an Z U "a ns p u Q) > E \p CD 0000000 C i N J J J J J J J dA C 4- U O W W W W W W W ,I Cl.) ,."."• LL LL LL LL LL LL LL +-, a) a) a) -0 O Q J J J J J J J O' _o > c N tO f Q Q Q Q Q Q Q a) N C a- 0 Z Z Z Z Z Z Z U 0 CD a) a) 0 C • LL LL LL LL LL LL LL cc ^ Q C > .. O CD 0 CD n3 C CD O ' w a v u > C O OA -a3 4- m I. f. 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M f W � aaaaaa r , > > > > > > is u C �./ Y Y Y Y Y Y 0.0ta N UcCx in 00o00o E W o C� 0 000000 V 0 000000 m v Y Y Ii ti LL Li. c W ro LL LL p p O p w 0 0 0 D 0 p c N u S 0 0 0 0 0 0 o 0 0 0 0 oOD d' to m v) r r ch •v E ` T e- to N O Im C) t0 N 0 U O O O 0 0 M • N N N N N N N 'Q 0 f`•) f`•) O M 8 • RO O N O N N N 01 O - O O 7 L. 00 0 0 0 0 +' 0 N e. t() LO to to Q U C Ci3 L to V (C C) YI C C To 0 3 a • _ CU d Q CO N It N O c0 7 ,— Y E 61 ~ ,!, Z «1 co a aH to rn X Y m Z v co Q N J M M N N N ti, y �i z I L L4.4 C 10 n O CO3 ala F`- a a < Loepp, Victoria T (DOA) From: Schwartz, Guy L(DOA) Sent: Monday,January 23, 2017 3:25 PM To: Simek,Jill Cc: Loepp,Victoria T(DOA) Subject: RE:2K-18 P&A (Sundry#316-560) Follow Up Flag: Follow up Flag Status: Flagged Jill, As you mention the IA and tubing pressure tested OK after the second cement plug. The cement is indeed higher than expected in the IA and can be clearly seen at around 650 ft. and . The changes proposed to the sundry are approved as detailed below. A couple barrels of diesel will be left in the tubing but will be trapped between cement plugs and will pose no environment issue in the long term. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC SCANNED A/A1: 2 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Simek,Jill [mailto:Jill.Simek@conocophillips.comj Sent: Monday,January 23,2017 3:17 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Subject:2K-18 P&A(Sundry#316-560) Guy, During P&A operations at 2K-18, Plug#2 was tagged in the tubing at 1,582ft RKB and the bond log(attached)showed top of cement in the IA at approximately 565ft RKB. Planned top of cement was 1,200ft in both tubing and IA. Mechanical Integrity Test of tubing(1500psi)and the drawdown tests of tubing and IA all passed. Due to discrepancies in planned and actual top of cement,ConocoPhillips proposes to change the perforating depth from 1,200ft RKB to approximately 500ft RKB in the tubing and production casing. This will be followed by placement of the surface cement plug(plug#3) in tubing, IA,and OA from perforation depth to surface. The plan would leave a column of diesel in the tubing from approximately 1,582ft RKB(TOC plug#2)to 500ft RKB(bottom of plug#3). Please let me know if this plan is acceptable. Thank you, 1 • Jill Simek • ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1854, Anchorage, AK 99501 Phone: 907-263-4131 I Cell: 907-980-7503 2 / I I I I• I 1 • • n. �y/ L l' ~ T 0 6. pry � r � .- a X >• N 3 w 500 i J°�U-/ pq +� f0 T (D O J s O C r r r r (0 F+ CA Y v 0- t.)u a` no a3 � y +� c a = c LLI (0 N T Q < O E a 6 m J• QF, U 0 OS CO CO CO E 4-, L 'O O N < F ,� C C C C ,_ -p +-, s- N W +� L z Q r r r O v \ U Z 0 a) n, i v - 0 O U 0 0 0 0 pCp L. 41) O p "*� W J J J J ° "" U n W_ W W W 'I v .. E 4- F LL LL LL LL a > _c 73 (.01- Q Q Q Q a) vi c i G O) Q Z Z Z_ Z a) _c aa)i ° N Q O; LL LL LL LL CC — J C > (0 > C aJ u o Cr' E v > oz c a o oA u 4.7 m _ U ftl .. w , O E Y 'U c R O Q , a. ~ C ((o a 0 0 u ct Q CD a sn c a u a LL rn 2 a. L O w ca C p G ix 3 m 4t 0) O Jwa b y m V F \ �' Jv. d m U (--.4 W c� VA CD W 0 > W Cr* y 0 0 eq 00 a 0 i 7 s z W O "" tot '54 Loo u aa.. J> J >J J 4 co 10 c,:, 2 3 3 > g zap v, vl z P cc re cc rc IA W W W W W > > > > z • Y Y Y > > > > VI ® ,i- a a as a a 03 LUY• YYY pp0 U X (J = N ( , ILI M E V 0 0 0 ti Q o 0 0 o d O O O C W W r r u '> z co 2 2 E 0 a c Q W 0 0 0 0 a W —s g ., u Y o 0 coCr 53 0 co 0 +' rz o Q 0 0 0 0 a (o r r N . a Y r r In c co r' O co C N p, N N N N w •• L g. Q O T M O> O ao ERN N O NRI 0 01 O O e' O M O ou 4c tila c Co U'El • U CD ERE d O° z '- as g a C Y C a p J N N rte.. v z 0 0 0 pp r..-. 3 f6 cE E .. ` ~ ~OC/aoQ - it aa • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Friday,January 06,2017 P.I.Supervisor k(26.- ICY( 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-18 FROM: Guy Cook KUPARUK RIV UNIT 2K-18 Petroleum Inspector Src: #Error Reviewed Byrr P.I.Supry �!��`— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-18 API Well Number 50-103-20117-00-00 Inspector Name: Guy Cook Permit Number: 189-108-0 Inspection Date: 1/4/2017 Insp Num: mitGDCl70105091020 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2K-18 ' 1Type Inj N .1TVD 5900 Tubing 330 1570 ' 1540 1530 I- 1525 " PTD 1891080 Type Test SPT Test psi 1500 - IA 400 1570 1550 . 1545 : 1540 Interval OTHER PAF P OA 380 420 - 430 430 - 430 . Notes: CMIT-TIA to 1500 psi for a P&A. Diesel was pumped for this test.Sundry 316-560.No corresponding operator report required. SCOApp052�� . S Friday,January 06,2017 Page 1 of 1 u • PTQ /8q—/ Loepp, Victoria T (DOA) From: Senden, R.Tyler <R.Tyler.Senden@conocophillips.com> Sent: Thursday,January 05,2017 10:51 AM To: Loepp,Victoria T(DOA) Subject: RE:2K-18 Follow Up Flag: Follow up Flag Status: Flagged Thank You! Thanks, Ty Senden Director,Well Integrity and Interventions MED npp ti t Conocophillips Alaska, Inc. C' ���� ATO-1396 907-265-1544(o) 907-982-3996(C) r.tyler.senden@cop.com From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday,January 05, 2017 10:50 AM To:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: [EXTERNAL]RE: 2K-18 Tyler, Approval is granted to proceed;the cement tag and passing MIT are acceptable for this bottom plug. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppna alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loem@alaska.gov From:Senden, R.Tyler[mailto:R.Tyler.Senden@conocophillips.com] Sent:Thursday,January 05, 2017 10:46 AM 1 • To: Loepp,Victoria T(DOA)<victori .loepp@alaska.gov> Subject:2K-18 Victoria, We've heard verbally from Guy Cook that the tag and MIT of the first plug were approved by you and that we have approval to proceed with the remainder of the procedure. Can you confirm that the cement tag and MIT meet your criteria and that we have approval to proceed? Thanks, Ty Senden Director,Well Integrity and Interventions Conocophillips Alaska, Inc. ATO-1396 907-265-1544(o) 907-982-3996(C) r.tyler.senden@cop.com 2 MEMORANDUM State of Paska Alaska Oil and Gas Conservation Commission TO: Jim Regg {il bIDATE: January 4, 2017 P.I. Supervisor � 7 SUBJECT: Well Bore Plug &Abandonment KRU 2K-18 FROM: Guy Cook ConocoPhillips Alaska Inc. Petroleum Inspector Kuparuk River Field - PTD 1891080; Sundry 316-560 Section: 11 Township: 10N Range: 8E Meridian: Umiat Drilling Rig: Rig Elevation: 154 ft Total Depth: 7960 ft Lease No.: ADL25588 Operator Rep: Eddie Zemba Casing/Tubing Data: Casing Removal: Conductor: 16" - O.D. Shoe@ 79 - Feet Casing Cut@ Feet Surface: 10" - O.D. Shoe@ 3359 • Feet Casing Cut@ Feet Intermediate: O.D. Shoe@ Feet Casing Cut@ Feet Production: 7" O.D. Shoe@ 7430 Feet Casing Cut@ Feet Liner: 5 3/4" - O.D. Shoe@ 7918 Feet Casing Cut@ Feet Tubing: 3.5" O.D. Tail@ 7143 Feet Casing Cut@ Feet Plugging Data: Type Pluq Founded on Bottom of T.O.C. Depth T.O.C. Mud Weight Pressure (bottom up) Cement Verified? above plug Test Perforation Retainer - 7126' • 7107' Wireline Tag - 15.8 - 1500 PSI Type Pluq Founded on: Verified? Open Hole Bottom Drillpipe tag Perforation Bridge plug Wireline tag Annulus Balanced C.T.Tag SCANNED Casing Stub Retainer No Surface Cement was tagged twice, once before and once after the passing CMIT-TxIA test(refer to Inspection Report# mitGDC170105091020). Both tags were at the same footage of 7107 ft,while the tag depth in approved Sundry 316- 560 was proposed at 7011 ft. This gives 19 ft of cement on top of the retainer at 7126 ft. I spoke with AOGCC Engineer Victoria Loepp about this and since the procedure calls for them to punch holes in the tubing and cement again, she was okay with them proceeding on with the P&A as scheduled. cc: Attachments: none rev. 2-25-14 2017-0104_Plug_Verification_KR U_2 K-18_gc.xlsx 1/6/2017 of jj,8� THE STATE Alaska Oil and Gas F �� OfALAVKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek Staff Well Integrity Engineer SCANNED FEB 2 12017, ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-18 Permit to Drill Number: 189-108 Sundry Number: 316-560 Dear Ms. Simek: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, AP9c,Laz-,_ Cathy '. Foerster Chair DATED this ZN d y of November, 2016. RBDMS V-10y - 2 2016 RECEIVED STATE OF ALASKA NU V 0 1 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION /71Z, 44 w.C APPLICATION FOR SUNDRY APPROVALS J 20 AAC 25.280 1.Type of Request: Abandon F Plug Perforations I— Fracture Stimulate E Repair Well E Operations Shutdown E Suspend Perforate E Other Stimulate 1 Pull Tubing r Change Approved Program 1— Plug for Redrill I— Perforate New Pool E Re-enter Susp Well E Alter Casing E Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory 1 Development E 189-108` 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service ` 501032011700 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? none Will planned perforations require a spacing exception? Yes r NoF / KRU 2K-18 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25588 Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,960' 6,582' 7787 6425 3634 psi 7110 none Casing Length Size MD ND Burst Collapse Structural Conductor 79' 16" 115' 115' Surface 3,324' 10" 3,359' 2,970' Production 7,430' 7" 7,463' 7,463' Liner 797' 5 3/4 7,918' 6,550' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7504-7515,7566-7576, i6225-6233,6274-6282, 3.500" J-55 7,143' 7602-7642 6302-6334 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER-BAKER HB RETRIEVABLE PACKER MD=7094 TVD=5900 SAFETY VLV-CAMCO TRDP-1A-SSA SAFETY VALVE(FLAPPER LOCKED MD=1808 TVD=1768 12.Attachments: Proposal Summary 2 Wellbore schematic 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory r Stratigraphic Development ifl Service F/ 14.Estimated Date for 11/8/2016 15.Well Status after proposed work: ,,h Commencing Operations: OIL E WINJ WDSPL E Suspended E 16.Verbal Approval: Date: GAS E WAG I `, GSTOR E SPLUG E Commission Representative: GINJ Op Shutdown E Abandoned 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Jill Simek @ 263-4131 Email JilI.Simekc cop.com Printed Name Jill Simek Title Staff Well Integrity Engineer IL /0/7///t. Signature 76 Phone 263-4131 Dae COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: / k— (P b Plug Integrity W BOP Test Mechanical Integrity Test 0 Location Clearance ❑ Other: 1 P144-2› c ,-,---h"--'"•• 6 "ci'3 r., c k-j-_le 4- Loe- p Y T ( Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes ❑ No T// Subsequent Form Required: [V—y v RBDMS t,V PuV - 2 2016 APPROVED BY Approved by:(P, / 9244,7 COMMISSIONER THE COMMISSION Date: 'Ply l !Fy ^ /�-2 -/ ��aiN,A- Submit Form and Form 10-403 Re sed 11/2015 p e � � alid for 1 mon s from the date of approval. � �' �l'Z'/Attachments in Duplicate • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 26 October 2016 Commissioner, State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to Plug and Abandon Kuparuk Injector 2K-18(PTD#: 189-108). 2K-18 was originally drilled and completed in 1989 as a pre- produced injector. The well operated as an injector from April, 1991 to August,2009 when injection was ceased due to tubing leaks. Since then,repair has been deemed uneconomical and the well remains shut-in. The 2K-24 CTD project plans to replace the 2K-18 injection support in that area.Furthermore, a grassroots well is planned at 2K, to utilize the 2K-18 location and reuse flowlines, wellhouse and other facilities. Without any future utility and a need to recover the 2K-18 location,a P&A of the well is recommended. The well has 9-5/8" surface casing to 3,359.2' KB and 7"production casing to 7,463.3' KB, and a 5" liner from 7,134' to 7,918.2' KB. There is 3-1/2"tubing with a packer at 7,093.8' KB. Three sets of Kuparuk perforations are at 7,602.0-7,642.0' KB,7,566.0-7,576.0' KB,and 7,504.0-7,515.0'KB. Per this procedure, P&A operations will be performed with coiled tubing to set a cement retainer at approximately 7,126' KB and cement pumped into the 5" liner, across the Kuparuk perforations, and up into the 3-1/2" tubing tail. Cement will also be placed above the retainer in the tubing to an approximate depth of 7,011' KB. Holes will then be punched in the tubing, above Plug #1 Top of Cement (TOC) at approximately 6,980' KB. Coiled tubing will place cement in the tubing and tubing x production casing annulus (IA), with TOC of Plug #2 calculated to be 1,200' KB. Tubing will be punched above Plug #2 TOC and a third cement plug will be pumped fullbore, to bring cement to surface in the tubing, IA, and production casing x surface casing annulus (OA). The well will then be excavated 4 feet Belo ,, original ground level,wellhead and cellar removed,and site backfilled with gravel/fill to ground level. If you have any questions or require any further information,please contact me at 263-4131. tA'b Sincerely, j 1 <65 1 Jill .imek W- 1 Integrity Engineer 01''AI Drilling and Wells • ConocoPhillips 2K-18 P&A Permit to Drill #: 189-108 P&A operations will be performed with coiled tubing to set a cement retainer at approximately 7,126' KB and cement pumped into the 5" liner, across the Kuparuk perforations, and up into the 3-1/2" tubing tail. Cement will also be placed above the retainer in the tubing to an approximate depth of 7,011' KB. Holes will then be punched in the tubing, above Plug #1 Top of Cement (TOC) at approximately 6,980' KB. Coiled tubing will place cement in the tubing and tubing x production casing annulus (IA), with TOC of Plug #2 calculated to be 1,200' KB. Tubing will be punched above Plug #2 TOC and a third cement plug will be pumped fullbore, to bring cement to surface in the tubing, IA, and production casing x surface casing annulus (OA). Surface excavation for removal of wellhead and final P&A operations will follow. Proposed P&A: Slickline: Objective: Pull plug, drift for cement retainer 1. Inspect pad and work area for Hazards. Complete Pre Job Safety Meeting. RU Slickline unit and support equipment. PT lubricator and surface lines as required. 2. Pull plug from nipple at 7,110' KB. 3. RIH with 2.75" x 15' dummy mechanical cement retainer tool string, down to 7,126' KB (middle of full joint in tubing tail). 4. RDMO. Coiled Tubing /Cementing: Objective: Plug #1 - Place a cement plug across the open perforations and squeeze some cement into perforations. NOTE: Maximum pressure, volume and rate for squeeze to be discussed and agreed with client representative at site prior to starting cement job, based on injectivity test results. Cement Volume Calculations (TOC in tubing to be at approximately 7,011' KB): • 5" Liner volume from 100ft below perforations to tubing tail = (7742' —7143') x 0.01776 = 10.6 bbl • 3-1/2 tubing volume from tubing tail to cement retainer= (7143' —7,126') x 0.008696 bbl/ft = 0.2 bbl • 3-1/2" tubing volume from cement retainer to TOC = (7,126' — 7,011') x 0.008696 bbl/ft = 1.0 bbl • Squeeze volume = 10 bbl • Total volume: 10.6 + 0.2 + 1.0 + 10 = 21.8 bbl JS • • 1. Ensure an approved sundry has been received from AOGCC. 2. Contact Halliburton a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Wesley Miller/ Ed Jans 907 670-5827). The job is designed for 21.8 bbls of 15.8# Class "G" cement. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. RU Coil Tubing Unit and PT Surface Equipment as required. 5. Reference 8/3/2014 schematic and tubing details for depth correlation. Perform tie-in/pipe flag run to ensure cement retainer is set at desired depth. 6. RIH with Weatherford 2.75" cement retainer, taking returns up the CT x Tubing annulus. Do not pump while RIH. . /7. Set cement retainer at approximately 7,126'KB (middle of full tubing joint in tubing iu tail), or as deep as the retainer will safely &Wt. 8. Close in the CT x Tubing annulus, and line up to pump down the coil tubing. 9. Pump 30 bbls of diesel through the retainer to verify proper set and injectivity required for cementing operations (+/- 2 bpm at 2,000psi). 10. RU HAL Cement Equipment and PT surface lines as required. 11. Pump 10 bbls fresh water spacer 12. Pump 10.8 bbls of Class "G" cement + 10 bbls excess, if formation drinks. If squeeze pressure is seen before pumping total cement volume, unsting from retainer and begin next step. 13. Shut down, un-sting from retainer 14. Lay in remaining 1.0 bbl cemeI - .e - - -'ner(equates to - 115' of cement above the retainer, leavi-• OC 7,011' KB) 15. POOH above TOC 16. Circulate CTU clean. 17. RDMO Slickline/ Little Red Objective: State witnessed tag of TOC, CMIT-TxIA, DDT-TxIA 1. WOC per UCA data (minimum 24 hours). Notify the AOGCC Inspector of the timingof the cement plugtag. 9 2. Conduct SafetyMeetingand IdentifyHazards. Inspect wellhead and pad condition to identify any p9 re-existin conditions. 3. RU Slickline and PT Equipment as required. 4. RIH and tag TOC @ approximately 7,011' KB. Record Results. TAG MUST BE AOGCC WITNESSED- I-4) Jo, 5. RU LRS and PT Surface Equipment as required. 1 6. Perform CMIT-TxIA to 1,500 psi. Record Results. P -c)-- 7. Perform DDT-TxIA. Record Results. 8. Report issues and results to Well Integrity Engineer. 9. RDMO JS • Eline/ Little Red: Objective: Punch tubing, injectivity test 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU E-Line and PT Equipment as required. 3. RIH with 2" x 4' tubing punch, 4 spf; reference 8/3/2014 schematic and tubing details for depth correlation. 4. Punch approximately 30' above TOC or as close to mid joint as possible. '= 7o 9 5. Pump 20 bbls diesel through tubing holes to ensure adequate rate for cementing (+/- 2 bpm <= 2,000psi). 6. If 2 bpm circ. rate is not achievable, RIH with a second tubing punch and punch holes 32' above the previous holes. 7. RDMO. Coiled Tubing /Cementing: Objective: Plug #2 - Fill the wellbore with cement from tubing punch (-6,980' KB) to approximately 1,200' KB. We will be circulating cement down the 3 '/2" tubing and up the 3 1/2" x 7" annulus. Cement Volume Calculations (TOC approximately 1,200' in tubing and annulus): • Volume in 3 'h" x 7" annulus: (6,980' - 1,200') x 0.02636 bbl/ft = 152.4 bbl • • Volume inside 3 'h' tubing: (6,980' - 1,200') x 0.008696 bbl/ft = 50.3 bbl • Total volume: 152.4 + 50.3 = 202.7 bbl 1. Contact Halliburton a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Wesley Miller/ Ed Jans 907 670-5827). The job is designed for 202.7 bbls of 15.8#Class "G" cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU Coil Tubing Unit and PT Surface Equipment as required. 4. RU HAL Cement Equipment and PT surface lines as required. 5. Reference 8/3/2014 schematic and tubing details for depth correlation. 6. Take returns to coiled tubing x 3-1/2" annulus. RIH to tubing punch holes (-6,98C0 KB). /2-4," • a`--' 7. Close coiled tubing x 3-1/2" annulus. Take returns to 3-1/2" x 7" annulus (IA) with • coil nozzle above tubing punch holes. Pump 152.4 bbls Class "G". TOC in IA should be at 1,200' KB. 8. Close IA. Take returns to coiled tubing x 3-1/2" annulus. Let 50- 100' of cement go behind pipe (-0.3 bbl). Then pump and pull 50.3 bbls to 1,100' KB (100' above planned TOC). 9. Contaminate cement to 1,200' MD and circulate out excess. 10. RDMO. JS • Slickline/ Little Red Objective: Tag TOC, CMIT-TxIA, DDT-TxIA 1. WOC for 48 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU Slickline and PT Equipment as required. 4. RIH and tag TOC @ approximately 1,200' KB. Record results and report tag depth to Well Integrity Engineer. 5. RU LRS and PT Surface Equipment as required. 6. Perform CMIT-TxIA to 1,500 psi. Record results. 7. Perform DDT on Tubing and IA. Record results. 8. Report issues & results to Well Integrity Engineer. 9. RDMO E-line/ Little Red Objective: Punch 31/2" tubing and 7" production casing to establish circulation for surface cement plug. 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU a-line and PT Equipment as required. 3. RIH with dual-string perforating gun, referencing 8/3/2014 schematic and tubing details for depth correlation. 4. Punch 30' above TOC, as close to mid joint as possible. 5. Pump 8 bbls diesel through tubing holes to ensure adequate rate for cementing (+/- 2 bpm <= 2,000psi). Ensure circulation to both IA and OA. 6. If 2 bpm circ. rate is not achievable, RIH with a second tubing punch and punch holes 32' above the previous holes. 7. RDMO Pumping Services: Objective: Plug #3 - Fill the wellbore with cement from punch depth (-1,200' MD) to surface. We will be circulating cement down the 31/2" tubing and up the 9 5/8" x 7" annulus as well as up the 7" x 3 '/2" annulus. Cement Volume Calculations: • Volume in 3 'h" x 7" annulus: (1200'-0') x 0.02636 bbl/ft= 31.6 bbl • Volume in 7" x 9 5/8" annulus: (1200'-0') x 0.02971 bbl/ft = 35.7 bbl • Volume inside 3 1/2' tubing: (1200'-0') x 0.008696 bbl/ft =10.4 bbl JS • • • Excess: 20 bbl • Total volume: 31.6 + 35.7 + 10.4 + 20 = 97.7 bbl 1. Contact Halliburton a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Wesley Miller/ Ed Jans 907 670-5827). The job is designed for 97.7 bbls of Permafrost Cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU HAL Cement Equipment and PT surface lines as required. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from both the 7" x 9 5/8" (OA) and 3 '/z" x 7" (IA) annuli independently. Also ensure that there is a way to pump down the IA or OA in case the tubing pressures up. Rig up line to flush all surface lines of cement post-job. 4. Close the OA, open the IA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the IA to confirm circulation. 5. Close the IA, open the OA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the OA to confirm circulation. 6. After circulation to IA and OA is confirmed, batch up Permafrost Cement. 7. Line up to pump cement down the tubing, taking returns from the OA. 8. Follow Pump Schedule below: i. 5 bbls fresh water spacer ahead ii. 97.7 bbl of Permafrost Cement (cement to surface in T/I/O, including 20 bbls excess) 9. After approximately 46.1 bbls of cement is pumped away, expect to see OA cement returns. Utilize mud balance to confirm good Permafrost Cement to surface coming from the OA. Pump contingency cement if needed to obtain good cement to surface. 10. With good OA cement to surface, open the IA, close the OA, and line up to take IA returns to tanks. This step must be performed efficiently as Permafrost Cement is thixotropic and will develop gel strength quickly when static. 11. After approximately 31.6 bbls of cement is pumped away, expect to see IA cement returns. Utilize mud balance to confirm good Permafrost Cement to surface coming from the OA. Pump contingency cement if needed to obtain good cement to surface. 12.After good OA and IA cement is seen at surface, shut down pumps and close in the IA and OA valves. 13. Close in the master valve, open up the cement clean up line, and circulate to tanks to wash up tree and surface equipment. 14. RDMO DHD: Objective: DDT 1. WOC for 48 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. RU DHD and PT equipment. JS • 3. Perform drawdown test on tubing, IA, and OA. Wellhead Excavation / Final P&A: 1. Remove the Well House (if still installed). 2. Bleed off T/I/O to ensure all pressure is bled off the system. 3. Remove the production tree, in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. 6. Perform Top Job and verify that cement is at surface in all strings. AOGCC witness and photo document required. 7. Send the casing head w/stub to materials shop. Photo document. 8. Weld 1/4" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Drill 1/8" weep hole in the cover plate. Photo document. AOGCC Witness Required. ConocoPhillips 2K-18 PTD#: 189-108 API #: 50-103-20117-00 9. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo document final location condition after all work is completed. '1(4 JS 1110 • P&A Diagram: 2K-18 Plug & Abandonment PTD#: 189-108 Current Completion Proposed P&A n F geni AI; L Third Pkig(T,IA,&OA)1,200'KB-Surface Permafrost Cement 16"62.5#H-40 Conductor @ 115'KB , 8)seettAry0 4440.0. 841001001. Tubing Leak-1,154'KB „ Second Plug(T&IA)6,980'KB-1,200'KB A. ' 15.8ppgClass"G" SSSV @ 1,807.8'KB — \\N,:'"\ \ GLM: GLV @ 2,530.5'KB '"a kist40.: i*V.A.T.,, W.\11, Al hi, 9 518"36#3-55 Surface Casing @ 3,3592 KB WitgatiA :**%!:„ GLM'. "Ali DMY G.4,654.5 4,654.04KB DMY @ 5,935.3'KB DMY @ 6,627.8'KB DMY @ 7,0352 KB 77,7r. *Cs's\k i „As,: /0 First Plug(Perforations,Liner,&Tubing) 7,742'-7.011'KB fr,,f0 15.8 ppg Class"G" Baker HB Retrievable Packer @ 7,093.8'KB yo., f� 2.81"XXN PLUG ve 2.75"NO-GO it OTIS XN il �jfr Nipple @ 7.110.0'K8 4"9.3#J55 Tubing G 7,143.1'KB 'gym . i'" ,, Cement Retainer Set @ 7,126'KB 35 ;11‘,„ 7"26#J35 Production Casing @ 7,463.3'KB , Parts: 7,504.0-7,515.0'KB a 7,566.0-7,576.0'KB -=,,,,,, ,.,.... � 76020-7,6420'KB ✓' //' 11111. 5"18#L-80 Liner @ 7,918 2'KB J5 10-26-2016 Js • • Wellbore Schematic: ""` . KUP INJ 2K-18 ConocoPhillips F Weil Attitmtes Max Angle a MO ID 24.09,-.0,10,,, W04001,AW'llM 01,40lien a Yteetcre Samet i *0 5X8 44 7#5 iAUP) 50.1532015700 9.2FA cJM RI✓5R.:07 W,'. 2,E.:C;3 7.060.0 ••• Commit 122 lm 5 Dab Pmotatten Ena CAS 5)803101*5 F10 Assam Ole :17:.ts,v22,,et1112.2,ens SSW:F35051 LOCOS OW 'W3', :3.99 11!311969 Ans.efitARMMz+}1»,; :.Aflee4tien DMln itR) Sod Oak, Mxatanan ted Mea 05 0134 MS _355130 3:07 7,759 F '731'x314 Rev Reason.TAG,053E7 PLUG 3¢4110 &'37514 I'T �1: i Casing Skimps Coln OoowO.Oco CO fa:) 10 aat 7410 tRIA61 eat Devet RIM EA Daps ITA35...001205 0...erase Tap RAW III :2)200:30•:Pt 16 55.052 30.0 'i s C 1 i3.0 62,50?10.40 WELDED OBIS wo) ,lex i:awzux mxe4e.usr.aui-4. a, Calntf 000050.550. 01310.77 04Fop(10[30 1001 Daum 3.35 Ed Depth,970 15dA.36O02-5de TapThead SURFACE :5s6 5,925 330 3 59:: 290.5 3E:30 w55 BTC 01301,5 Datw1p*00 CO RS MON Top t is OSDIn 10104 Sat Capps•7019)...MA.0. 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Yoe ThreadJWE,6154 4.27E 7.134.5 7.511 3.2 5,5097 16.00 4-SO _.t 4000,01.+Tnpa r Details Norma/10 Tee{N{D1 Top CND;Rt1R0 Tap es,5) Mem Deo Can 051 7'34. 0.9319 37 51 1IE9000 5555505673 T1E5ACK60_EEVE 3253 2" 0 927.7 _7.76 HANGER E4.Yf00.7T '1 r:JAE55 MAJ5G55 0 200 Tubing Strings 100 0e005{31 11105*MM..ID Ant 18/0011,81 Oat 0005516 tet 3etdinC,504{1,'t/Md Uo0W rap Canna. 0,450A ESa-ss5nr-. 5152,._ 312 2592 3'2 ?.143' 1,53_11 0.33.-65 2Lk'-uOU Completion Detail 4 0'JI'?015.0 Tq eRdBI Tan(TOM011r0 Teearo F) Wnrlw Can 00(.Ont 51010 4 312 312 0 11 1ANGER PAC 13V2112 TING HANGER 3.5015 0A1,07 504.0. 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F' g. ,54,.1010' '4.0401-0.160 9 6 an 5 IOW Mks 000 LAMPat Sitz TRC fon Tapra85 ks 0050. 010ISO I'm 7000 M) OM Ram Drs Eo, Il lel :3A2, 5 2,337.7 VERLA TNPS AS LIST av,e 9K0 500 OO 517:1944 MBA 3,0105 1, i 2 24554.0 3,9644 LERLA T9J525 1 GAS LIFT 35.7.7 Ed 0595 0.0 5/1611994 3 5:935.3 4,994.0 11ERLA 7I.P0 0 t,ASLWFT 527(7 90 LI 3.0)5' 0.0 5.16.'1994 4 6.,527.9 5,534'5 05515500 916114.2 1 112 GAS LIFT 3117 RA 0500 0.0 3316:1994 Vilotaw Lien*A)8l E$ASKOI deed Due Amelabn 8.30:2909 NGTE'RED 121E COO59015E3 LEAK 0 1154'610tC,OJAR) 111442010 NOTE tow sote.reste:A78153 Sene0nai119.0 405U5 11271,14022709 5 5519414 1 344 44 315. 4P0RF 1,5654.7S71 , 94Ri_'AO 04ftrO ,.5458*00,3,11104424 Js 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 RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS' Scanned by: Bevedy Rren~athan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd 2K-18 (PTD 189-108) Report of ~d MITIA Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Thursday, March 18, 2010 4:26 PM To: Maunder, Thomas E (DOA) Cc: Brooks, Phoebe L (DOA) Subject: RE: 2K-18 (PTD 189-108) Report of failed MITIA Attachments: MIT KRU 2K-18 08-08-09 .xls Tom, • Page 1 of 2 Attached is the test data for the MITT and the CMIT TxIA performed on 08!08!09. Please let me know if you have any questions. Brent RogerslMartin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, March 18, 2010 2:55 PM To: NSK Problem Well Supv Subject: FW: 2K-18 (PTD 189-108) Report of failed MITIA Sorry, wrong address. From: Maunder, Thomas E (DOA) Sent: Thursday, March 18, 2010 2:51 PM To: 'NSK Well Integrity Proj' Subject: FW: 2K-18 (PTD 189-108) Report of failed MITIA Brent and Martin, I am looking at the AA request for 2K-18. This is the last piece of information I show having been sent on the well. There are a number of activities noted as taking place in August 2009. The caliper report is in our well file, but I don't find any of the other information. While the MITT and CMIT were for diagnostics, were they witnessed and was a MIT report submitted? Thanks in advance, Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Tuesday, July 14, 2009 2:36 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Schwartz, Guy L (DOA); NSK Problem Well Supv Subject: 2K-18 (PTD 189-108) Report of failed MITIA 3/19/2010 2K-18 (PTD 189-108) Report of ~d MITIA • Page 2 of 2 Jim, Kuparuk injector 2K-18 (PTD 189-108) failed a diagnostic MITIA on 07/13/09 following a report of frequent IA bleeds. The well has been shut in and freeze protected, and has been added to the monthly report. The TIO prior to the test was 2900/2740/310. It is ConocoPhillips intention to troubleshoot the failed MITIA and repair if possible. The appropriate paperwork will be submitted following the work and a plan forward is developed. Attached is a schematic and a 90 day TIO plot. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Welts Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 «2K-18 schematic.pdf» «2K-18 90 day TIO plot.jpg» 3/19!2010 i • KRU ConocoPhillips Alaska, Inc. 2K-18 A_PI: 501032011700 Well_Type:INJ SSSV Type: LOCKED OUT Orig Completion: I, 11/3/1989 _ iFLAPPER_ SSSV (1808-1809, Annular Fluid: Last W/O: OD:3.5o0) _ Reference Log:.,, ., Ref Log Date: ,^^^4 ^ Gas Lift 3ndrel/Dummy Valve 1 (2530-2531, OD:5.620) Gas Lift andrel/Dummy Valve 2 (4654-4655, OD:5.620) Gas Lift 3ndrel/Dummy Valve 3 (5935-5936, OD:5.620) Gas Lift 3ndrellDummy Valve 4 (6628-6629, OD:5.793) Gas Lift 3ndrel/Dummy Valve 5 (7035-7036, OD:5.793) PBR (7080-7081, OD:3.500) PKR (7094-7095, OD:6.151) NIP (7110-7111, OD:3.500) TUBING (0-7143, OD:3.500, ID:2.992) TTL (7143-7144, OD:3.500) Perf (7504-7515) LINER (7121-7918, OD:S.OOQ W 1:18.00) Perf (7566-7576) - 7642 6302 - 6334 A-4 4 2K-18 Angle @ TD:39 deg @ 7960 Gun Vlv 7110 5913 NIP 'Otis 'XN' Ni le NO GO 2.750 7128 5927 PACKER ,BROWN JM TIEBACK PACKER 4.250 __ 7143 ~ 5939 TTL Muleshoe 2.992 Perf (7602-7642) TIIIO Plot - 2K-18 3aoo 25oa 2aoo ... ........................................................................,~.,.................... ,~f..J........1 ... .. ....... i ~ ~' a 1500 1000 200 150 Q 100 0 s U 50 500 0 ~-++++ 14-Apr-09 27-Apr-09 1o-May-09 23-May-09 o5-Jun-09 18-Jun-09 01-Jul-09 Date 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Conoco Phillips Alaska Inc. Kuparuk /KRU / 2K 08/08/09 Phillips / Hurley -AES Packer Depth Pretest Initial 15 Min. 30 Min. Well 2K-18 Type Inj. W TVD 5,900' Tubing 1,950 3,000 2,850 2,825 Interval O P.T.D. 189-108 Type test P Test psi 1500 Casin 1,800 1,920 1,960 1,975 P/F P Notes: Diagnostic MITT OA 150 150 150 150 45 MIN T/110=2825/1975//150 Well 2K-18 Type Inj. W TVD 5,900' Tubin 1,950 3,000 3,000 3,000 Interval O P.T.D. 189-108 Type test P Test psi 1500 Casin 1,800 3,000 3,000 3,000 P/F P Notes: Diagnostic CMIT T x IA. OA 150 150 150 150 Well Type In~. TVD Tubin Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Wate r TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year CyGe V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27;07 MIT KRU 2K-18 08-08-09 .xls LJ ~~~ L T~A~1~'TA ~t, PrtoACrive D'~nyNOSnc Seevic.~s, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907J 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing lnspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 j Leak Detection - WLD 24 Aug-09 2) Replacement Disk With Corrected API # 2 K-1 S 19 0~~"( ~~ J Signed : 'C ~~ ~" \4~~ Print Name: EDE 50-1 03-201 1 7-00 J Date : - - '. PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ,~, - - - -- - . _ _ wEBSITE '~'.; , C:Documents and Se[tings~Diane Williams',Desk~op`?Tzansmit_Cenocodocx D • ~ WE`LL LC~fa TRA1V`4'~/TTAL ,,. PeoAcrive Dinc~nosric SeRVicES, tnc_ To: ACIGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Explaration (Alaskaj, Inc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and Urt~ 7~~-1b`6 I~~-/5 / ~6L~-b3~ 1 c~/s~ ProActive Diagnostic Services, Inc. Attn: Robert l4. Richey 130 Westi International Airport Road ~~ 7=,. x;_. ~Q~~ Suite C .~;~~'~~~~'°` !~~~~ Anchorage, AK 99518 Fax (907) 245-8952 1) Caliper Report 1&Aug-09 2K 18 2) Caliper Repor~ 20 Aug-09 2P-443 Signed : Pririt Name: 1 Report / EDE 50-1 Q3-20 1 1 7-00 ~ 1 Report .~-`~~ ~7-00 s:s ,~UG 2 ~ 2009 Date : ~~:~~~ ~il ~ Gas Car~s. ~os~ ` °i~~ ~nchnra~e PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCNORAGE, AK 99618 PMONE: (907)245-8851 FAX: (907)24$-88952 E-Ma~~ : pdsanchoraaeta~memorvloa.com WEBSITE : www.memorvlog.com ~ C:~Documents ana setmngs~ow,iet~Desktop~l}ansmit_sr.aocx ' ' I ' ~ i ~ • • Memory Mu1t~Finger Ce[iper Lc~g Resu~lts 5ummar~ Company: ConocoPhillips Ataska, Inc. 1Net1: 2K-18 Log Date: August 18, 2009 Field: Kuparuk Log No. : 10585 Sfate: Alaska Run No.: 1 API No.: 5Q-103-201'17-00 ', Pipe1 Qesc.: 3.5" 9.3 Ib. J-55 EUE-MOD Top Log Irrtvl: SurFace ' Pipe1 Use: Tubing Bot. Log Intvl: 7,144 Ft. (MD) ^ Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: ~ Thls caliper data is tied into the bottom of the tubing tail ~ 7,143' (Driller's Depth). ' This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing is in good to poor cflndition. Walt penetrations from 20°~ to 73°~ are recorded from ~650' to ~1,800'. Recorded damage appears in the forms of shallow, scattereci pitting, lin~s vf pits and line corrosion, occasionally broadening into areas of general corrosion. No significant ' areas of cross-seetional wall loss are recarded. Although the caliper recordings indicate scattered deposits throughout the tubing, no significant I.p. restrictions are reeorded. The caliper recordings indicate siight corkscrewed tubing. '~' A 3-D log plot of the caliper recordings across the Nnes of pits and line corrosion from 650' to 1,800' is included in this report. MAXIMUM RECORDED WALL PENETRATIONS : Line Corrasion ( 73%) Jt. 28 @ 922 Ft. (MD) Corrosion ( 61°10) Jt. 29 @ 960 Ft. (MD) Corrosion ( 52°~) Jt. 26 ~ 866 Ft. (MD) Line of Pits ( 494~0} Jt. 27 ~ 902 Ft. (MD} Line Cortosion ( 49%) Jt. 30 @ 992 Ft. (MDj MAXIMUM RECORDED CROSS-SECTIUNAL METAL LOSS : No significant areas of cross-sectional wall loss (> 8°~) are recorded. MAXIMUM RECORDED ID RESTRICTiONS : No significarrt I.D. restrictions are recorded. ~, ~, ~.~.; ~' , , ; ., ~ ~ '' y ' ~ `..~ ,. ~ . '~ !:~:i~:'; Field Engineer. G. Ethertan Analyst: M. Lawrrence Witness: C, Fitzpafrick ProActive Diagnastic Services, Inc. / P.O. Box 1369, Staffc~rd, Tx 77497 Phane: (281) or (888) 565-9085 Fax: (281} 565~1369 E-mail: PDStamemorylog.com Prudhae Bay Field Office Phone: {907) 659-230? Fax: (9d"?) 659-2314 (.~_ c~ L 1~`~ -~ l~~ ~~~~~/ ' • • PDS Multifinger Caliper 3D Log Plot ~ ~_._.~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2K-18 Date : August 18, 2009 ' Description : Detail of Caliper Recordings Across Lines of Pits and Line Corrosion Image Map 90° 180° 270° 0• . ' • • ~ • • • Correlation of Recorded Damage to Borehole Profile ~ Pipe 1 3.5 in (37.4' - 7142.9') Well: 2K-18 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: August 18, 2009 ^ Approx. Too) D eviaUon ^ A pprox. Boreho le Profil e 43 816 1625 GLM 1 2455 ~ 3254 ~ u_ C .C 4033 v 0 GI_M 2 4850 5651 GLM 3 6457 GLM 4 GLM 5 218.1 7143 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 218.1 1 25 50 v 100 ~ ~ 7 Z ~ •0 125 ~ 150 175 200 • • PDS Report Overview ~ ~F Body Region Analysis Well: 2K-18 Survey Date: August 18, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 A~a st: M.I.awrence Tubing: Nom.OD Weight Grade & Thread Nom.l[) Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f -55 FUE MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (9'o wall) ~ penetration body ~ metal loss body 200 150 100 50 ~ 0 to 1 to 10 to 1°io 10°/ ZO% 20 to 40 to over ~10% 85% 85% Number of'oints anal se d rotal = 227 pene loss . 57 66 70 174 53 0 20 14 0 0 0 0 Damage Configuretion ( body ) 60 40 ZO 0 isolated general hnv ring holc / poss pitting corrosion mrrosion corrovon ible hole Number of ~oints dama ed total = 81 59 9 13 0 0 Damage Profile (% wall) ~ penetration body ~ metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 Bottom of Survey = 218.1 Analysis Overview page 2 • PDS REPORT JOINT TABI, Pipe: 35 in 9.3 ppf J-55 EUE MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Cornpany: Norninal I.D.: 2.992 in Country: Survey Date: ~ ~LATION SHEEf 2K-18 Kuparuk ConocoPhillips Alaska, Inc. USA August 18, 2009 Joint No. Jt. Depth (Ft.) I'f~n. I ~~~~<~t Iln~.) Pen. Body (Ins.) I'E~n. %, 1~1~~t,~l I o,~ °~~, Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 SO 100 .1 37 i~ 0.03 1U ~' 2.95 PUP 1 43 u 0.04 17 _' 2.90 Shallow ittin . LL De sils. 1.1 7 U 0.00 Z U .96 PUP 1.2 85 l~ 0.03 13 E~ 3.00 PUP Linc shallow corrosion. 2 95 ~~ 0.04 15 I 2.88 Shallow ittin . Lt De sits. 3 126 ~~ 0.03 13 1 2.89 Shallow i tin . Lt. De its. 4 158 i~ 0.03 I I I 2.88 I.t De osits. 5 189 ~~ 0.03 I t 1 2.92 Shallow ittin . Lt. e sits. 6 2 ~) 0.02 ~) I 2.91 7 252 U 0.04 18 I 2.92 Shallow ittin . 8 283 l) 0.05 19 _' 2.93 Shallow ittin . 9 314 U 0.03 1:t I 2.89 Shallow it6n . Lt. De sits. 10 345 ~) 0.03 1 l i I 2. 3 11 376 O 0.04 1> I 2.92 Shallow ittin . 12 407 U 0.04 17 ! 2.8F3 Shallow ittin . Lt. De sits. 13 435 O 0.02 ~ t~ 2.92 14 67 t1 0.03 1U I 2.89 Lt De osits. 15 498 U 0.04 1(> Z 2.89 Shallow ittin . Lt. De sits. 16 530 t i U 1 2.93 U 561 c~ 0.05 18 2 2.89 Shallow ittin . Lt De its. 18 592 U 0.04 16 1 2.93 Shallow ittin . 19 625 u 0.00 I ~~ 2.92 20 657 U 0.06 ~?~ ' 2.91 Isolated ittin . 21 688 U.(~,- 0.07 1E~ 1 2.90 Pittin in u set. 2 720 u .04 1 b 2.89 Shallow ittin . Lt. De si s. 23 752 i) 0.08 32 5 2.89 Line of its. Lt. De sits. 24 784 t~.U ~ 0.05 21 ! 2.90 Line of its. Lt e sits. 25 816 t~ 0.05 19 _' 2.89 Corrosion rin shallow . Lt. De osits. 26 847 t~.U s 0.13 52 4 2.89 Corrosion. L De osits. 27 879 (~.~~-1 0.12 -19 5 2.90 Line of its. Lt. e sits. 28 910 (~ 0.19 7:3 (> 2.90 Line corrosion. Lt. De sits. 29 942 U.t):3 0.16 61 i 2.90 Corrosion. Lt. De osits. 30 973 t~.t1 ; 0.12 4~) -3 2 89 Line corrosion. LL De osits. 31 1005 t1.114 0.12 4i -1 2.91 Line corrosion. Lt De sits. 32 1037 U.e~~l 0.12 47 ~ 2.90 Line of itc. Lt De osits. 33 1069 (1.ii; 0.11 44 ~a 2.91 Linecorrosion. 34 1103 U 0.12 46 -t 2.91 Line corrosio . 35 1136 U 0.12 -1ti a 2.89 Line corrosion. Lt. De sits. 36 1168 U.l1t~ 0.11 -1.~ -l 2.89 Line corrosion. Lt. De si . 37 1200 l~ 0.10 4O ' 2.88 Corrosion. Lt. De osits. 38 1233 u 0.12 d7 ti 2.90 Line of its. Lt. De sits. 39 1265 ll 0.11 41 _' 2.92 Line corrosion. 1298 u 0.10 4tl ~ 2.92 Line corrosion. 41 1331 !? 0.11 4 ~ `"i 2.91 Line corrosion. 42 1364 ~) 0 07 2 7 4 2.90 Line corr sion. 43 1397 n 0.06 25 3 2.92 Isolated ittin . 44 1429 ~~ 0.08 S I ~ 2.89 Isolated ittin . Lt. De sits. 45 1463 ~~ 0.06 _'"~' _' 2.91 Isolated ittin . 46 1496 t~ 0.09 34 ' 2.90 Corrosion. Lt. De osits. 47 1527 u 0.07 26 2.92 Isolated ~~ittin . ~ PeneUation Body Metal Loss Body Page 1 ~ PDS REPORT JOINT TABI. Pipe: 3.5 in 93 ppf J-55 EUE MOD Well: Body Wall: 0.254 in Field: Upset Wail: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~ LATION SH EEf 2 K-18 Kuparuk ConocoPhillips Alaska, Inc USA August 18, 2009 Joint No. )t Depth (Ft.) !'~~n. IJF~~c~i Un~.~ Pen. Body (Ins.) Pe~n. °4, ~1~~t.il I~,~~ ~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 48 1560 ~~ 0.06 :.' i 2.89 Isolated itti . Lt. De osits. 49 1592 (~ 0.06 14 ~ .89 Isolated itti . Lt. De sits. 50 16 5 U.t) > 0.07 26 I 2.89 Corrosion. I.t. De osits. 51 1657 ~) 0.03 13 Z 290 Shallow ittin . 52 1690 l) 0.06 24 Z 2.88 Isolat d it6 . Lt e sits. 53 17 2 l? 0.06 < i ' 2. 0 Corrosion. Lt. e osi . 54 1755 U 0.06 ? f ? 2.90 Corrosi n. t. De osits. 54.1 1787 ~> 0.08 31 5 2.96 PUP Corrosion. 54.2 1795 U 0 O U 2.81 SSSV 55 1807 U 0.05 1~) 1 2.87 Shallow itti . Lt. De osits. 56 1839 l~ 0.03 1Z I .88 Lt. De osits. 57 1872 ~) 0.00 _' I 2.88 t. De osi . 58 1904 U 0.04 1' ' 2.88 Shallow ittin . Lt. De si . 59 1936 t~ 0.03 1 1 2.90 Lt. De osits. 60 1969 +) 0.0 ~) U 2.88 l. e o its. 61 2001 O.Ub 0.06 ~~.,' tl 2.93 Pittin in u t. 62 2033 t? 0.04 1=1 ' 2.86 Shallow ittin . Lt. De sits. 63 2066 U 0.02 6 I 2.92 64 20 7 O 0.04 14 I 2.89 Shallow ittin . t. De sits. 65 213 U 0. 3 1 i l 2.87 Shallow itb . Lt. De sits. 66 2162 U 0.03 1 1 I 2.88 Lt. De osits. 67 2195 U 0.04 16 1 2.91 Shallow ittin . 6 2227 U 0.04 14 i 2.89 Shallow ittin . Lt. e sits. 69 2260 O 0.04 1 5 ~' 2.88 Shallow ittin . Lt. De sits. 70 292 t) 0.03 1? 2. t. e osi s. 71 2325 U 0.03 12 I 2.89 Lt. De osits. 72 2357 O 0.01 2 ~) 2.90 Lt. De osits. 73 2390 ~~ 0.04 15 ' 2,91 Shallow ittin . Lt. De sits. 74 2422 t1 p.04 15 I .89 Shallow ittin . t.t. De sits. 75 2455 ~) 0.03 1 ~) I 2.92 Lt. De osi ts. 76 2487 ~~ 0.03 12 _' .90 Shalow ittin . tDe sits. 76.1 2520 U 0 U t~ N A GLM 1 Latch ~ 630 77 2527 U 0.03 13 I 2,89 Shallow ittin . Lt. De osits. 78 2560 (1 0.04 1(> 1 2.91 Shallow ittin . Lt. De sits. 79 2592 c) .04 14 I 2.91 Shall w i tin . Lt. De osits. 80 2624 U 0.03 12 I 2.91 Shallow ittin . Lt. De sits. 81 2657 U 0.0 9 U 2.90 t. e osits. 82 'L688 ~1 0.02 9 1 2.91 Lt. De osits. 83 2720 t? 0.03 1 I I 2.90 Lt. D osits. 84 2753 s~ p.03 I I _' 2.88 Lt De osits. 85 27 S ~~ 0.03 I 3 I .89 S allow it in . t. e sits. 86 2817 U 0.00 Z U 2.89 Lt. De osits. 87 2851 l? 0.00 I ~~ 2.88 t De osits. 88 2883 U 0.03 10 I 2.89 Lt De osits. 89 2915 u 0.02 9 1 2.91 Lt. De osits. 90 2948 t~ 0.03 11 i 2.93 91 2978 ~~ 0.03 11 U 2.92 92 3009 + 1 0.01 ~! 2.94 93 3039 ~~ 0.00 I 2.90 94 3070 i~ 0.02 ~~ I 2.90 Lt. De ~osils. ~Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf J-55 EUE MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 2 K-18 Kuparuk ConocoPhillips Alaska, Inc. USA August 18, 2009 Joint No. Jt. Depth (Ft.) I'c~n. lI{>,e~t (lii~;.) Pen. Body (Ins.) I'en. %~ Mc~1al loss ",~~ Min. I.D. (Ins.) Comrnents Damage Profile (%wall) 0 50 100 95 3 7 00 U 0.02 ~) I 2.92 96 3131 O 0.02 f3 1 2.93 97 3162 U 0.03 1' ' 2.93 S allo ittin . 98 3193 u 0.04 15 I 2.92 Shallow ittin . 99 3 23 u 0.03 I~~ I 2.91 00 3254 U 0.01 ~1 u 2.91 101 3 84 ~? 0.01 4 I 2.91 Lt. De osits. 102 3316 ll 0.03 I ~~ I 2.92 Li e shall w corrosion. 103 3347 t) 0.03 1~~ I 2.92 104 3377 U 0.01 t I 2.92 105 3409 U 0 t) t! 2.91 t De osits. 106 3439 t) 0.00 ? !~ 292 107 3467 u 0.02 r3 i .91 108 3498 U 0.00 1 ~~ .91 Lt. De osits. 109 3528 t~ 0.02 ~) ~,7 2. 2 110 3560 t~ ~.01 ~ I 2.93 111 3591 tl 0.00 2 ~~ 2.91 112 3622 U 0.00 1 t~ 2.91 113 3652 U 0 U U 2.89 Lt e osits. 114 3 82 U 0.02 9 I 2.91 115 3713 U 0.02 9 I 2.87 Lt. De s'ts. 116 3745 U 0 l 1 ~~ 2.85 Lt. De osi ts. 117 3778 U 0.00 1 U 2.85 Lt. De osits. 118 3810 U 0.04 16 1 2.90 Shallow ittin . Lt De sits. 119 1 O 0. 3 13 1 . 1 Sh Ilow ~tfi 120 3872 n 0 l) c1 2.91 121 3903 11 0 U U 2.85 Lt. De osits. 122 3935 ~~ 0 U t~ 2.84 Lt. De osits. 12 3968 ~) 0.03 1~ I 2.83 Shallo itti . Lt. De si . 124 4000 U 0_03 10 ~i 2.83 Lt De osits. 125 4033 (1 0.02 ~1 1 2.82 Lt. De osits. 126 4065 c) 0.01 2 U 2.84 Lt. De osits. 127 4098 O 0.02 ~) 1 .76 Lt. D osits. 128 4130 tl 0.03 12 1 2.84 Lt. De osits. 129 4163 U 0 U t1 2.84 Lt. De osits. 130 4195 U 0.03 I 3 1 2.85 Shallow ittin . Lt. De sits. 131 4226 l) 0 U 1) 2.85 Lt.l~e osits. 132 4258 ~~ 0.00 U u 2.84 Lt. Ue osits. 133 4291 l~~ 0 O u 2.82 Lt De osits. 134 4323 ct 0.01 s i) 2.85 Lt. De osits. 135 4356 l1 0 (1 U 2.87 Lt. De osits. 136 4389 ~~ 0 U (1 2.86 Lt De osits. 137 4421 ll 0.00 1 (1 2.$5 Lt. De osits. 138 4453 t~ 0 ll O 2.84 Lt, De osits. 139 4486 ~) 0 (1 I 2.85 Lt. De osi ts. 140 4518 (1 0.03 1; i 2.83 Shallow ittin . Lt. De osits. 141 4551 ~) 0 U ~~ 2.86 Lt. De osi ts. 142 4583 ~~ 0 U ~~ 2.82 Lt. De osi ts. 143 4617 0.03 1 U I 2.82 I I. Dc~ ~oci ts. 143.1 4649 ~ 0 0 u N A GI M 2 I alch Co,> 2:00 ' Penetra6on Body i Metal Loss Body Page 3 • PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf )-55 EUE MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~LATION SHEET 2K-18 Kuparuk ConocoPhillips Alaska, Inc. USA August 18, 2009 )oint No. )t. Depth (Ft.) I'~~n. U~n~~t (In..) Pen. Body (Ins.) Pe~n. °i~> ~t~t,d I c>ss °4~ Min. I.D. (Ins.) CommenYs Damage Profile (%wall) 0 50 100 144 4655 ~~ 0.04 17 I 2.87 Shallow ittin . Lt. De osits. 145 4688 t 1 0 O I 2.87 Lt. De osi ts. 146 4720 ~~ 0.02 '> I 2.88 Lt. De sits. 147 4752 ~ ~ 0 ~) I 2.85 l.t. De os ls. 148 4785 ~~ 0 +~ i ~ 2.88 Lt. De osits. 149 4817 t~ 0.03 I I I 2.88 Lt. De osits. 150 4850 1) Q02 ~~ I 2.93 151 4881 (~ 0.02 ~~ 1~ 2.88 Lt. De osi ts. 152 4912 ~~ 0.01 b u 2.84 Lt. De osi ts. 1 3 4942 t~ 0.01 S ~~ 2.85 l.t. De osi ts. 154 4974 t~ 0 0 u 2.84 Lt. De osits. 15 5007 t~ 0 l1 ~i 2.84 Lt De osits. 156 5039 l1 0.03 I; I 2.83 Shallow ittin . Lt. De sits. 1 7 5072 ~) 0 U ~ ~ 2.83 Lt De osits. 158 5105 i~ 0 (1 i) 2.85 Lt. De osits. 159 5135 U 0.03 1 I I 2.87 Lt. De osits. 160 5165 ll 0.00 2 t) 2.88 Lt. De osits. 161 5196 c1 .00 1 U 2J9 D sits. 162 5228 ~~ 0 O ~~ 2.86 Lt. De osit . 163 5261 u 0 U I 2.84 Lt. De osits. 164 5293 U 0 l~ ~~ 2.86 Lt. e osits. 165 5326 O D l~ ~~ 2.86 LL De osits. 166 5359 U 0.02 ~) U 2.87 Lt De osits. 167 5391 U 0.03 1 1 U 2.89 Lt. De osits. 168 5424 ~~ 0.01 Z u 2.91 169 5456 u 0.01 2 ~? 2.87 Lt. De osits. 170 5488 i~ 0.00 1 ~~ 2.87 Lt. De osits. 171 5521 ~ 1 0.00 1 (! 2.87 Lt. D osi ts. 172 5554 c~ 0 O I 2.8 Lt. sits. 173 5586 ~~ 0.02 ~3 1 2.87 Lt. De osits. 174 5618 ~~ 0.02 9 1 2.85 Lt. De sits. 175 5651 u 0 0 u 2.86 Lt De osits. 176 5683 ~~ OA 9 I 2.8£3 t De osits. 177 5716 U 0.02 ~) I 2.86 Lt. De osits. 178 5748 (1 0.02 ~) I 2.86 I..t De osits. 179 5781 ~.l 0 l) u 2.88 l.t. De osits. 180 5810 U 0 l~ tt 2.86 Lt. e osits. 181 5841 t~ 0 {~ I 2.88 Lt. De osi ts. 182 5872 l) 0.02 i ~1 2.89 Lt De osits. 183 5902 O 0.01 4 U 2.90 Lt. De osits. 183.1 5931 ~~ 0 (1 t~ N A GLM 3 Latch 7:00 184 5938 l~ 0 l1 ~1 2.85 Lt. De osits. 185 5971 l) 0 0 U 2.84 Lt. De osits 186 6004 t) 0 U 1 2.86 Lt. De osits. 187 6036 l) 0.0 ~~ t1 2.86 Lt. De osits. 188 6069 U 0 U u 2.85 Lt. De sits. 189 6101 U 0 ~ 1 t~ 2.86 L. De osi ts. 190 6134 l~ 0 ll ~~ 2.86 Lt De osits. 191 6166 ~~ 0.02 ~) I 2.85 Lt. De osits. 192 6199 !~ 0.02 9 1 2.84 I.t. De osi ts. Penetraiion Body Metal Loss Body Page 4 • PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf j-55 EUE MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: No-ninal I.D.: 2.992 in Country: Survey Date: • -LATION SHEEf 2 K-18 Kuparuk ConocoPhillips Alaska, Inc. USA August 18, 2009 Joint No. Jt. Depth (Ft) I'c~n. I I~>,<<i Un..) Pen. Body (Ins.) Pc~n. °4~ ~Ic~tal I oss "4~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 193 6231 ~~ 0.02 ~) I 2.85 Lt. De osits. 194 6264 i~ 0 U I) 2.88 Lt. De osi . 195 6296 ~~ 0 U U 2.86 Lt. e osi . 196 632 9 i) 0.02 £3 ~ 1 2.86 l.t. De osi ts. 197 6361 ~ ~ 0 U i~ 2.88 Lt. De osits. 198 6392 t1 0.02 ~) ~~ 2.87 Lt D osits. 199 6425 ~~ 0.03 I? I 2.90 Lt De osits. 200 6457 (~ 0 U U 2.89 Lt De osits. 201 6489 U 0.02 ~) I .85 Lt. De osits. 202 6522 U 0.03 1 1 I 2.87 L~ De osits. 203 6555 1) 0.03 1t) U 2.91 Lt. De osits. 204 6587 U U.03 11 1 2.86 Lt. e vsits. 204.1 6619 0 0 l1 u 2.89 PUP Lt. De sits. 204.2 6627 (~ 0 U ~~ N A GLM 4 atch ~ 430 2043 6634 ~~ 0.03 II U 2.93 PUP 205 6639 ~~ 0.03 I I i i 2.86 Lt. De osi ts. 206 6671 ~) 0.03 I~ i ~) 2.91 07 6703 c~ 0.04 la I 2.86 Shallow ittin . Lt. De sits 208 6737 (~ 0 U U 2.89 Lt. De osits. 209 6769 U 0.04 16 I 2.90 Sh Ilow i[tin . Lt. De sits. 2 0 6f300 U 0.03 11 I 2. 6 tt. De osits. 211 6834 O 0.03 1~' 1 2.90 Shallow ittin . Lt. De sits. 212 6866 ~1 0.03 lU 1 2.89 Lt. De osits. 213 6898 U 0.02 ~~ I 2.92 Lt. De osits. 214 6930 U 0.02 ~) I 2.90 Lt. De osits. 21 S 6963 t ~ 0 U u 2.91 Lt De osi ts. 216 6996 l1 0.02 ~) 1 2.90 Lt. De osits. 216.1 7028 ~) 0.03 1O I 2.90 PUP Lt. De sits. 216.2 7035 (~ 0 0 ~~ N A GI.M 5 I_atch ~ 10:00 216.3 7042 U 0.03 13 I 2.92 PUP Shallow ittin . Lt De si1s. 217 7046 t) 0.03 12 1 2.87 Shallow ittin . LL De sits. 217.1 7079 O 0 0 U 2.90 PBR - Baker'80-40' w 10' Stroke 217.2 7093 ~ 1 0 ll t~ .89 Baker'HB' Retrievable Packer 217.3 7100 ~~ 0.00 1 u 2.93 PUP 217.4 7108 tt 0 U ~~ 2J5 Otis'XN' ~ le 2.75" No Go 2.81" Polishe 218 7110 ~ ~ 0.04 1 t; ' 2.92 Shallow corrosion. Lt. De osits. 218.1 7143 c~ 0 U 'L.92 -1-IL Muleshoe ~ Nenetration Body Metal Loss [3ody Page 5 ~ ~ ~ ~ ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ r ~ ~ ~ ~1U r~+c.~ PDS Report Cross Sections Well: 2K-18 5urvey Date: August 18, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin : 3.5 ins 9.3 f -55 EUE MOD __ __ _ Analyst: M. Lawrence Cross Section for Joint 28 at depth 922.363 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 95 % Tool deviation = 3 ° Finger 14 Penetration = 0.185 ins Line Corrosion 0.19 ins = 73% Wall Penetration HIGH SIDE = UP • • Cross Sections page 1 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections ~„ -- ~'~ ,. Well: 2K-18 Survey Date: August 18, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin : 3.5 ins 93 f •55 EUE MOD Anal st: M. lawrence !, Cross Section for Joint 29 at depth 960.123 ft ', Tool speed = 43 Nominal ID = 2.992 Nomina! OD = 3.500 Remaining wal~ area = 96 % Tool deviation = 1 ° Finger 22 Penetradon = 0.156 ins Corrosion 0.16 ins = 61 % Wall Penetra6on HIGH SIDE = UP ~ • Cross Sections page 2 ~,- ~~a KUP ~ 2K-18 ~OIlOCO~'11~~IP5 n At tributes - M le ~ ND TO a~.~.:^ w oa a 501032071700 KUPARUK RIVER UNIT w~n INJ ma ~ 42.28 2,500.00 eao 7,960.0 ~ -- o. Commen[ SSSV_ TR DP H2 mpm) ete MoUtlon Last WO: Dafe 39.99 Pog Neue 11/3/1989 ~ e Amaatlon Last MoA y ah Last Tag: SI.M 7.730-0 &1/2009 Rev Reason: TAG, SET PWG krasbor 8/8f2009 Casi~ Strin s --- s~nns Nre oepn sN mAl rvg strr v caskg D esatpoon M) (-+1 rop I~el f~) Io~q Ona e r Tra CONDVCfOR, CONDUC TOR 1 6 15.062 0.0 115.0 175.0 62.50 H-40 ~15 SURFAC E 95 B 8J65 0.0 3,359.0 2,970.4 .00 J-55 PRODUC TION 7 6.151 0 0 7 463.0 6.192.5 26.00 .F55 SnFeivv~v, ° LINER 5 4276 7.121.0 7.918.0 6.549.5 18.00 L-80 , ~ . ~ Tnbi 9tri s ~ T1~Ehg D eaalpbon cnng (M) a~ (~+) Top (Itltl) set ueqn (~~) se~ ~ (~B) s[rng Nrt (wsllq smr dae g e 3Uh~g Ta p 71R1 TU&NG 3 1/ 2 2.992 0.0 7.743D 5,9J9.1 9.30 J~55 EUE-MOD Other I n Hole NI Jawe l . Tu Run 3 R ~trleva Fish etc. ~~ ~~~ zsao io °P (ND) ~~ 7op YW (') De on CmmM R~n Date N SURFACE 1,808 .768.3 31.55 S AFETY VLV Camco RD -tASSA'Lo d~ed Out Flapper 4/15P93' 4/27/1990 2.812 , 3 ase 2.5 2,337.6 4224 G AS IIFT ME LMM PD/tl MVIBKI II Comment: STA 1 5i17/1994 2.875 4,654 3,984.4 37.96 G AS LIFT ERLNTM PDIIIDMY/BK/// Comment: STA 2 5/16l1994 2.875 5,935 4,993.7 37.36G ASLI MEFLlVTM PD/11DMY/BW//CoemmentSTA3 5/16/1994 2.875 ~ns uFr. 4.654 6,628 5.536.0 40.69 G AS UFT CAMCO/MM G-711.5/DMY/ RK/ll Camient: STA 4 5/16/1994 2.920 7,035 5,854.1 38.30 G AS LIFT CAMCO/NM IG-71 .5/DMV/ RKIl/ Comment STAb 5/16l1 2.920 7,080 5,889.3 38.08 BR Baker'80-40 ' w! 10' Stroke 4I27/1990 3.000 7,094 5,900.3 38.01 P ACKER BaFM'HB' R IEVABLE ACKER 4l27/1990 2.890 G~S 395 7,170 5.913.0 37. 3P LUG 2.81"XXNP LUGwlFILLE XT(OAL=-08') &3/2 0.000 7,110 5,973.0 37.93N IPPLE Otis'XN'tip ple2.7 N0 60w/2.81'POLISHEpBO E 4/27/1990 2.750 7,128 5,9271 37.84 P ACKER ROWNJM TIEBACKPA CKE 4127l1990 42 7,143 5.939.1 37.77 T 7L MWeshoe M27/7990 2.992 G~a e Partoro tlons ~ Slots TePl~o) 8trn rop IT~iq (~W eon ITwI (~BI Zone Cate oenc (~- Car mient ~ns uF-r. ~ ws 7.504 ,5 5 6,223.6 6,2J2.5 C-4, UNR B, 2K-18 SI'16f1997 6.0 R 60 deg. Ph.isirig; 2.5" HSD DP 7.566 ~,576 . 73.6 6.281.6 A-5. 2K-78 5/26/1997 6.0 APFRF 60 deg. Phasig: 2.5' HSD 7.602 .642 .301.7 6.~33.8 A~A. 2K-18 4/26/1990 4.0 IPER 180 deg. Phasing ~ '3 3/8' FIL C ssirg PBF.I,OBp i. PACNfR. 7 096 NIPPLE 7 110 . . 1 PLUG 1~0 . . PACKF_R,],12E ~ I il I.. I.1A3 PROWCTION, I6W {WERF, ],504-~.515 APERF. ~ 566-].S16 IPERF T 602 T.602 LINER. ] 918 TD, 1960 • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 29, 2008 ~p AU G ~ ~~ ~~IIB Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • 1~~_ ~p8 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped June 30, July 4, and July 20, 2008. The corrosion inhibitor/sealant was pumped June 29, June 30, July10, and July 24, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~J ~~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field t Date 7/29/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2K-01 1.88-122 SF NA 10" 6/30/2008 2 6/29/2008 2K-02 188-121 SF NA 10" 6/30/2008 2 6/29!2008 2K-03 188-120 24" NA 24" 6/30/2008 8.5 6/29/2008 2K-05 188-118 SF NA 10" NA 2.55 7/10/2008 2K-06 189-082 SF NA 15" NA 1.27 7/10/2008 3K-13 189-095 8'1" 1.00 25" 7/4/2008 6.38 7/10/2008 2K-15 189-089 SF NA 6" 6/30/2008 1 6/30/2008 2K-17 189-119 10" NA 10" 6/30/2008 23.8 6/30/2008 2K-18 189-108 SF NA 11" NA 2.12 .7/10/2008 2K-21A 198-158 20' 2.70 14" 7/4/2008 4.68 7/10/2008 2K-22 189-115 6" NA 6" 6/30/2008 5.1 6/30/2008 2K-25 190-012 SF NA 12" NA 2.55 7/10/2008 2K-26 190-015 SF NA 10" 6/30/2008 2 6/29/2008 2K-28 201-154 3'10" NA 3"10" 6/30/2008 23.8 6/30/2008 2M-04 192-093 SF NA 20" NA 3.4 7/10/2008 2M-27 192-071 9'9" 1.2 18" 7/4/2008 2.55 7/10/2008 26-07 184-024 20' 2.7 34" 7/4/2008 5.95 7/10/2008 2V-01 183-158 24" NA 24" NA 20.4 7/24/2008 2V-02 183-161 11" NA 11" NA 1.3 7/24/2008 2V-03 183-164 24' 6" 3.40 8" 7/20/2008 5.5 7/24/2008 2V-04 183-165 20' 4" 2.80 8" 7/20/2008 5.1 7/24/2008 2V-05 183-176 SF NA 4" NA 2.1 7/24/2008 2V-09 185-037 SF NA 4" NA 1.7 7/24!2008 2V-11 185-049 SF NA 4" NA 1.7 7/24/2008 2V-12 185-050 40' 5.4 8" 7/20/2008 8.5 7/24/2008 2V-13 185-030 18" NA 18" NA 3.8 7/24/2008 2V-14 185-031 SF NA 4" NA 1.7 7/24/2008 2V-15 185-032 SF NA 4" NA 1.7 7/24/2008 ~7~rll~~m~~'~~i~ I, .1i n Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ 2~~7 ATTN: Beth ~~~~~ ~~~ Well Job # N0.4445 Company: Alaska OiI & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ~~ ~ . Log Description _ .._... -~ '"~""'~•---Date BL Color CD 10/15/07 2N-343 (REDO) 11745232 MEM INJECTION PROFILE Z C- - '~' 08108/07 1 1B-14 11837493 PRODUCTION PROFILE - ~ - 08/27/07 1 1A-18 11839651 PRODUCTION PROFILE Q- 08/30/07 1 1Y-18 11837499 PRODUCTION PROFILE G~ " - 08130/07 1 1G-14 11839652 INJEGTION PROFILE ~ ~- ~ 08131107 1 1A-01 N/A USIT - 08131107 1 1Y-04 11839653 INJECTION PROFILE ~~5 ~ 09101/07 1 1Y-32 11839655 PRODUCTION PROFILE '~ - 09/02/07 1 2T-TAB-01 11839656 INJECTION PROFILE C. - - 09/03/07 1 2K-25 11846439 {NJECTION PROFILE U = j I 09106/07 1 2K-18 11846440 INJECTION PROFILE 1 09/07107 1 1B-18 11846441 PRODUCTION PROFILE < - (p 09108/07 1 2T-20 11846442 PRODUCTION PROFILE ~~ '~ -- 09109107 1 2N-310 11850433 SONIC SCANNER 7b"~ -(~ ~ 09116/07 1 2N-310 11850433 SONIC SCANNER-FMI ~ - C~`~ C7 09116107 1 1J-176 11846443 USIT "3 -p 09117!07 1 1 E-29 NIA UCI ( - ( -09/19/07 1 3F-21 11837503 RST/ WFL - 09120107 1 26-10 11839661 INJECTION PROFILE ~- - 09/22107 1 1G-05 11837506 INJECTION PROFILE v=C - 09/23/07 1 2K-13 11839682 INJECTION PROFIL ~ - 09123!07 1 iB-OS 11837508 INJECTION PROFILE .1.-~- 09124107 1 3H-08 11839663 PRODUCTION PROFILE - t'j 09/24/07 1 1Y-31 11839664 PRODUCTION PROFILE jai - 09/25/07 1 1G-06 11839665 INJECTION PROFILE 09/26/07 1 2Z-01A 11837512 USIT - ~ ~ 09/27/07 1 2V-08A 11837511 ISOLATION SCANNER ~~(- ~ 09/28107 1 1G-11 11837513 PRODUCTION PROFILE 09/29/07 1 1Y-22 11837515 PRODUCTION PROFILE ~ - 6 09130/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: ~~~ s~:~r~isor 'Ref? ro/fo(07 DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-18 KUPARUK RIV UNIT 2K-18 (Ã" \Oq, \'6 -, FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~1æ- Comm Well Name: KUPARUK RIV UNIT 2K-18 API Well Number: 50-103-20117-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070601181643 Permit Number: 189-108-0 Inspection Date: 6/1/2007 ¡/ Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K-I8 Type Inj. w TVD 5900 IA 1600 2380 2280 2280 P.T.D 1891080 TypeTest SPT Test psi 1500 OA 540 610 610 610 Interval 4YRTST P/F P ,/ Tubing 2500 2500 2500 2500 Notes: Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. /' NON-CONFIDENTIAL SCANNED JUN· 2 0 2007 Wednesday, June 06, 2007 Page 1 of 1 MEMORANDUM Commissioner P.I. Supervisor THRU: FROM: State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 14, 2003 SUBJECT: Mechanical Integrity Tests Conoco/Phillips Kuparuk River Field 2K Pad John Crisp Petroleum Inspector NON- CONFIDENTIAL Kuparuk River Unit Packer Depth Pretest Initial 15 Min. 30 Min. We,,I 2K-OS I Type,nj.I s I ~.v.o. I~ I Tubingl=~oo I~oo I~oo I~oo I,nterv~'l 4 P.T.D.I 1881180ITypetestl P ITestpsil 3000 ICasingI 1380I 2980I 2940I 2930I P/F I -P Notes: OA 600 psi. pretest 680 psi, during test. 4.5 BBL, Pumped. We,,I aK-Oe IType,~j.I S I ~.v.o. I~oo~ I~u~,~l ~o I~o I~o I~o I,~terva, I 4 P.T.D.I 1890820 ITypetestl P ITestpsil 3000 ICasingI 1320I 3010I 2980I 2975I P/F I -P Notes: OA 950 psi. during test. 2.6 BBL. Pumped. We,I 2~-~0 I Type,nJ.I ~ I T.V.O. I~ I~u~,n~l~0 I~0 I~0 I~0 I,~terv~,l 4 P.T.D.I 1890590 ITypetestl P ITestpsil 3000 ICasingI 410 I 29601 29101 29001 P/F I --P Notes: OA 200 psi. during test. 5.4 BBL. Pumped WellI 2K,13 I~,ni.I s I T.V.D. 16138 ITubingl 2450 I 2450 I 2450 I 2450 Ilntervall 4 P.T.D.I 1890950 ITypetestl P ITestpsil 3000 I Casingl 1220I 2940I 2875I 2860I P/F I P Notes: OA 850 psi. pretest 1020 during test. 4.5 BBL. Pumped. WellI 2K-la I Typelnj.I S I ~.v.~. I ~oo I Tubing I 2550 I~o I ~o I~o I,~terv~,l 4 P.T.D.I 1891080ITypetestl P ITestpsil 3000 I Casingl 1320I 2980I 2925I 2900I P/F I E Notes: OA 300 psi. during test. 5 BBL. Pumped. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING 4 year MIT's witnessed. No failures. Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 4 Attachments: Number of Failures: 0 Total Time during tests: 4 hrs, CC: MIT report form 5/12/00 L.G. 2003-0614_MIT_KRU_2K- 18__ic.xls 6/24/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD I UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/2K 06/14/03 Sauvageau/Brake - APC John Cdsp Packer Depth Pretest Initial 15 Min. 30 Min. WoIII2K-05 ] TypelnjI ~ ] T.V.D. I 5945 I Tubing I 22001 22001 22001 22001 Interval P.T.D.]1881180 Type Test TestpsiI 1500 I Casing I 13801 298O1 2940] 29301 P/F Notes: P.T.D.I'Ia90820 Type Test Test psiI 1502 I Casing I 13201 30101 29801 29751 P/F Notes: P.T.D. II.890590 TypeTest Test psiI 1500 I Casing I 4101 29601 29101 29751 P/F Notes: P.T.D, It890950 Type Test TestpsiI 1535 I Casing I 12201 29401 28751 28601 P/F Notes: Wo"I~K'~s ITypeInJ I Sp I T.V.D. I~00 I Tubi.gl ~oI~oI~oI~oool,n~e~,l ~I P.,T'.:D::/~:89t080' Type Test Test psiI 1500 I Casing I 13201 29801 29201 29001 P/F Notes: Wo'll2K'20 I TVpo'njl ~ IT.V.~.l~l*u~ingI 20401 20401 20~01 20~01'n~e~'l ~I P,T,:D,I~89~80 Type Test Test psiI 1536 I CasingI 400129001 28751 28501 P/F Notes: We"I2K'24 I Typelnj I gIT'V'D' I~0~ I Tubingl ~1 ~1 ~*1~l'"'e~'l ¢~ P;T:D:I~89~300 TypeTest Test psi I 1551 I Casing I ~3001 28801 28201 28001 P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting MIT Report Form Revised: 05/19/02 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test 2003-0614 MIT KRU 2K-05 06 10 13 18 20 24.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) 6/25/2003 KRU 4 yr MIT's 2K & 2T Subject: KRU 4 yr MIT's 2K & 2T Date: Sun, 15 Jun 2003 16:23:23 -0800 From: "NSK Problem Well Supv" <nl 617@conocophillips.com> To: bob_fleckenstein~admin.state.ak.us, jim_regg~admin.state.ak.us, tom_maunder~admin.state.ak.us CC: "nl 617" <nl 617~conocophillips.com> Tom, Bob, Jim, Attached are the 4 yr MIT's for injection wells on 2K and 2T. Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224 (See attached file: MIT KRU 2T 06-14-03.xls) (See attached file: MIT KRU 2K 06-14-03.xls) i~MIT KRU 2T 06-14-03.xls MIT KRU 2T 06-14-03.xls ] Name:Type: EXCEL File (application/msexcel) 1~ 1 Encoding: base64 %~_~ MIT KRU 2K 06-14-03.xls Type: EXCEL File (application/msexcel)~:] ~E~?ding: base64 ] 1 of I 6/2.5/2003 1:45 PI~ 1. Operations Performed: 2. Name of Operator STATE OF ALASKA ALA,SKA OIL AND GAS CONSERVATION COMMMSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown __ Stimulate __ Plugging Pull tubing Alter casing Repair well ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 194' FNL, 94' FEL, Sec. 11, T10N, R8E, UM At top of productive interval 1467' FSL, 949' FWL, Sec. 12, T10N, R8E, UM At effective depth 1293' FSL, 1004' FWL, Sec. 12, T10N, R8E, UM At total depth 1191' FSL, 1036' FWL, Sec. 12, T10N, R8E, UM 7960' feet 6560' feet Present well condition summary Total Depth: measured true vertical Effective depth: measured 7787' true vertical 6425' Length Size 80' 3324 9 5/8" 7430' 7" 784' 5" measured 76O2-7642' true vertical 6303'-6334' 4 SPF, 12. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Plugs (measured) None feet Junk (measured) feet None Cemented 1100 Sx AS III & 450 Sx Class G 250 Sx Class G 157 Sx Class G 180° phasing Tubing (size, grade, and measured depth) 3.5" J-55 9.3#, ABMOD, EUE @ 7143' Packers and SSSV (type and measured depth) Baker HB @ 7094', Camco TRDP-1A-SSA @ 1808' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure OR IG IN A L ¢ Prior to well operation 14. Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Perforate _ Other 6. Datum elevation (DF or KB) 154' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-18 9. Permit number~approvaLnumber - lOG I10. APl number 50-1 03-2011 7 11. Field/Pool Kuparuk River Oil Pool True vertical depth Measured depth 80' 80' 3359' 2743 6171' 5919'-6527' 7463' 7134'-7918' R 'ECEIVED JUN ]g9 .Oil,& Gas Cons. (;ommission Anchorage Representative Daily Average Produmion or Injection Data OiI-Bbl Gas-Mcf Water-Bbl CasingPressure 380 1250 -0- 1000 -0 -0- 1500 1000 Tubing Pressure 295 2100 Status of well classification as: Water Injector ~ Oil _ Gas Suspended 16. Service Date SUBMIT IN DUPLICATE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,Signed ' Title Form 10-404 Rev 09/12/90 ,Ii AHC;O Alaska, Inc-- ~ ' Subsidtm'y of Atlantic Richfield Comps' WELL iF)BDT .ARKS IFIELD - DISTRICT- STATE IOPERATION AT REPORT TIME WELL SERVICE REPOR'I I DAY,.~ DATE CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, Subsidiary of Atlantic Richfield Compa, ]PBDT "'~NTRACTOR REMARKS WELL SERVICE REPORT IFIELD - DISTRICT- STATE OPERATION AT REPORT TIME IDAYS IDATE . / 0 ~7oo Dt/R~ OT~5 o Cl,.f 5 ,//00 !q, oo · ~°S~. CHECK THISBLOCKIF SUMMARY CONTINUED ON BACK w,,,~ i,-,._ , I--~. I~,'~,,,,,~ _-"' STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate Change approved program_ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development ~ ARCO Alaska. Inc. Exploratory _ RKB 154' feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 194' FNL, 94' FEL, Sec. 11, T10N, R8E, UM 2K-18 At top of productive interval 9. Permit number 1467' FSL, 949' FWL, Sec. 12, T10N, R8E, UM 89-1 08 At effective depth 10. APl number 1293' FSL, 1004' FWL, Sec. 12, T10N, R8E, UM 5o-103-20117 At total depth 11. Field/Pool Kuparuk River Field 1191' FSL, 1036' FWL, Sec. 12, T10N, R8E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 7960' feet Plugs (measured) true vertical 65 6 0' feet None Effective depth: measured 7787' feet Junk (measured) true vertical 6 4 2 5' feet None Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 170 Sx AS II 1 1 5' 1 1 5' Surface 3324' 9 5/8" 1100 Sx AS III & 3359' 2743' Intermediate 450 Sx Class G Production 7 4 3 0' 7" 250 Sx Class G 74 6 3' 61 71 ' Liner 784' 5" 157 Sx Class G 71 34'-791 8' 591 9'-6527' Perforation depth: measured ~L., [ ~ ~b, ~ 7602'-7642' 4 SPF, 180° phasing R~C true vertical 6303' 6334' Tubing (size, grade, and measured depth) ~t~$~,,0~'"" ~ 3 1/2" J-55, 9.3#, ABMOD, EUE @ 7143 .... Packers and SSSV (type and measured depth) '~ Baker HB @ 7094'~ Camco TRDP-1A-SSA @ 1808' 13. Attachments Description summary of proposal _ Detailed operation program ~ BOP sketch_ Convert well from oil producer to water injector. (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: N(~vember 20. 1990 Oil ~ Gas __ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service _.Water Iniector Si~nedl7' I he,~~ t~th~ true and correct to the best of my knowledge. ~, Title ~'-'~i~'/~ ~NL~~ Date FOR COMMISSION USE O Conditions of approval: Notify Commission so representative may witness IAppr~',~J3N__,o. Plug integrity __ BOP Test Location clearance__ I Mechanical Integrity Test~.~ --Subsequent form require 10- /% ORIGINAL'SIGNEO ~¥ LONNIE C. SMITH ! Approved by order of the Commission Commissioner Date Fnrm ln-4nR nnv n.q/lp/_qn _ SUBM T II'i TRIPLICATE Approved Copy Returnee ,- ,_... WELL 2K-18 PRODUCER APl # 501032011700 SURFACE LOCATION' 194' FNL, 94' FEL, SEC 11, T10N, R8E, UM TOP KUPARUK: 1471' FSL, 897' FWL, SEC 12, T10N, R8E, UM DEPTHS: REFERENCED TO 0' RKB TUBING SPOOL ELEV: 31' RKB ALL DEPTHS MD-RKB 16": 62.5# H-40 @ 115' 9 5/8": 36# J-55 @ 3359' TREE: FMC GEN IV 5000 PSI J L ~' GLMI: GLM2: GLM3: GLM4: GLM5: SPUD: 10/24/89 COMPLETION: 4/27/90 SSSV · CAMCO TRDP-1A-SSA ID 2.812" @1808' 2530' / 1.0" TMPD/DV 4654' / 1.0"TMPD/DV 5935' / 1.0"TMPD/DV 6628' / 1.5"MMG-2/DV 7035' / 1.5"MMG-2/DV BAKER PBR 3.000" ID @ 7080' BROWN HB PKR: 2.892" ID @ 7094' OTIS 'XN' NIPPLE 2.75" X 2.813" ID @ 7110' BROWN JM TIEBACK PKR: 4.250" ID @ 7128' 7": 3.5" 9.3# J-55 EUE ABMOD IPC TUBING TAIL(MULESHOE) @ 7143' 26# J-55 @ 7463' A5 A4 A3 5": 18# L-80 @ 7918' PBTD: 7785' HOLE ANGLE ACROSS KUPARUK = 37 DEGREES MAX HOLE ANGLE = 42 DEGREES @ 2500' VOLUME TO TOP PERF = 70 BBLS RECEIVED :~:~.0i] .& Gas Co~s.. Commis~ic,~, 7602' . '. gnchora~,e 4 SPF ~ 180° PHASING ORIENTED 171 ° CCW 7642' FILL TAGGED AT 767O' (8/28/90) REVISION: 10/30/90 M. essrs. Kralick and October 29, 1990 Page 2 Drill Site 2K Initial Water Injection Conversions CC: Downhole 899381 Surface 899399 10/29/90 1) 2) 3) 4) This wireline work should be completed approximately one week prior to the completion of the water injection piping work at DS-2H. The spool piece work inside the manifold building should be completed at the same time. MIRU Slickline and diesel pump truck. RIH and set SV in "XN" or "D" nipple. Wells 2K-06, 18 and 20 are currently on gas lift. Well 2K-10 has not been gas lifted. RIH and pull the bottom DV and replace with a CV in Well 2K-10. Pump diesel down casing while taking returns from tubing. Fill annulus with diesel. Casing displacement to bottom mandrel and mandrel depth are listed below: 2 K- 0 6 195 bbls 7361 feet 2 K- 1 0 166 bbls 6270 feet 2 K- 1 8 186 bbls 7035 feet 2 K- 2 0 274 bbls 9056 feet 2-7/8" TBG 6 ) RIH and pull all GLV's, OV's and CV's and replace with DV's. Ensure annulus is filled with diesel. 7) 8) 10) 11) Pressure test tubing to 2500 psi to ensure DV's are set. Place 2000 psi on casing while pressure testing to prevent tubing buckling. RIH and pull sr. RDMO Slickline. Prior to initiating water injection, a diesel/xylene spear should proceed to clean up the perforations. Pump 50 bbls of diesel with 10% xylene at 2 BPM. Initiate water injection at approximately 500 BWPD and gradually ramp up the injection rate until the WHP reaches 1500 psi. Keep the injection rate constant until Operations Engineering can perform a step rate test. Once the step rate test is complete, open wells to maximum injection pressure. STATE OF ALASKA AL/-,..,(A OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL E~] GAS F-"] SUSPENDED ~ ABANDONED r'~ SERVICE E~ 2 Name of Operator 7 Permit Number ARCO Alaska, I nc 89-108/9-1094 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20117 4 Location of well at surface COP~ ?LETJ0~,~ T('~ £ ~.i '. '.: :'/~:' 9 unit or Lease Name 194' FNL, 94' FEL, SEC 11, T10N, R8E UM _ DATE ~ ~ ~ KUPARUK RIVER 1469' FSL,898' FWL,SEC 12, T10N, R8E UM V~R~Ft_.ED .~ ~", ........ 2K-18 L At['['(~ 0epth .~c~ - ~, ~ 11 Field and Pool ~-~5' FSL, 906"'FWL, SEC 12, T10N, R8E UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 154'I ADL: 25588 ALK: 2674 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 116 No. of Completions 10/24/89. 11/2/89. 6/15/90.I NA feet MSLI 1 7960' MD & 6581' TVD 7787' MD & 6425' TVD YES [~] NO ~I 1808' feet MDI 1400' APPROX 22 Type Electric or Other Logs Run DIL/SFL/GR/SP/FDC/CN L/CAI_/CBL/GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 170 SX AS II 9 5/8" 36# J-55 SURF 3359' 12-1/4" 1000 SX AS III, 450 SX CLASS G 7" 26# J-55 SURF 7463' 8-1/2" 200 SX CLASS G 5" 18# J-55 7143' 7918' 6" 157 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9.3#, J-55 7143' 7094' 7602' - 7642' W/3-1/8" @ 4 SPF MD 6303' - 6334' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED SEE ATTACHED ADDENDUM 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATI: ,,~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~ ~'~'~ t ~, ~ '~; ~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 7503' 6224' NA KUPARUK C BOTTOM 7510' 6229' KUPARUK A TOP 7550' 6261' KUPARUK A Be'I-rOM 7715, 6391, . 31. LIST OF ATTACHMENTS GYRO, FRAC 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed __t~, ~~~ Title AREA DRILLING ENGINEER Date '"'~/~ ~'/~ {~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pedinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO 011 and Gas Company Well History - Initial Report - Dally Inaffuctlena: Prepare and submit the "lldlild Re~t" on the first Wednesday after a well is spudded or workover operetlona are started, Daily work prior tO sPudcll~ Mmuld be summarized on the form giving inclusive dates only. Distriot ICounty, parish or borough lState ARCO ALASKA INC. I NORTH SLOPE I AK Field ILease or Unit /Well no. KUPARUK RIVER ~NIT J ADL: 25588 ALK: 2674 24-18 Auth. or W,O. no. ITitle AK4311 I COMPLETIONS Operator IARCO W.L ARCO J 55. 8533 Spudded orW,O, begUnspt,Tp IDate 10/24/89 IH°ur 00: 00 IPrt°r statusi, aW'O' Date and depth as of 8:00 a.m. 04/23/90 (12) TD: 7960 PB: 7787 SUPV:DB 04/24/90 (13) TD: 7960 PB: 7787 SUPV:DB 04/25/90 (14) TD: 7960 PB: 7787 SUPV:DB 04/26/90 (15) TD: 7960 PB: 7787 SUPV:DB 04/27/90 (16) TD: 7960 PB: 7787 SUPV:DB The above is corr~ct Signature ~ ~ sFe°er fl~;omcePdruerPeasratJa°r~, sedic~Ir~nbUlti0,On' ~ Drilling. Pages 86 and 87. Complete record for each day reported NORDIC ~1 CIRC & COND MUD 5"@ 7918' MW:10.1 WBM MOVE RIG FROM 2K-17, ACCEPT RIG 1400 4/22/90, ND DRYHOLE TREE, NU BOPE AND TEST TO 3000 PSI, SET WB, PU AND RIH W/BIT/SCRAPPER/3-1/4" DC ON 3-1/2" DP, CIRC OUT ICE PLUG AT 249-265, CeNT RIH TO 2150, CIRC 10.2 BRINE TO MUD, CONT. RIH, TAG CMT AT 7140, CIRC AND COND MUD DAILY:S39,557 CUM:$1,120,851 ETD:S1,120,851 EFC:$1,126,000 LOG W/CBL 5"@ 7918' MW:10.1 NaCl CIRC. & COND MUD, DRILL CMT F/7140-7295, RIH TO LC AT 7791, CIRC, REVERSE CIRC 90 BBL WATER SPACER FOLLOWED BY BRINE, CONT. CIRC UNTIL CLEAN BRINE RETURNS, POH, RU HLS E-LINE, RIH W/ CBL TO 7785, LOG 5" LINER DAILY:S29,374 CUM:$1,150,225 ETD:S1,150,225 EFC:$1,126,000 POH W/DP 5"@ 7918' MW:10.1NaCl CONT. LOGGING W/CBL IN 5" LINER, GOOD BOND, POH, RIH W/ GYRO, POH LOGGING AT 100' STOPS, RD E-LINE, RU & RIH W/ BIT AND SCRAPPER ON DP, TAG TOL AT 7140, REVERSE CIRC, POH, RIH W/ 4-1/8" BIT AND 5" SCRAPPER, TAG BTM AT 7791, REVERSE CIRC, FILTER BRINE, POH DAILY:S48,305 CUM:$1,198,530 ETD:S1,198,530 EFC:$1,126,000 POH W/TIEBACK SETTING TOOL 5"@ 7918' MW:10.1 NeC1 CONT. POH, MU FLUTED MILL, RIH, CIRC & POLISH LINER TIEBACK STEM, POH, MU BAKER TIEBACK PKR, RIH, TAG TeL AT 7140, STING SEALS INTO TIEBACK SLEEVE, VERIFY POSITION, SET DOWN ON PKR TO ENGAGE, PU 10 K LBS, PRESS TEST DP TO 2500 PSI - OK, PRESS TEST CSG/DP ANNULUS TO 1000 PSI - OK, ROTATE SETTING TOOL OUT OF TIEBACK PKR, TEST CSG/LINER TO 2500 PSI - OK, CIRC, POH DAILY:S48,419 CUM:$1,246,949 ETD:S1,246,949 EFC:$1,126,000 RU OTIS SLICKLINE 5"@ 7918' MW:10.1 NaCl POOH W/3-1/2" DP & BAKER SETTING TOOL, RU HLS, MU GUN #1, HLS 3-3/8" CSG GUN 4 SPF, 180 DEG PHASE, ALTERNATING 26 GM DP & 22 GM BH SHOTS, ORIENTED TO 171 DEG CCW FROM HI-SIDE., RIH W/GUN#l, PERF 7622'-7642', ASF & ORIENTATION READS 163 DEG CCW FROM HI-SIDE. RIH W/GUN#2, WON'T ORIENT CORRECTLY, POOH RE-ORIENT RIH W/GUN #2, PERF 7602'-7622', ASF & ORIENTATION READS 168 DEG CCW FROM HI- SIDE, RD HLS, RU & RUN 3-1/2" COMP, MU & TEST SS CONTROL LINE, MU LNDG JT & LANDED TBG, RU OTIS SLICKLINE. DAILY:S44,686 CUM:$1,291,635 ETD:S1,291,635 EFC:$1,126,000 IDate / r.j ~ .... ~,,~,~ Number all dally well hlatO~-forma Page no. las they are prepared for each well. ' J AR3B--459-1-D ARCO (.,,, and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Fillal Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report compietlol~ and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District IC°unty or Parish ARCO ALASKA INC. I NORTH SLOPE Field ILease or Unit KUPARUK RIVER UNIT I ADL: 25588 ALK: 2674 Auth. or W.O. no, ITM AK4311 I COMPLETIONS IAccounting cost center code State IWell no, 2i~[-18 Operator A.R.Co. W,I. ARCO 55.8533 Spudded or W.O. begun Date SPUD 10/24/89 Date and depth as of 8:00 a.m. 04/28/90 (7) TD: 7960 PB: 7787 SUPV:DB Complete record for each day reported NORDIC #1 Iotal number of wells (active or inactive) on this~ pst center prior to plugging and 1 bandonment of this well our IPrior status if a W,O. I 00:00 RIG RELEASED 5"@ 7918' MW:10.1 NaC1 RU SLICKLINE, RIH AND SET SV IN XN NIPPLE, POH, PRESS TBG TO 2500 PSI TO SET PKR, PRESS ANNULUS TO 1000 PSI, BLEED ANNULUS, BLEED TBG TO 1500 PSI, BOLDS, PU & SHEAR PBR, RELAND TBG, RILDS, PRESS TEST ANNULUS TO 2500 PSI, TEST SSSV, BLEED OFF PRESS, RU SLICKLINE, RIH AND PULL SV, POH, RD SLICKLINE, SET BPV, ND BOPE, NU TREE, PULL BPV, SET TP, TEST TREE TO 5000 PSI, PULL TP, REVERSE CIRC 6 BBLS DIESEL INTO ANNULUS, BULLHEAD 2 BBLS DIESEL DOWN TBG, RELEASE RIG AT 1400 4/27/90 DAILY:S148,417 CUM:$1,440,052 ETD:S1;440,052 EFC:$1,126,000 Old TO New TD PB Depth Released rig Date K nd of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, ~PM X length Choke size T.P, C,P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signatu~ ~ Date For form preparatil~nd'distribution, '~ see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively I Page no. as they are prepared for each well, I Dl'~lNon of AtlsnllcRIchfleldCompsny ADDENDUM WELL 2K-18 5/27/90 Frac Kuparuk "A" sand perfs 7607'-7642' 180 deg oriented 171 deg ccw in ten stages as follows. Stage 1: Stage Stage Stage Stage Stage Stage Stage Stage Stage Pmp 100 bbls YF240 Gel water prepad @ 25 bpm 4970-4115 psi 60 bbls YF240 Gel water prepad @ 20bpm 3550-3810 psi 45 bbls YF240 Gel water prepad @ 15 bpm 3305-3670 psi 30 bbls YF240 Gel water prepad @ 10 bpm 3160-3640psi 2:68 bbls slick diesel flush @ 25-23 bbm 4160-3255 psi 3:1300 bbls YF240 GW pad @ 25 bpm 3420-4410 psi 4:101 bbls YF240 w/2 ppg 16/20 Carbolite @ 25 bpm 4410-3990 psi 5:102 bbls YF240w/4 ppg 16/20 Carbolite @ 25 bpm 3990-4083 psi 6:111 bbls YF240 w/6 ppg 16/20 Carbolite @ 25 bpm 4083-3990 psi 7:118 bbls YF240 w/8 ppg 16/20 Carbolite @ 25 bpm 3990-4100 psi 8:76 bbls YF240 w/10 ppg 16/20 Carbolite @ 25 bpm 4100-4260 psi 9:53 bbls YF240 w/12 ppg 16/20 Carbolite @ 25 bpm 4260-4660 psi 10:68 bbls Slick Diesel flush @ 25 bpm 4660-4100 psi Fluid to recover: 2331 bbls Sand in zone: 150,727 lbs Sand in csg: 978 lbs Avg pressure: 4400 psi ~pervisor MICROFILMED GREAT LAND DIRECTIONAL DRILLING, client .... : ARCO ALASKA, INC. Field ..... : Kuparuk River Unit Well ...... : 2K-18 (11-10-8) Section at: S,16,36,E Mag Dcln..: 0,0 E S MEAS INCLN VERTICAL-DEPTHS C DEPTH DEG MN BKB '-~ '.~.EC01~) 02" SURVR¥ ~'~ ..~ SECTION DIRECTION RELATIVE-COORDINATES SUB-SEA DISTNCE DEG MIN FROM-WELL-HEAD Computation...: RADIUS CURVATURE Survey Date...: 05/08/96~ ~ RKB Elevation.: 154.00 f~ Case ID ....... : KRU2K18 i~}~ CLOSURE DL DISTNCE DEG MIN /100 7 100 0 21 100.0 -54.0 7 200 0 5 200.0 46.0 7 300 0 16 300.0 146.0 7 400 0 19 400.0 246.0 7 500 0 8 500.0 346.0 -0.2 N 52 33 W -0.2 S 22 23 W -0.3 N 5 35 E -0.8 N 14 44 W -1.1 S 78 29 W 0.2N 0.1E 0.1N 0.2W 0.2N 0.5W 0.7N 0.5W 0.9N 0.SW 0.2 N 18 44 E 0.35 0.3 N 61 30 W 0.26 0.5 N 67 45 W 0.17 0.8 N 35 56 W 0.05 1:2 N 42 24 W 0.18 7 600 0 15 600.0 446.0 7 700 0 21 700.0 546.0 7 800 0 35 800.0 646.0 7 900 1 27 900.0 746.0 7 1000 3 13 999.9 845.9 7 1'100 4 55 1099.6 945.6 7 1200 8 12 1199.0 1045.0 7 1300 11 30 1297.5 1143.5 7 1400 16 46 1394.4 1240.4 7 1500 20 3 1489.3 1335.3 -1.2 N 52 15 W -1.6 N 63 41 W -1.9 S 74 44 W -1.5 S 43 29 W 1.2 B 21 58 W 6.9 B 16 17 W 16.7 B 12 37 W 31.7 S 11 8 W 53.5 B 9 18 W 82.2 S 6 25 W 0.9N 1.1W 1.2N 1.5W 1.3N 2.3W 0.4N, 3.9W 3.08 6.0W 9.78 8.4W 20.88 ll.2W 37.5S 14.7W 61.5S 19.0W 92.8S 23.4W 1.4 N 49 39 W 0.12 2.0 N 51 51 W 0.10 2.7 N 61 10 W 0.24 3.9 N 84 16 W 0.86 6.7 S 63 28 W 1.76 12.8 B 40 44 W 1.70 23.6 S 28 21 W 3.29 40.3 B 21 26 W 3.30 64.4 S 17 12 W 5.27 95.7 S 14 8 W 3.30 7 1600 23 29 1582.1 1428.1 7 1700 26 31 1672.8 1518.8 7 1800 28 55 1761.3 1607.3 7 1900 33 49 1846.6 1692.6 7 2000 36 16 1928.5 1774.5 117.3 S 1 55 E 158.6 S 6 30 E 204.8 S 16 43 E 256.8 S 19 48 E 314.2 S 17 5 E 129.8 S 24.8 W 171.9 S 21.7 W 217.4 S 12.4 W 266.8 S 3.9 E 321.3 S 22.1 E 132.2 S 10 49 W 3.68 173.3 S 7 12 W 3.16 217.8 S 3 15 W 3.39 266.9 S 0 51 E 4.98 322.0 S 3 56 E 2.64 7 2100 39 52 2007.2 1853.2 7 2200 39 27 2084.2 1930.2 7 2300 38 47 2161.8 .2007.8 375.8 S 18 3 E 439.6 S 17 52 E 502.7 S 17 41 E 380.1 S 40.7 E 440.8 S 60.4 E 500.8 S 79.7 E 382.2 S 6 7 E 3.61 444.9 S 7 48 E 0.42 507.1 S 9 2 E 0.66 *Survey Codes: 7/GYRO 2K-18 (11-10-8) S MEAS INCLN C DEPTH DEG MN 7 2400 39 28 7 2500 42 17 7 2600 41 57 7 2700 41 32 7 2800 40 53 7 2900 40 30 7 3000 40 3 7 3100 39 37 7 3200 38 44 7 3300 38 7 7 3400 37 46 7 3500 38 8 7 3600 38 38 7 3700 38 37 7 3800 38 38 7 3900 38 37 7 4000 38 41 7 4100 38 53 7 4200 38 17 7 4300 38 23 7 4400 38 24 7 45OO 38 29 7 4600 38 23 7 4700 37 58 7 4800 37 57 7 4900 37 41 7 5000 37 44 7 5100 37 35 RECORD OF SURVEY VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE DEG MIN FROM-WELL-HEAD 2239.4 2085.4 565.8 S 19 6 E 560.7 S 99.6 E 2315.0 2161.0 631.1 S 22 17 E 621.9 S 122.7 E 2389.2 2235.2 697.8 S 21 51 E 684.1S 147.9 E 2463.8 2309.8 764.1 S 21 26 E 746.0 S 172.4 E 2539.0 2385.0 829.8 S 21 0 E 807.4 S 196.3 E 2614.8 2460.8 894.8 S 21 1 E 868.2 S 219.7 E 2691.1 2537.1 959.2 S 21 25 E 928.5 S 243.0 E 2767.9 2613.9 1023.1 S 21 13 E 988.2 S 266.3 E 2845.4 2691.4 1086.1 S 18 40 E 1047.6 S 287.9 E 2923.8 2769.8 1148.3 S 16 57 E 1106.7 S 306.9 E 3002.6 2848.6 1209.7 S 18 20 E 1165.3 S 325.5 E 3081.5 2927.5 1271.2 S 17 45 E 1223.8 S 3.44.6 E 3159.9 3005.9 1333.3 S 18 2 E 1282.9 S 363.6 E 3238.0 3084.0 1395.7 S 18 2 E 1342.2 S 383.0 E 3316.1 3162.1 1458.1 S 17 17 E 1401.7 S 401.9 E 3394.3 3240.3 1520.5 S 16 26 E 1461.5 S 420.0 E 3472.4 3318.4 1583.0 S 16 32 E 1521.3 S 437.7 E 3550.3 3396.3 1645.6 S 16 37 E 1581.4 S 455.6 E 3628.5 3474.5 1708.0 S 15 34 E 1641.3 S 472.9 E 3706.9 3552.9 1770.0 S 14 37 E 1701.2 S 489.0 E 3785.3 3631.3 1832.1 S 14 32 E 1761.3 S 504.6 E 3863.6 3709.6 1894.2 S 14 5 E 1821.5 S 520.0 E 3941.9 3787.9 1956.3 S 14 9 E 1881.8 S 535.2 E 4020.6 3866.6 2018.0 S 14 4 E 1941.8 S 550.2 E 4099.4 3945.4 2079.5 S 14 6 E 2001.4 S 565.2 E 4178.4 4024.4 2140.7 S 14 16 E 2060.9 S 580.2 E 4257.5 4103.5 2201.9 S 14 40 E 2120.1 S 595.5 E 4336.7 4182.7 2262.9 S 15 11 E 2179.1 S 611.2 E Page 2 05/08/90 CLOSURE DL DISTNCE DEG MIN /100 569.5 S 10 4 E 0.89 633.9 S 11 10 E 3.16 699.9 S 12 12 E 0.38 - 765.6 S 13 1 E 0.46 830.9 S 13 40 E 0.67 895.6 S 14 12 E 0.39 959.8 S 14 40 E 0.48 1023.4 S 15 5 E 0.45 1086.4 S. 15 22 E 1.32 1148.5 S 15 30 E 0.90 1209.9 S 15 36 E 0.63 1271.4 S 15 43 E 0.44 1333.4 S 15 50 E 0.50 1395.8 S 15 55 E 0.02 t458.2 S 16 0 E 0.29 1520.6 S 16 2 E 0.33 1583.1 S 16 3 E 0.09 1645.7 S 16 4 E 0.19 1708.1 S 16 4 E 0.71 1770.1 S 16 2 E 0.38 1832.2 S 15 59 E 0.03 1894.3 S 15 56 E 0.20 1956.4 S 15 52 E 0.09 2018.2 S 15 49 E 0.43 2079.7 S 15 46 E 0.02 2141.0 S 15 43 E 0.27 2202.2 S 15 41 E 0.15 · 2263.2 S 15 40 E 0.24 'Survey Codes: 7/GYRO 2K-18 (11-10-8) Page 3 05/08/90 S MEAS INCLN C DEPTH DEG MN 7 5200 38 13 7 5300 38 37 7 5400 38 26 7 5500 38 10 7 5600 38 6 7 5700 38 3 7 5800 37 46 7 5900 37 49 7 6000 38 14 7 6100 38 8 7 6200 38 31 7 6300 38 38 7 6400 38 51 7 6500 39 2 7 6600 39 19 7 6700 39 35 7 6800 38 4 7 6900 37 59 7 7000 37 53 7 7100 37 59 7 7200 37 29 7 7300 37 16 7 7400 38 4 7 7500 38 1 7 7600 37 22 7 7700 38 11 7 7785 39 2 7 7787 39 2 RECORD OF SURVEY VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE DEG MIN FROM-WELL-HEAD 4415.6 4261.6 2324.3 S 14 53 E 2238.5 S 627.2 E 4493.9 4339.9 2386.4 S 13 29 E 2298.7 S 642.4 E 4572.2 4418.2 2448.6 S 14 32 E 2359.1 S 657.5 E 4650.7 4496.7 2510.6 S 14 13 E 2419.2 S 672.9 E 4729.3 4575.3 2572.3 S 13 50 E 2479.1 S 687.8 E 4808.0 4654.0 2633.9 S 14 59 E 2538.8 S 703.2 E 4886.9 4732.9 2695.3 S 14 15 E 2598.2 S 718.7 E 4966.0 4812.0 2756.5 S 14 2 E 2657.7 S 733.6 E 5044.8 4890.8 2818.0 S 14 11 E 2717.4 S 748.7 E 5123.4 4969.4 2879.8 S 14 37 E 2777.3 S 764.0 E 5201.8 5047.8 2941.8 S 14 46 E 2837.2 S 7'79.8 E 5280.0 5126.0 3004..1 S 14 46 E 2897.5 S 795.7 E 5358.0 5204.0 3066.6 S 15 14 E 2958.0 S 811.9 E 5435.8 5281.8 3129.5 S 15 10 E 3018.6 S 828.3 E 5513.3 5359.3 3192.6 S 15 10 E 3079.6 S 844.9 E 5590.5 5436.5 3256.1 S 14 52 E 3141.0 S 861.3 E 5668.4 5514.4 3318.8 S 16 53 E 3201.3 S 878.5 E 5747.2 5593.2 3380.4 S 16 30 E 3260.3 S 896.2 E 5826.1 5672.1 3441.9 S 16 34 E 3319.2 S 913.7 E 5904.9 5750.9 3503.4 S 16 48 E 3378.1 S 931.3 E 5984.0 5830.0 3564.6 S 16 18 E 3436.8 S 948.7 E 6063.5 5909.5 3625.3 S 14 55 E 3495.2 S 965.1 E 6142.7 5988.7 3686.3 S 12 35 E 3554.6 S 979.6 E 6221.4 6067.4 3747.6 S 9 13 E 3615.1 S 991.2 E 6300.5 6146.5 3808.0 S 5 51 E 3675.7 S 999.3 E 6379.6 6225.6 3867.6 S 0 55 E 3736.8 S 1002.9 E 6446.0 6292.0 3917.5 S 6 41 W 3789.7 S 1000.2 E 6447.6 6293.6 3918.7 S 6 41 W 3791.0 S 1000.1 E CLOSURE DL DISTNCE DEG MIN /100 2324.7 S 15 39 E 0.63 2386.8 S 15 37 E 0.68 2449.0 S 15 34 E 0.44 2511.0 S 15 33 E 0.29 2572.7 S 15 30 E 0.16 2634.4 S 15 29 E 0.44 2695.8 S 15 28 E 0.40 2757.1 S 15 26 E 0.09 2818.6 S 15 24 E 0.42 2880.4 S 15 23 E 0.19 2942.5 S 15 22 E 0.39 3004.8 S 15 21 E 0.11 3067.4 S 15 21 E 0.29 3130.2 S 15 21 E 0.18 3~93.4 S 15 20 E 0.28 3256.9 S 15 20 E 0.31 3319.6 S 15 21 E 1.71 3381.2 S 15 22 E 0.16 3442.7 S 15 23 E 0.09 3504.1 S 15 25 E 0.13 3565.3 S 15 26 E 0.52 3626.0 S 15 26 E 0.56 3687.1 S 15 24 E 1.19 3748.5 S 15 20 E 1.28 3809.1 S 15 13 E 1.40 3869.0 S 15 1 E 2.05 3919.5 S 14 47 E 3.69 3920.7 S 14 47 E 0.34 ~Survey Codes: 7/GYRO 2K-18 (11-10-8) Page 4 05/08/90 RECORD OF SURVEY S MEAS INCLN C DEPTH DEG MN 7 7918 39 2 7?6O VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE DEG MIN FROM-WELL-HEAD 6549.3 6395.3 3994.5 S 6 41 W 3872.9 S 990.5 E 'Survey Codes: 7/GYRO /lOO CLOSURE DISTNCE DEG MIN 3997.6 S 14 21 E 0.00 2K-18 (11-10-8) Page 5 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 05/08/90 SUBSEA MEA8 BKB MD-TVD VERT DEPTH DEPTH DEPTH DIFF CORRECT 0 154 154 0 0 100 254 254 0 0 200 354 354 0 0 300 454 454 0 0 400 554 554 0 0 5OO 600 700 800 9OO 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 25O0 2600 2700 654 754 854 954 1054 1155 1256 1358 1463 1569 1679 1792 1909 2032 2161 2290 2419 2553 2687 2820 2951 3082 3211 654 0 0 754 0 0 854 0 0 954 0 0 1054 0 0 1154 1 0 1254 2 1 1354 4 2 1454 9 5 1554 15 7 1654 25 10 1754 38 13 1854 55 17 1954 78 23 2054 107 29 2154 136 29 2254 165 29 2354 199 34 2454 233 34 2554 266 33 2654 297 32 2754 328 30 2854 357 29 RELATIVE COORDINATES FROM WELL HEAD 0.26 N 0.18 W 0.09 N 0.35 W 0.44 N 0.45 W 0.87 N 0.64 W 0.87 N 0.94 W 1.08 N 1.32 W 1.31 N 1.92 W 0.98 N 3.05 W 1.05 S 4.96 W 6.27 S 7.25 W 15,03 S 9.81 W 29.39 S 13.07 W 50.34 S 17.13 W 80.43 S 21.88 W 117.87 S 25.19 W 162.77 S 23.00 W 213.85 S 14.88 W 271.46 S 5.66 E 339.55 S 27.64 E 417.00 S 52.78 E 494.82 S 77.86 E 572.36 S 103.07 E 654.58 S 136.28 E 737.70 S 169.71 E 819.47 S 200.93 E 899.44 S 977.32 S 1053.92 S 231.34 E 262.42 E 290.40 E 2K-18 (11-10-8) Page 6 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 05/08/90 SUBSEA MEAS BKB MD-TVD VERT DEPTH DEPTH DEPTH DIFF CORRECT 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 38OO 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 3338 3465 3592 3720 3848 3976 4105 4233 4360 4488 4615 4742 4869 4996 5122 5249 5377 5504 5631 5758 5885 6012 6139 6267 6395 6523 6653 6782 2954 384 27 3054 411 27 3154 438 27 3254 466 28 3354 494 28 3454 522 28 3554 551 28 3654 579 28 3754 606 28 3854 634 28 3954 661 28 4054 688 27 4154 715 27 4254 742 26 4354 768 26 4454 795 27 4554 823 28 4654 850 27 4754 877 27 4854 904 27 4954 931 27 5054 958 27 5154 985 27 5254 1013 28 5354 1041 28 5454 1069 29 5554 1099 29 565.4 1128 29 RELATIVE COORDINATES FROM WELL HEAD 1129.61 1203.02 1278.60 1354.25 1430.29 312.83 E 338.74 E 361.60 E 387.26 E 411.81 E 1507.30 1584.18 1660.46 1737.27 1813.77 433.34 E 456.57 E 479.13 E 498.56 E 519.48 E 1891 ' 07 S 1967.09 S 2042.68 S 2117.82 S 2191.97 8 537.54 E 55'6.53 E 575.14 E 593.38 E 614.98 E 2266.93 S 2345.85 S 2421.69 S 2498.16 S 2572.88 S 637.59 E 650.39 E 673.58 E 690.84 E 714.29 E 2648.42 S 2724.51 S 2800.67 S 2877.46 S 2955.48 S 732.25 E 750.20 E 769.84 E 790.41 E 808.55 E 3032.92 S 3111.60 S 3191.88 S 832.21 E 854.49 E 865.21 E 2K-18 (11-10-8) Page 7 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 05/08/90 SUBSEA MEAS BKB MD-TVD VERT DEPTH DEPTH DEPTH DIFF CORRECT 5600 5700 5800 5900 6000 6100 6200 6300 6909 7035 7162 7288 7414 7541 7668 7795 5754 1155 27 5854 1181 27 5954 1208 27 6054 1234 26 6154 1260 26 6254 1287 27 6354 1314 26 6454 1341 28 RELATIVE COORDINATES FROM WELL HEAD 3265.37 3340.19 3413.95 3485.36 3561.79 897.65 E 919.36 E 944.12 E 970.65 E 984.40 E 3636.51 3707.23 3796.18 1003.69 E 1022.65 E 999.45 E 2K-18 (11-10-8) Page 8 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL o5/o8/9o MEAS BKB SUBSEA DEPTH DEPTH DEPTH RELATIVE COORDINATES FROM WELL HEAD 6000 5045 4891 2717.39 S 748.67 E 7000 5826 5672 3319.21 S 913.66 E 1000 1000 846 3.01 S 6.04 W 2000 1929 1775 321.28 S 22.10 E 3000 2691 2537 928.51 S 243.05 E 4000 3472 3318 1521.34 S 437.71 E 5000 4258 4104 2120.10 S 595.51 E GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. 05/08/90 Client .... : ARCO ALASKA, INC. Field ..... : Kuparuk River Unit Well ...... : 2K-18 (11-10-8) Section at: S,16,36,E Mag Dcln..: 0,0 E Computation...: RADIUS OF CURVATURE Survey Date...: 05/08/90 RKB Elevation.: 154.00 ft Case ID ....... : KRU2K18 INTERPOLATED MARKERS REPORT Surface Location: 194 SNL 94 WEL Sll T10N RSE MARKER IDENTIFICATION RKB 9-5/8" CASING 5" LINER TOP 7" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD 5" LINER BOTTOM MEAS INCLN DEPTH DEG MN 0 0 0 3359 37 54 7134 37 49 7463 38 2 7503 38 0 VERT-DEPTHS SECT BKB SUB-S DIST 0 -154 2970 2816 5932 5778 6192 6038 6224 6070 DIRECTION REL-COORDINATES DEG MIN FROM-WELLHEAD 7510 37 57 6229 6075 7550 37 42 6261 6107 77157 58 20 63917 6237 7787- 39 2 644~ 6294 -7~7 ~39 2 6448 6294 7918 39 2 6549 6395 0 N 90 0 E 1185 S 17 46 E 3524 S 16 38 E 3725 S 10 28 E 3749 S 9 7 E 0 N 0 E 1141 S 318 E 3398 S 937 E 3593 S 987 E 3617 S 992 E 3754 S 8 52 E 3778 S 7 32 E 3876 S 0 25 W 3919 S 6 41 W 3919 S 6 41 W 3994 S 6 41 W 3621 S 992 E 3645 S 996 E 3746 S%~1003 E ~ 3791 SI- 1000 E ~' 3791 S 1000 E 3873 S 990 E Sre t L Birection I ZTnilling, £nc. <KB>O F ..... 400 800 1200 ",600 ~---.i ................... 2000 2400 2800 3200 3600 4000 4400 4800 F ...... 5200 5600 6000 6400 6800 7200 400 VERTICAL SECTION VIEW ARCO ALASKA, INC. 2K-18 (11-10-8) Section at: S 16 36 E TVD Scale.: 1 inch = 800 feet Dep Scale.: 1 inch : 800 feet Dpawn ..... : 05/08/g0 Marker Identification MD TVD DEPRT INCLN A) RKB 0 0 0 0.00 B) 9-5/80 CASING 3359 2970 tt85 37.9t C) 5" LINER TOP 7t34 5932 3524 37.8t D) 7" CASING 7463 6t92 3725 38.03 ~ TOP KUPARUK C 7503 6224 3749 38.00 F) BASE KUPARUK C 7510 6229 3754 37.96 G) TOP KUPARUK A 7550 626! 3778 37.70 H) BASE KUPARUK A 77t5 6391 3876 38.33 I) TD 7787 6448 39t9 39.03 J) PBTD 7787 6448 3919 39.03 K) TD EXTRAPOLATED 79t8 6549 3994 39.03 0 400 800 1200 t600 2000 Departure 2400 2800 3200 3600 4000 4400 ~rsat Aan~ D/rs£t/onal 9r/ll/n~ Z~c. Marker Identification MD N?S E/W A) RKB 0 0 N 0 E 8] 9-5/8' CASING 3359 tt4t S 3t8 E C) 5' LINER TOP 7t34 3398 S 937 E D) 7' CASING 7463 3593 S 987 E ~ TOP KUPARUK C 7503 36t7 S 992 E F) BASE KUPARUK C 75t0 3621 S 992 E G) TOP KUPARUK A 7550 3645 S 996 E H) BASE KUPARUK A 77t5 3746 S t003 E I)PBTD 7787 379t S iO00 E J)TO 7787 379t S iO00 E K)TD EXTRAPOLATED 79t8 3873 S 990 E L)5' LINER BOTTOH 79t8 3873 S 990 E PLAN VIEW ARCO ALASKA, INC. 2K-18 CLOSURE .....: 3998 ft$ 14 21E DECLINATION.: 0,0 E SCALE .......: 1 inch = 600 feet DRANN .......: 05/08/90 300 0 300 6O0 9OO t200 1500 1BO0 2100 2400 2700 3000 3300 3600 3900 i800 t500 t200 900 600 600 900 300 0 300 <- NEST ' EAST -> t200 t500 iBO0 .. COMPLETION DATE WELL NAME /e,~ CO. CONTA£T AOGCC GEOLOGICAL MATERIA'~ INVENTORY LIST ( check off or list data as it is re~ived ~ 407' ! ~'/~ "~'""//~ drilling] histon/ ~ survey I,/1~ well tests I core desription cored intervals core analysis d~ ditch inte~als digital data '" , , ~~, ~~ . LOG 'IYPE ' RUN INTEl:O/ALS . SCAIF NO. 2) ~ ,, ~,, _- C~' ," m ' Cx~,. I..~ / 7~' '- 7~ ~~ ' 13] 16] ,, 18} 1~1 ARCO Alaska, Inc. Date: May 18, 1990 Transmittal#: 7762 '"~"~7°~/~/~,/O~, RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 1 9 Pulse Echo Cement Evaluation PET 4 - 3 0 - 9 0 81 0 0 - 1 0 4 6 6 2 K - 1 8 Acoustic Cement Bond Log 4 - 2 4 - 9 0 71 0 0 - 7 7 8 0 2 K - 0 9 Acoustic Cement Bond Log 4 - 6 - 9 0 5 9 5 6 o 6 70 7 2K-09 Collar Log 4-8- 90 6000-6685 Receipt AcknoWledged: ..... ~Date- DISTRIBUTION: Drilling NSK state of AlaSk~(+Sepia) . , :. STATE OF ALASKA A~ OIL AND ~ CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 99510 5. Type of Well: Development Exploratory Stratigraphic Service Operation Shutdown ~ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska,, Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 194' FNL, 94' FEL, Sec. 11, T10N, R8E, UM At top of productive interval 1467' FSL, 949' FWL, Sec. 12, T10N, R8E, UM (approx) At effective depth 1293' FSL, 1004' FWL, Sec. 12, T10N, R8E, UM (approx) At total depth 1191' FSL, 1036' FWL, Sec. 12,T10N, R8E, UM (approx) 12. Present well condition summary Total Depth: 7960' feet Plugs (measured) 6560' feet None feet RKB 154' 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-1~ measured (approx) true vertical 7787' feet Junk (measured) 64 25' feet None Effective depth: measured (approx) true vertical Size Cemented 16" 9 5/8" 1100 Sx AS III & 450 Sx Class G 7" 250 Sx Class G 5" 157 Sx Class G None Casing Length Structural 8 0' Conductor Surface 33 24' Intermediate Production 74 30' Liner 784' Perforation depth: measured true vertical 9. Permit number 89-10~ 10. APl number 50-103-20117 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool Measured depth True vertical depth 115' 115' 3359 2743' (approx) 7463' 6171' (approx) 7134'-7918' 5919'-6527' (approx) R.. CEIVED Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Attachments Description summary of proposal _ Detailed operation program ~[ BOP sketch _ 15. Date approved Status of well classification as: Oil .X Gas ~ Suspended Service 14. Estimated date for commencing operation February, 1990 16. If proposal was verbally approved Date Name of approver 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~ ~ ~;~%.~ Title Area Drilling Engineer ~ FOR COMMISSION USE ONLY Commissioner JApproval No. I Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test_ Location clearance ~ Mechanical Integrity Test_ Subsequent form require ~JlIGiNAL SIGNED 9Y LONNIE C. Slv'/ITH Approved by the order of the Commission SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 ARCO Oil and Gas Company Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to Spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. KUPARUK RIVER FIELD lCounty, parish or borough NORTH SLOPE Lease or Unit ADL: 25588 ALK: 2674 Title DRILLING State IWell no, Field 2K-18 Auth, or W.O. no, AK4311 Operator ARCO Spudded or W.O. begun IDate Hour SPUD I 10/24/89 05:00 ARCO w.I. 55.8533 Pr or status if a W,O, Date and depth as of 8:00 a.m. 10/24/89 (1) TD: 215'( 215 SUPV:CD 10/25/89 ( 2) TD: 2840'( 2625 SUPV:CD 10/26/89 ( 3) TD: 3379'( 539 SUPV:SC 10/27/89 ( 4) TD: 4786'( 1407 SUPV:SC 10/28/89 (5) TD: 7276'( 2490 SUPV:SC 10/29/89 (6) TD: 7484'( 2081 SUPV:SC 10/30/89 ( 7) TD: 7484' ( 01 SUPV:SC 10/31/89 (8) TD: 7531' ( 47] SUPV: SC Complete record for each day reported DOYEN 14 DRLG MW: 0.0 VIS: 0 MOVED RIG F/ 2K16, 2100HRS TO 2400HRS 10/23/89, ACCEPTED RIG AT 0001HRS 10/24 NU DIVERTER, PU BHA, TESTED DIVERTER, OK, DRLG F/ 115 T/ 215. DAILY:S42,870 CUM:$42,870 ETD:S42,870 EFC:$1,308,000 DRLG F/2840 MW: 9.1VlS:106 DRLG TO KOP @ 850, KICK OFF W/ 1.5 BH STEERABLE MOTOR, DRLG AHEAD T/ 2840. DAILY:S55,521 CUM:$98,391 ETD:S98,391 EFC:$1,308,000 L.D. LANDING JT. 9-5/8"@ 3359' MW: 9.6 VIS: 96 DRLG F/ 2840 T/ 3379, POOH, RIH W/ HOLE OPENER, POOH, RAN 86 JTS. 9 5/8 - 36# - J55 - BTC CASING, CIRC, CMT W/ 1000 SX ASIII & 450 SX CLASS G DAILY:S52,738 CUM:$151,129 ETD:S151,129 EFC:$1,308,000 DRLG F/4786 9-5/8"@ 3359' MW: 9.2 VIS: 32 FINISH CMT TOP JOB, NU BOPE TEST SAME,OK, PU BHA, RIH, DRLG CMT SHOE, PERFORM LEAK OFF TEST, OK, C 0 MWD, RIH, DRLG F/3379 T/4786 DAILY:S124,812 CUM:$275,941 ETD:S275,941 EFC:$1,308,000 POOH 9-5/8"@ 3359' MW:10.1 VIS: 39 DRLG T/7276, POOH (SUSPECT BIT DAMAGE) DAILY:S76,067 CUM:$352,008 ETD:S352,008 EFC:$1,308,000 POOH 9-5/8"@ 3359' MW: 9.8 VIS: 38 POOH, C.O. BHA, RIH T/ SHOE, LEAK OFF TEST, RIH, DRLG TO CAP @ 7484', CIRC, LOWER WT. TO 9.8, SHORT TRIP, TIGHT HOLE, POOH LDDP T/ RUN 7"CSG. DAILY:S72,721 CUM:$424,729 ETD:S424,729 EFC:$1,308,000 TEST BOPE 7"@ 7463' MW: 9.8 VIS: 39 LDDP & BHA, RUN 190 JTS 7"-26#-J55-BTC CSG, CMT W/ 200 SX CLAS G, LOST RETURNS,BUMPED PLG CUT 7", NU BOPE, PU BHA, TEST BOPE T/3000#. DAILY:S168,387 CUM:$593,116 ETD:S593,116 EFC:$1,308,000 DRLG F/7531 7"@ 7463' MW:10.1 VIS: 34 PU BHA, RIH PU DP, DRLG FLOATS,TEST SHOE 10.9 EMW, DRLG 10' NEW HOLE, TEST FORMATION T/ 10.9 EMW, DRLG DAILY:S57,349 CUM:$650,465 ETD:S650,465 EFC:$1,308,000 The above is correct Sign~ ~ For form prepara~ an~l distributio ,~"" see Procedures ~ual, Section 10. Drilling, Pages 86 and 87. AR3B-459-1-D ,11 dally well histor7 forms consecutively are prepared for each well. Page no. ARCO Oil ana Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing1 conng, or perlorahng, show fo~malien name in descnbinr~ work perlormed. Number ail drill stem tests sequentially. Attach description of ali cores Work performed by Producing Section wdl be reported on "Interim" '~hrJets until final completion. Report official or representative test on "Final" form. 1) Submit "lnlerim" sheets when filled ou~ DUl not less frequently than e,,ery 30 days, or (2) On Wednesday of the week in which oil string is set, Submit weekly for workovers and following setting of oil strinG until completion. District Field ARCO ALASKA INC. County or Parish NORTH SLOPE ILease or Unit ADL: 25588 ALK: 2674 KUPARUK RIVER FIELD 2K-18 IWell no Date and depth as of 8:00 a.m. 11/01/89 ( 9) TD: 7795'( 2( SUPV:SC 11/02/89 (10) TD: 7960'( SUPV:CD 11/03/89 (11) TD: 7787'( SUPV:CD The above is correct Signature.~~, ~ For form preparati~ ~d distribution see Procedures Ma~l Section 10, Drilling, Pages 86 and 87 Complete record for each day while drilling or workover in progress DOYEN 14 DRLG F/ 7795 7"@ 7463' MW:10.1 VIS: 36 DRLG, POOH, ADD 6 DCS, CHANGE BIT, RIH, DRLG F/7531 T/7795. SLIPPED DRLG LINE DAILY:S63,939 CUM:$714,404 ETD:S714,404 EFC:$1,308,000 TIH F/ WIPER RUN 7"@ 7463' MW:10.1 VIS: 40 DRLG TO TD @ 7960, CIRC, SHORT TRIP, POOH TO LOG, SLM -NO CORR.,LOG, MU BHA, RIH F/ WIPER TRIP. DAILY:S148,468 CUM:$862,872 ETD:S862,872 EFC:$1,308,000 DRLG .CMT TO TOP OF LINER 5"@ 7918' MW:10.1 VIS: 39 TIH & CIRC., POOH,RUN 5"LINER, (18#, LB0, LTC), CMT W/ 157 SX CLASS G POOH, PU BHA, RIH, TAG CMT @ 6740', DRLG CMT TO TOP OF LINER @ 7143 DAILY:S152,117 CUM:$1,014,989 ETD:S1,014,989 EFC:$1,308,000 AR3B-459-2-B Number all daily well history forms consecutlw;ly as they are prepared for each well Page no ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Pluqgod, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time, On w~)rkovers when an official test is not required upon completion, report completion and representative test data in blocks provided The "Final Report" form may be used for reporting the entire operation if space is ava~iab~e. Accounting cost center code District ICounty or Parish ARCO ALASKA INC. NORTH SLOPE Field Lease or Unit I Well no KU?ARUK RIVER FIELD I ADL: 25588 ALK: 2674 2K-18 Auth. or W.O. no. ITitle AK4311 J DRILLING Operator AR,Co. W.I. [Total number of wells (active or inactive) on this ARCO 55. 8553 Icost center prior to plugging and J abandonment of this well Spudded or W.O, begun Date IHour I Prior status if a W,O. SPUD 10/24/89 / 05: 00 I Date and depth as of 8:00 a.m. Cid TD 11/04/89 (12) TD: 7787 PB: 7787 SUPV:CD Released rig Complete record for each day reported DOYON 14 RIG RELEASED @ 2130 HRS 5"@ 7918' MW:10.1NaC1 CIRC. & COND. MUD @ TOP OF LINER,(7142'),TEST LINER LAP TO 1000 PSI, POOH DISP MUD W/ BRINE FROM 2000', LDDP, ND BOPE, INJ DIESEL, RIG RELEASED 2130 HRS, 11/3/89 DAILY:S66,305 CUM:$1,081,294 ETD:S1,081,294 EFC:$1,308,000 INew TD Date JPB Depth Kind of rig Classifications (oil, gas, etc.) I Type completion (single. dual elc.) Producing method I Official reservoir name(s) I Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production · Oil on test Gas per day Pump si~,e, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form prepar~fio.¢ and distribution, see Procedures M.e~ual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily wall history forms consecutively I Page no. as hey are prepared for each well. J I Dlvl~on of AtlantlcRichfleldCompany ARCO Alaska, Inc. Date: December 6, 1989 Transmittal Ct: 7619 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 1 8 OH Edit Tape and Listing 1 2 - 1 - 8 9 Ct 7 3 5 3 4 (Replace tape sent 11-15-89) Receipt Acknowledged' DISTRIBUTION: Lynn Goettinger State of Alaska AD~]LTIONAL TAPES TO:* A}~CO-ANCH: ANO- 11 ! 9 CEEVRON'SAN RAHONE,CA ~qDBiL: DALLAS, TX i~P: ANCH UNUCAL 'ANCH 11/30/89 SCHLUMBERGER WELL SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE,.ALASKA 99518 COMPANY · ARCO ALASKA, INC. LOCATION · AT O- 1 1 1 9 ATTENTION · KUPARUK RECORDS CLERK X COMPUTING CENTER PRINT CENTER WELL NAME · 2K-15 (REDO) SERVICES · 2 OH LIS TAPES WELL NAME · SERVICES · NO. OF BOXES' 0 N E JOB NO. ·7 3 5 3 4 ADD'LTAPES ·*SEE ABOVE ';PLEASE NOTE' WELL NAME · SERVICES ' THESE TAPES REPLACE ON THE OLD' TAPES'.,~~ THE ONES NO. OF BOXES: JOB NO. · ADD'L TAPES · SENT '11/'15/89, WELL NAME · SERVICES · THERE WAS A PROBLEM NO. OF BOXES: JOB NO. · ADD'L TAPES ' NO. OF BOXES: JOB NO. · ADD'L TAPES · WELL NAME · SERVICES ' NO. OF BOXES: JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER:-'-' /'~/?/'~' DATE DELIVERED: WELL NAME · SERVICES · NO. OF BOXES: JOB NO. : ADD'L TAPES : '. / Y~ ARCO Alaska, inc. Date' November 20, 1989 Transmittal #: 7609 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 1 8 OH Edit Tape and Listing 1 1 - 0 1 - 8 9 # 7 3 5 3 4 Receipt Acknowledged' - Date' DISTRIBUTION: Lynn Goettinger State of Alaska RECEIVED NOV22],989 /~lasl~ 0ii & Gas Cons. Anchorage ARCO Alaska, Inc. Date: November 13, 1989 Transmittal #: 7600 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2K-18 NFD-Raw Data 1 1-1-89 7453-7914 2K-18 NFD-Porosity 1 1-1-89 7453-7914 2 K- 1 8 2" Dual Induction- SFL 1 1 - 1 - 8 9 9 90 - 79 3 8 2K-1 8 5" Dual Induction- SFL 1 1 - 1 -89 7488-7804 2K-18 Cyberlook 1 1 -1-89 990-7938 Receipt Acknowledged: DISTRIBUTION: D&M Drilling L---'/Alaska Oil & Gas Cons. Cot~isstO ', Anchorage Franzen Vendor Package(Johnson) NSK State of Alaska(+Sepia) __D~._C-o8-'~9 t~: 1~ ~vo~ ~I~ 1~ TEL BOP~ las~U~ Report ~3~ P01 LOoeU~ns ha . :. T Prlg :~ _ . ,,,,, Lo~fl~en (oen.ral) ..... , General houIek.p~ng ,, .... lug (,,. ii m -.-,,, patg Prell If1~f olooure Pit pup Get deho~orl Vt ll/l 7 Aud? o :- --- IIII --r ~ ii _ ' _1 ui iii ...... I I . ' _ _ -- i L-- ' i . . 1~ - -i! __ N ............. pltO d. L ........... '~ - . "' Controll; ~Bib~ ................. ii i Illll . ~ Ass..: _ B1 tnd lwftoh oovsr..___._ .KE~. Y_ ~ r'l. O01! Annulet preventer ...... Mpa remt lltnd fps 11I c~ke IJ ne vol ~m HCR valve N(1) lln~ vmlv. Cheek volvo Tilt Pressure i I _ ~ mi I .... i ..... ____._ LI_ i I Ii1 iii -- _ II i Upper blly ~ Tole pressure _. ..... i i ii .... i1 iiii ..... RECEIVED __ d,;, DEC, · i _ iii - .......... " - -~1 i i ii i III I ii II iiii, , · mi : Ortg - Agg e - Operm~ M EMOR. I dM stat of Alaska ALASKA OIL AN~' CONSERVATION COMMISSION TO: Lonnie C. Smit~~' DATE: November 1, 1989 C~issioner ['- O F, tE NO- D. BDF. 117 TELEPHONE NO: Sr. PetrOleum Engineer FROM: ~obby D. Fos~ee~~-' ..... ' Petroleum Inspedte~- BOP Test AAI KRU 2K Permit No. 89-108 Kuparuk Rv ~ The BOP test on Doyon rig ~14 began at am was conc 12:45 pm. As the attached BOP test report shows there were' no . The kill line contains threaded connections:and'I requested t at these be removed as soon as ial coUld be . ~r. CamarO, AAI rep and Mr.i'~paulding, rep., both to this request. Attachment Q2-O01A (Rev. 8/85) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report ! Location (general) General housekeeping Reserve pi t MUD SYSTEMS: Visual Audio Trip tank / i Pit gauge ~ I Flow monitor / .I Gas detectors ~/ I DATE Representative ACCUMULATOR SYSTEM: Full charge pressure ~~ g Pump incr c]os press 200 psig ~ Fu]3 cha~ge p~ess a~ained ~ Controls: Master ~ ~ / Remote ~,~ B]ind switch KELLY AND FLOOR SAFETY VALVES: Upper Kelly, , BOPE STACK: Test Pressure Lower Kelly , Annular preventer ~.~0/ ~)~0 Ball type Pipe rams ~/~~ Inside BOP Blind rams (~)//,~r"g) Choke manifold Choke 1 i ne val yes d~ Number val yes / Kill line valves .m ~ Adjustable chokes Check valve ~ Hydraulically operated choke ft psig psig min x~ / sec min /~ sec psig cover~' Test pressure .~/3~g~ ~ TeSt pressure ~;/~'-g) Test pressure ~/~~ TEST RESULTS: Failures Test time , 7~ /~/d~ Repair or replacement of failed equipment to be made within ~-' days and Inspector/Commission office notified. Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 03/17/89) Inspecto~ ~ October 19, 1989 Telecopy: (907)276-7542 P. J. Archey Area Drilling Engineer AIICO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 2K-18 ARCO Alaska, InC. Permit No. 89-108 Sur. Loc. 194'FN~L, 94'FEL, Sec. 11, T10N, R8E, UM. Btmhole LoC. l147'FSL, l155'FWL, Sec. 12, T10N, RSE, UM. Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permit~ required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. VpryA gru~y/y~u~,/ ~ C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~R~ISSiON dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of EnviropJaental Conservation w/o encl. STATE OF ALASKA ALAL,,4~, OIL AND GAS CONSERVATION COMMI,S,~,ON PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill X Redrill -- I lb. Type of Well Exploratory __ Stratigraphic Test ~ Development Oil .~X Re-Entry __ Deepen mI Service m Development Gas __ Single Zone ~ Multiple Zone 12.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 154, Pad 118' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25588 ALK 2674 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 194' FNL, 94' FEL, Sec. 11, T10N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1320' FSL, 1100' FWL, Sec. 12, T10N, R8E, UM 2K-18 #U630610 At total depth 9. Approximate spud date Amount 1147' FSL, 1155' FWL, Sec 12, T10N, R8E, UM 11-10-89 $200,000 , 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) properly line 2K- 1 6 7960' MD 1147' @ TD feet 50' at SURFACE' feet 2560 6510 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 900'feet Maximum hole angle 40 o Maximum surface 1 618 psig At total depth (TVD) 341 9 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling! Length lVD TVD IVD TVD linclude stage data/ 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 1 15' +200 CF 12.25 9.625 36.0# J-55 BTC 3262' 35' 35' 3297' 2942' 1000 Sx AS III & HF-ERV 450 Sx Class G 8.5 7" 26.0# J-55 BTC 7926' 34' 34' 7960' 6510' 200SxClassG HF-ERV Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth itu°rrfnUa;ii;°alR E C E! V E D Intermediate OCT 1 1 1989 Liner Perforation depth: measured A/aska 0il & Gas Cons, C0mml~.ll true vertical Anchorage 20. Attachments Filing fee X~ Property plat m BOP Sketch ~ Diverter Sketch ~ Drilling program Drilling fluid program ~ Time vs depth plot __ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ "~', ~ Title Area Drilling Encjineer Date ~ Commission Use Only Permit Number I APl number I Approval date ~.0/1~9/8~ See cover letter for t'~'-' v/O ~' 50- /'(') ._'~ '- ~ (~ /"/~ other re(]uirements Conc~tiohs of approval Samples required ~Y e s ,,~ N o Mud log required~ Ye s ~('N o Hydrogen sulfide measures~ Yes ,~N o Directional survey required ~Yes ~ N o Required working pressur_~efor DOPE _.~; . ~ 3 M; ~ 5M' ~ 1 0M' ~ 1 5 M Approved by ~ */. { r Commissioner the commission Date Form 10-401 Rev. 7-24-89 ,/ / ~licate HO~ ZONTAL ..... PROJECT I ON SCALE 1 IN. - 1000 FEET ARGO ALASKA. !ne. Ped 2K. Well Not 18 Proposed Kupnruk Field. North Slope. Al 8URFACE LOCA!'; ON, 194' FNLo 94! FEL SEC. I1. TI OIi. R8E WEST-EAST 1000 0 1 000 2000 I I I 3000 1000 2000 3000 4000 TARGET CENTER TVD-6294 THD-?677 DEP-395! SOUTH 3756 EAST 1~94 TARGET LOCATION' 1320' FSL, llO0' FWL SEC. 12, TION. RSE TD LOCATION, 1147' FSL. 1155' SEC. 12. TION. RSE DEG (TO RECEIVED OCT 1 1 ]989 I~/asJ~ Oil & Gas Cons. Commission Anchorage ......................................................................KuperukP°dAROO2K*iAI'ASK:A*Fleld,Wel I No :[no,~ .................................................. Northt 18 Propooedsiope, Aleoke 0 .~. RKB ELEVAT[ONt 154' ~ 1000._ KOP TVD=900 TMD=900 DEP=O ....... 3 .................. BUILD' 3 DEe g PER 1 co FT IS B/ PERMAFROST TVD=1424 TMD=1431 DEP=73 21 T~ UONU SNDS TVD=1544 TMD=1557 DEP=112 27' 39 EOC TVD=2129 TMD=2255 DEP-448 T/ W SAK SNDS TVD-2164 TMD=2281 DEP-477 3000 _ 4000_ 5000 _ 6000 _ 7000 ,,, B/ W SAK SNDS TVD-2742 THD-3036 DEP-964 9 5/8" CSG PT TVDm2942 THD=3297 DEpm1132 K-lO ~?TVD=3190 TMD=3621 DEP=1340 i K-5 TVD=4611 THD=5478 DEP=2535 AVERAGE ANGLE 40 DE G 4 T/ ZONE C TVD=619¢ F~0=7547 DEP=3867 T/ ZONE A TVD=6230 T71D=7594 TARGET CNTR TVD=6294 TMD=7677 DEP=,. B/ KUP SNDS TVD=r~.7':~F THD=7760 DEP=4004 TD (LOG PT) TVD=;;i:?:~ 7HD=7960 DEP=4132 I ! 0 1 000 ..:'.:: © 0 ,.3000 I I 4000 5000 <::::~::"[ CAL SECTION 150 200 350 400 450 350 300 250 200 1 50 I I I I I . I I I -" 1700 /° 1500 100 50 / 1 900 I I / / / / I / / / 2100 ..... 5O0 \ \ I 100 0 50 1700 \ \ \ 0 _ 250 , I _ DRILLING FLUID PROGRAM (2K-18) Spud to 9-5/8"' Drill out to surface casing weight UD Density 8.8-9.0 8.7-9.2 PV 1 5-30 5- 1 5 YP 20-40 8-12 Viscosity 70-80 35-40 Initial Gel 5-15 2-4 10 Minute Gel 15-30 4-8 APl Filtrate 10-15 10-20 pH 9- 1 0 9.5-10.5 % Solids 10 +/- 4-7 Weight up to TD 10.1 11-16 8-12 35-50 3-5 5-12 6 9.0-10.5 12-15 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator. (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes' Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 12.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The closest well to 2K-18 is 2K-16. This well is 50' away at surface which would be the closest point. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4} Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) 'Drill 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casing. Pressure test to 3500 psig. 11) Downsqueeze Arctic pack' and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21} Secure well and release rig. 22) Fracture stimulate. MUD CLEANER SHALE SHAKERS STI STIR STIR TYPICAL MUD SYSTEM SCHEMATIC KUPARUK RIVER UNIT 20'-' DIVERTER SCHEMATIC DESCRIPTION 1. 16' CONDUCTOR 2. FMC SLIP~::)N WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16' 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/10° OUTLETS 5. 10" HCR BALL VALVES W/10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTEi~ VALVES CAN BE REMO~_LY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20' 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25,035(b) MAINTENANCE & OPERATION 2 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG 4/26/88 6 5 | l 4 13 5/8" 5000 BOP STACK 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 REGULATOFL 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WiTH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLO~ING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL 2. CHECK THAT ALL HOlD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCKq:X:)WN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO~ PSI AND HOLD ~ 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 6. TEST TO 250 PSI AND 3(X)O PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, UNES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BUND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES 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 3(X)O PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATK)N ON BLOWC~T PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TESTONCE A WEEKAND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16' - 2(XX) PSI STARTING HEAD 2. 11' - 3000 PSI CASING HEAD 3. 11 ' - 3(X)0 PSI X 13~/8' - 5000 PSI SPACER SPCX3L 4. 13-5/8' - 5000 PSI PIPE RAMS 5. 136/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL ENES 6. 1~5/8'-5000 PSI DOUBLE RAMW/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR SRE 8/2~89 DOYON 14 ARCO Alaska, Inc. Post Office Box ^nchol'age, Alaska 99510-0360 l'elephone 907 276 12'15 December 12, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- Conductor As-Built Location Plat- 2K Pad (Wells I - 24) Dear Mr. Chatteron' Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4618. Sincerely, If you have D. Martin Engineering Aide DM:hf Enclosure RECEIVED DECl 1988 Alaska Oil & (,las Cons. Commission Anchorage GRU13/010 ARCO Ala,~kn, Inc. is N.TS. SECTION SECTION I I WELLS 1-12 ARE LOCATED IN SECTION 2, T lO N., R. 8 E., UMIAT MERIDIAN. WELLS 13'24 ARE LOCATED IN SECTION II,T. ION., R. 8 E., UMIAT MERIDIAN. SECTION I FWOTRACTED SECTION CORNER Notes: VICINITY MAP I. COORDINATES ARE A.S. IR. ZONE 4. T ION SECTION ALL DISTANCES SHOWN ARE TRUE. ELEVATIONS ARE B.P,M.S.L. RECEIVED DEC; 1 [J 1988 4. O.G. ELEVATIONS FROM CEO- RlXX-$$11, rev4. 5. HORIZONTAL POSITION BASED ON 2-K CONTROL MONUMENTS PER LDUNSBURY & ASSOCIATES. 6. REFERENCE FIELD BOOK: L88-40, pgs. 55,56, 58,59, 65 I~ 66. Wel ASP's Alas¥ a uti & ~.;~s ~;ui,~.. t;.0,'T~m;~,c:u:: Dist. Dist. O.G. Pod .... No. 'Y' 'X' L~;'~dli)J~ LONGITUDE F.S.L. F.E.L. Elev. Elev. I 5,938,600.18 498,310.17 70014'36.519" 150°00'49.i53" 2~6' 94' 114.0 118.5 2 5,93,8,575.14 498,310.28 70° 14' .:7,6.273" 150°00'49.150" 271' 11:5.9 3 5,938,550.:50 498,310.35 70° 14-' :36.029" 150°00'49.128'' 246' 113.8 4 5,9:58,525.46 498,310.06 70o14' 35.784" 150°00'49.136" 222' 113.8 5 5,938,500.19 498,310.1Z 70°14' 35.536" 150°00'49.154'' 196' 113.8 6 5,958,475.14 498,:510.33 70014'35.289" 150°00'49.128'' 171' 113.8 7 5,938,450.36 498,310.36 70014' 35.046" 1.50°00'49.127'' 146' 113,.8 1 ii ii 8 5,938,425.30 498,310.18 70o14, 54.799 150°00'49'132"7 121' 113.8 9 5,938,400.3,0 498,309.98 70°1 34.555" 150°00'49.135, 96' 113.8 I0 5,958,375.19 498,510.14 70014'34.$06'' 150°00'49. I$ 71' 113.9 t I 5,938,350.22 498,310.14 70°14'34.061 " 150°00'49.133'' 46' 113.9 'I 12 5,938,.525.20 498,310.t7 70°14' 35.815'' 150 °00'49. t$1'' 21' 94' 115.9 118.5 FN.L. 13 5,958,235.31 498,310.$7 70°14'32.930" 150°00'49.125'' 69' 94' 113.7 118.5 14 5,938,210.14 498,310. t6 70o14'32.685" 150°00'49.151" 94' 113.7 15 5,938,185.12 498,310.16 70°14' $2.437'' 150°00'49.151" 119' 11.'3.8 16 5,938, 160.11 ! 498,310.20 70°14' 32. 191'' 150° 00' 49. 130'' ~44' 113.8 17 5,938, 13,5.21 498,310.18 70o14' 31.946" 150°00'49.130'' 169' 115.9 18 5,938, 110.19 498,310.29 70°14'31.700'' 150°00'49.127'' 194' i 114.0 19 5,958,085.~0 498,310.27 70014. 31.454" 150 °00' 49. 127'' 2 19' 114.0 20 5,938,060.14 498,310.22 70°14' 31.207'' 150° 00'49. 128" 244' 114.1 21 5,9 38,035.16 498,310.16 70° 14' 30.962'' 150° 00'49. 130'' 269' 'i 114.0 22 5,938,010.40 ~ 498,310.19 70°14'30,718'' 150°00'49.129" 2941 94' 114.0 23 5,937,985.32j 498,310.13 70°14'30.471" 150°00'49.130'' 319' 95' 114.0 24 51937,960.29 498,310.08 70 °14' 30.225'' 150°00'49.132" 344' 95' I 113.9 118.5 OF. A( I HEREBY CERTIFY THAT I AM ~a~-~%_~**,*' ARCO Abska, PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE~~ STATE OF ALASKA AND THAT THIS ~,.,.,., ............... S...~ PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPER- VISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF NOVEMBER Z:O~ 1988. DRILL SITE 2.K CONDUCTOR AS-BUILTS Dr. b/.' M.O'D C~.b.y.~'Gffl $,~f. I of I Defe.'ll/21/88 ID~. ~o. NSK 6.211. d 4 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE .oc me 3. 4. 5. 6. 7. 8. (8) (3) Admin ~p¢~ ~ 9. · ('9 ~hru 10. (10 and 13) 12. 13. (14 thru 22) (5) BOPE (23 thru 28) Company the permit fee attached .......................................... ~ ~ Lease & Well No. ~~ ~ ~.~'~'g~' ~' ~_~,~:~//~_~-- ,/~ YES NO REd. ARKS 2. Is operator the only affected party ................................. Can permit be approved before fifteen-day wait ...................... Is well to be located in a defined pool ............................. Is we~l] located proper distance from property line .................. ... Is we~d!ocated proper distance from other wells ................ ~ ... . ..... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ ,, Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ................................... '.. Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........ ~ ............................... Will surface casing protect ail zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate,~¢ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~CPd~ psig .. Does the choke manifold comply w/A_PI RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. ' (29 th ru' ) (6) Add: '~,~.,~,, Geology: Engineering: DWJ~-'LCS -~ BEW rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL' GEO. uNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE I I Additional Remarks: (D 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. ALASKA COMPUTING CENTER ....... SCMLUM~ERGER ....... COMPANY NAME : ARCO ALASKA~, INC. WE:LL NAME : 2K - 18: F'IELD NAME :' K'~U~PARU'K BOROUGH : NORTH SLOPE STATE : ALASKA AP[ NUMBER : 50-[03-20[[7'00 REFERENC:E NO : 7353a MI,C ROFiLHE. D ,IS TAPE VERIFICATION LISTING :CHLUMBERGER ALASKA COMPUTING CENTER 14-NOV-1989 11:50 PAGE.' · **~ REEL HEADER SERVICE NAME : EDIT DATE : 89/11/14 ORIGIN : FLIC REEL NAME : 73534 CONTINUATION ~ : PREVIOUS REEL : COMMENT : ARCO ALASKA, INC. ,KUPARUK **** TAPE HEADER SERVICE NAME : EDIT DATE : 89/11/14 ORIGIN : FLIC TAPE NAME : 73534 CONTINUATION a : 1 PREVIOUS TAPE : COMMENT : .ARCO ALASKA~ INC. eKUPARUK ~2K- 18 ~50-103'-,Z:0117-00 **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE :: FLIC VERSION : OOZAO'2 DATE : 89/11/:14 MAX REC SIZE : 1024 FI'LE TYPE : LO LAST FILE = SCHLUMBERGER WELL SERVICES COMPANY NAME': ARCO AL:ASKA., INC. WELL: 2K - I8 FIELD: K:UPAR~UK BOROUGH: NORTH SLOPE STATE:' ALASKA API NUMBER: 50-103-20117-00 LOCATION: 194' FN:L& 9'~I, FEL SECTION: 11, TOWNSHIP: RANGE: IS TaPE V~RIFICATION LISTING CHL:UMBERGE'R a. LASK. A COMPUTING CENTER 14-NOV-t989 li:50 PAGE: PERMANENT DATUM:' MSL E:LEV~TION: 0 LOG MEASURED FROM RKO 154 ABOVE PERMANENT DATUM ELEVA~TIONS KY: 154 OF: 153 GL:' 113 DaTE LDGGEO: RUN NUMBER: TO DRILLER: TO LOGGER: 01-NOV-1 989 ONE 7960 7949 CASING: 7'" 26 LB a DRILLER DEPTH DF 7~¢58 :BIT SIZE: 6, TYPE FLUID IN HOLE: LSND POLYMER OENSITT: 10.1 VISCOSITY: ¢0 PH: 8.5 FLUID: LOSS: 3'B MUD RESISTIVITY: FILTRATE RESISTIVITY: MUD CAKE RESISTIVITY: 3.48 ~ 65 2.95 @ 65 TIME CIRCULATION ENDED: 19:30 01-NOV TIME LOGGER ON BOTTOM: 00:44 02-NOV MAXIMUM TEMP RECORDED: 154 LO:GGING DISTRICT: LOGGING ENGINEER: WITNESS: PRUDHOE BAY FRITZKE DIXON/LDWEN TOOL NUMBERS: IEM 1348 SGC 24T9 CNC1238 DIC1308 NLM 133B PGS 508 DIS 1~57 PGC 1041 FIELD REMARKS: NO STANDOFFS USED aN THE DIT BECAUSE OF THE SMALL HOLE SIZE. MATRIX DENSITY = 2.65 G/CC., FLUID DENSITY = 1.0 G/CC. NEUTRON MATRIX = SaND~ HOLE CORRECTION = CALIPER. PAD ELEVATION = 118 FEET . HIGH RESOLUTION PASS LOGGED BUT NOT PRESENTED DN FILMS. NO BOWSPRING USED ON CNL DUE TO SMALL HOLE SIZE. MAXIMUM DEVIATION = 42.~ DEGREES @ 2589~. THE SP WAS NOISEY AND ERRATIC IN INTERVAL FROM 7790' TO 7B52'. ON THE 1.2~ PASS, THE TOOL WAS STICKING TN INTERVAL FROM 7790" TO 7852' THE GAMMA RAY AS WELL DID NOT REPEAT WELl IN IN'TERVAL FROM 7860' TO 7810' THEY APPEARED TO BE RELATED. POSSIBLY LOOSE ROiK FROM THE SIDE OF MOLE MAY HAVE FALLEN tN ON THE TOOL. NO FURTHER PASSES WERE MaDE AS PER CLIENT REQUEST. HIGH RESOLUTION PaSS WAS USED AS THE REPEAT SECTION. DATE JOB STARTED: T-NOV-SD JOB REFERENCE NO: 73534 ,IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASKA 'COMPUTING CENTER l~-NOV-t989 fl:SO PAGE:: 3 LDP/ANA: KOHR~NG FILE - EDIT.OOl ARCO ALASKA, IN K U P A RUK 2K - 18 50-103-20117-00 MAIN PASS LOG DATA DATA SAMPLEO EVERY -.5000 FEET DATA I:NC:LUOED- TOOL EXTENSION TOOL TYPE USED NAME DIT-D .DIL FDC o FDC C NT- A/D/H . CNL GR .CSG DUAL INDUCTION SFL FORMATION DENSITY COMPENSATED NEUTRON GAMMA RAY 7938' TO 7453~ T913~ TO 7453~ 7899m TO 7453~ 7507~ TO 990~ TABLE TYPE : CONS TUNI VALU DEFI CN FN WN APIN FL SECT TOWN RANG COUN STAT NATI WITN SON PDAT EPD LMF APO EKB FT FT FT ARCO ALASKA~ INC. KUPARUK 2K - 18 50-103-20117-00 194t FNL & 94~ FEL 11 1ON NO~TH SLOPE ALASKA DIXON/LOWEN 548373 O. 154. 154. COMPANY NAME FIELD NAME WELL NAME AP[ SERIAL NUMBER FIELD LOCATION SECTION TOWNSHIP RANGE COUNTY STATE OR PROVINCE NATION WITNESS'S NAME SERVICE ORDER NUMBER PERMANENT DATUM LOG MEASURED FROM IS TAPE VERIFICATION LISTING I¢-NOV-lgOg 11:50 PAGE: 4 CHLUMBERGER' ALASKA COMPUTING CENTER T UNI V ~,:LU DEF I EOF FT ! 53. EGL FT ! 13. TOD FT 7:960. 'BL! FT 793.8. BOTTOM LOG INTERVAL TLI FT 990. TOP LOG INTERVAL TCS !9=30 O!-NOV TINE C~ECULAT[ON STOPPED TLa~ 00:~4 OZ-NOV T~NE LOGGER :AT BOTTOM STEM DE~F -999.25 TABLE TYPE : CURV OEFI DEPT DEPTH CHANNEL NAME ILO IL-DEeP RESISTIVITY ILM IL-MEDIUM ~RESISTIVITY SFtU SFL UNAVER~G~O SP SPONTANEgUS POT~NTIA'L GR GAMM~ R~Y TENS TENSION DPHI D~NSITY POROSITY RHDB SUL~ O~NSITY DRHO DELTA RHO FFDC ~ FAR FOC COUNT RATE NFDC NE,~R FDC COUNT RATE CALI CALZPER GR GAMM~ RAY TENS TENS[ON NPH[ NEUTRON POROSITY TNPH THERMAL NEUTRON POROSITY TNR~ CALIBRRTED THERMAL NEUTRON RATIO NPOR NEUTRON POROSITY OUTPUT FROM AN APPLICATION PROGRAM RCNT RA~ CORRECTED NEAR THERMAL COUNTS RCFT ~A~ CORRECTED FAR THERMAL COUNTS CNTC CORRECTED NEAR THERMAL COUNTS CFTC CORRECTED FaR THERMAL COUNTS GR GAH~R RAY CALl CALIPE~ TENS TENSION GR GAMMA RAY TENS TENS[ON IS TAPE VERIFICATION LISTING ',CHLUMBERGER ALASKA COMPUTING CENTER 14-N~V-1989 11:50 DATA FORMAT SPECI;ICATIDN RECORD SET TYPE - 64E~ *~ TYPE R'EPR CODE V A L U E ! 66 0 2 66 0 3 73 ! ! Z 4 66 5 66. 6 73 7 65 8 68 0.5 9 65 FT 11 66 1.2 68 13 66 0 14 65 ~T 15 66 68 1 & 66 0 66 0 ** SET~TYPE - CHAN ~*~ NAME SER'¥ UNIT SERVICE API API API API FILE NUM5 NUMB SIZE REPR PROCESS IO ORDER J LOG TYPE CLASS MOD NUMB. SAMP E:LEM CODE (HEX) D E P T F T 548373 00 ILO OIL OHMM 548373 07 ILM OIL OHMM 548373 07 SFLU OIL DHMM 548373 07 SP OIL MV 548373 07 GR OIL GAPI 548373 07 TENS OIL LB 548373 07 OPHI FOC PU 548373 07 RHOB FOC G/C3 548373 07 ORHO FOC G/C3 548373 07 F~OC FOC CPS 54~373 07 NFOC FOC C~S 548373 07 CALI FOC ZN 548373 07 GR FOC GAPI 548373 07 TENS FDC LB 548373 07 NPHI CNL PU 5~8373 07 TNPM CNL PU 5~8373 07 TNRA CNL 54~373 07 NPOR CNL PU 548373 07 RCNT CNL CPS 548373 07 RCFT CNL CPS 548373 07 CNTC CNL CPS 548373 07 CFTC CNL CPS 548373 07 GR CNL GAPI 548373 07 C~Lt CNL IN 548373 07 TENS CNL L~ 548373 07 000 O0 0 1 I I 4 68 1120 46 0 I I 1 4 68 120 44 0 1 I I 4 68 220 O1 0 I I I 4 68 010 01 0 I I I 4 68 310 O1 0 I 1 1 ~ 68 635 21 0 1 1 I 4 68 635 21 0 I I 1 4 68 350 02 0 I I I 4 68 356 01 0 I i I 4 68 354 02 0 I I I 4 68 354 01 0 1 1 I 4 68 280 01 0 I I I 4 68 310 01 0 I I I 4 68 635 21 0 1 I I 4 65 890 O0 0 1 I I 4 68 B90 O0 0 I I I 4 68 420 01 0 1 I I 4. 68 BO0 O0 0 1 1 1 4 68 420 01 0 I I 1 4 68 420 01 0 1 I I 4 68 420 01 0 1 I 1 4 69 420 01 0 I I 1 4 68 310 O1 0 1 1 I 4 68 280 01 0 1 I ! 4 68 635 21 0 I 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 '0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O000OO0000 0000000000 0000000000 0000000000 0000000000 OOOO000000 0000000000 0000000000 0000000000 0000000000 P A G E:: : 5 IS TAPE 'VERIFICATION LISTING 14-NOV-1989 11:50 'CHLUMSERGER ALASKA COMPUTING CENTER PAGE:. NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID 'ORDER .e LOG TYPE CLASS MOO NUMB SAMP ELEM CODE (HEX) GR CSG GAPI 548373 OT 310 01 0 I I I 4 68 O000OO00O:O TENS CSG :LB 548373 07 635 21 0 1 I 1 4 68 0000000000 DEPT. 7957.000 ILO, OIL 1.974 I:LM°DIL 1.746 SFLU.DIL SP.DIL -22.531 GR.DIL 119.,~38 TENS.OIL 3844.000 DPHI.FDC RHOB. FDC 2.535 ORHO.FDC 0.186 FFOC.FOC 588.500 NFDC.FDC CALI.FDC 5.781 GR.FDC 119.438 TENS.FDC 38~4..000 NPHI.CNL TNPH.CNL 38.44~ TNRA.CNL 3.16Z NPDR'CNL 38.44~ RCNT.CNL RCFT.CNL 663.~8. CNTC.CNL 2345.~69 CFTC.,CNL 753.[3[ GR.CNL C~LI.C~L 5.78[ TENS.CNL 3844.000 GR.CSG -999..Z50 TENS.CSG DEPT. 7900.000 ILO.OIL 2.973 ILM.DII 3.030 SFLU. OIL SP.DIL -25.469 GR.OIL 119.37.5 TENS.OIL 6128.000 OPHI.FDC RHOB. FDC Z.403 DRHO.FDC 0.058 FFDC.FOC 593.000 NFDC.FDC CALI.FDC 6.063 GR.FDC t19.37:5 TENS.FDC 6128.000 NPHI.CNL TNPH.CNL 35.788 TNRA.CNL. 3.018 NPOR.CNL 35.082 RCNT.CNL RCFT.CNL 690.85~ CNTC.CNL 2317.656 CFTC. CNL 78?.376 GR.CNL CALI.CNL 6.063 TENS.CNL 6128.000 GR.CSG -999.Z50 TENS..CSG DE:PT. 7800.000 ILO.OIL 3.42! ILM.DIL 3.¢72 SFLU. DIL SP. DIL -49°000 GR.DIL 115.000 TENS.OIL 5752.000 DPHI.FDC RHOSoFOC 2.519 DRHO.FDC O.OZ5 FFDC. FOC 411.500 .NFDC.FDC CALI.FDC 6.191 GR.FDC 115.000 TENS.FDC 5752.000 NPHI.CNL TNPHoCNL 38.241 TNRA.CNL 3.167 NPOR.CNL 37..030 RCNT.CNL RCFT.CNL 635.71! CNTC.CNL 2~78.783 CFTC.CNL 734.076 GR.CNL CAtI.CNL 6.191 TENS..CNL 5752.000 GR.CSG -99'9.250 TENS.CSG DEPT. 7700.000 ILO.OIL 4.113 ILM.DIL 4.317 SFLU. DIL SP.DIL -40.000 GR.OIL 112.438 TENS.OIL 555Z.000 DPHI.FDC RHOB.FOC 2.474 DRMO.FDC -0.002 FFOC.FOC ~29o750 NFDCoFDC CALIoFDC 6.273 GR.FDC 11Z.438 TENS.FOC 555Z.000 NPHI.CNL TNPM. CNL 32.865 TNRA.CNL 2.809 NPOR.CNL 35.248 RCNT.CNL RCFT.CNL 842.712 CNTC.CNL Z623.782 CFTC.CNL 949.743 GR.CNL CALI.CNL 6.273 TENS.CNL 5552.000 GR.CSG -999.Z50 TENS.CSG DEPT. 7600.000 ILD.DIL 8.927 ILM.DIL 8.499 SFLU.OIL SP.OlL -39.500 GR.DIL 100.000 TENS.OIL 5412.000 DPHI.FDC RHOB.FDC Z.448 DRHO.FDC 0.019 FFDC.FDC 48Z.750 NFDC.FOC CALI.FDC 6.266 GR.FDC 100.000 TENS.FDC 5412.000 NPHI.CNL TNPH.CNL 27.110 TNRA.CNL 2.480 NPOR.CNL 27.964 RCNT.CNL RCFT.CNL 1209.647 CNTC.CNL 3326.833 CFTC.CNL 1393.527 GR.CNL CALI.CNL 6.266 TENS.CNL 5412.000 GR.CSG 109.563 TENS.CSG DEPT. 7500.000 ILO.OIL 2.675 ILM. DIL 2.693 SFLU.DIL SP.DIL -¢1.000 GR.DIL 14Z.750 TENS.OIL 5724.000 DPflI.FDC RHOB.FOC 2.453 DRHa. FDC 0.094 FFDC.FDC 573.000 NFDC. FOC CALI.FDC 7. 008, GR.FOC 142,750 TENS. FDC 5724.000 NPHI.CNL 1.693 6.998 752.500 40.299 2297. 853 1 ! 9.43 B -999-250 3.28¢ 14. 958 659.000 37. :357 230:9.168 119. 375 -999.250 &.070 7.960 564.500 39.935 Z295.089 115.000 -999.250 10.651 5¢2.000 33.288 Z425.967 112.438 -999.250 B.1B2 12.242 586.000 28.361 3182.746 100.000 5748.000 2.845 11.920 681.500 42.743 IS TAPE VERIFICATION LISTING :CHLUM~ERGER ALASKA COMPUTING CENTER TNPH.CNL RCFT.. CNL C A:L I. C N L 37. 646 TNRA.:CNL 5&4.48& CNTC.CNL 7.008 TENS.CNL DEPT. SP.OIL RHOB.FDC CALI. FDC TNPH. CNL RCFT. CNL CALI.CNL 7400. 000 ILO. OIL -1~6.453 GR.OIL 2.'173 ORHO.FOC 6.156 GR.FDC 40.660 T N R a. ~C NL $16. 193 CNTC.CNL 6.156 TENS.CNL D ~PT. SP.OIL RHOB.FDC CALI.FOC T NPH. CNL RCFT.CNL C ALI oCNL 7300.000 ILD.DIL - 999r. 250 GR'''DIL --999. 250 OR HO. FOC --99'9' 250 GE ' FOC --999'250 TNRA'CNL -999.250 CNTC. CNL -999. 250 TENS'CNL DEPT. S P ' D I L RHOB. FDC C .AL !. FDC TNPH.CNL RCFT.CNL CAL[.C'NL 7200.000 ILO. OIL -9 99.2 50 GR.OIL -999.250 ORHO.FOC -999.250 GR.FOC -999.250 TNRA.CNL -999.250 CNTC.CNL - 999.250 'T E N S. C NL DEPT. SP. OIL RHOB.FDC CALI. FDC TNPH.CNL RCFT.CNL CALI.CNL 7100.000 ILO. OIL -999. 250 GR.OIL -999.250 DRHO.FDC -999.250 GR.FOC -999.250 TNRA.CNL -999.250 CNTC..CNL -999.250 TENS.CNL DEPT. SP.DIL RHOB.FOC CALI.FOC TNPH.CNL ECFT.CNL CALI.CNL 7000.000 ILO.OIL -999.250 GR.DIL -999.250 DRHO.FOC -999. 250 GR.FDC -999.250 TNRA.CNL -999.250 CNTC.CNL -999.250 TENS.CNL DEPT. SP.DIL RHOB. FDC CALI.FDC TNPH.CNL RCFT.CNL C.~LI.CNL 6900.000 ILO.OIL -999.250 GR.DIL -999.250 DRHO.FDC -999.250 GR.FDC -999.250 TNRA.CNL -999. 250 CNTC.CNL -999.250 TENS.CNL 14-NOV-1989 11:50 3. 369 NPOR.CNL 2043,. '729 C F T C. C NL 572¢. 000 GR.CSG 17. 802 ILM.DIL OB. 875 TENS'OIL -0. 517 FFDC'FOC 88. 875 TENS.FOC 3. 229 NPOR. CN:L 1'749. 522 CFTC.CNL 5288. 000 GR.CSG -999.250 ILM.OIL -999.250 TENS.OIL -999.250 FFDC.FOC -999.250 TENS..FDC -999.250 N'POR.CNL -999.250 CFTCoCNL -999.250 GR.CSG -999. 250 ILM.OIL -999.250 TENS.OIL -'999. 250 FFOC.FOC -999. 250 TENS. FOC -999. 250 NPOR.CNL -9-99..250 CFTC.CNL -999.250 GR.CSG -999.25~0 ILM. O IL -999.250 TENS.OIL -999.250 FFDC.FDC -999.250 TENS.FOC -999. 250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -999.250 ILM.DIL -999.250 TENS.OIL -999.250 FFDC.FDC -999.250 TENS.FOC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -999.250 ILM.OIL -999.250 TENS.OIL -999.250 FFDC.FDC -999..250 TENS.FDC --999.250 NPOR.CNL -999.250 CFTC.CNL -999. 250 GR.CSG 40.143 RCNT.CNL 657.73& GRoCNiL 144.500 TENS.CSG 200 O. 000 S F L U. 01 L 5288.000 OPHI.FDC 254.125 NFDC.FDC 5288.000 NPHI.CNL 49.787 RCNT.CNL 53 7. ! 66 G R. C N L 61.750 T~NS.CSG -999.250 SFLU.DIL 999.250 DPHI.FOC -999.250 NFOC.FDC -999.250 NPHI'CNL - 999 o 250 R C N ~T. C N L -999.250 GR.CNL 102.438 TENS.CSG -999.250 S~LU.OIL -9~99.250 DPHI.FDC -999.250 NFDC.FDC -999.. 250 NPHI.CNL - 999.250 R C N T - C N L -999.250 GR.CNL 201.250 TENS.CSG --999.250 SFLU. DIL -999.250 DPHI.FDC -999.250 NFOC.FDC -999.250 NPHI.oCNL -999.250 RCNT.CNL -999.250 GR.CNL 94.375 TENS.CSG -999°250 SFLIJ.DJL -999.250 OPHI. FOC -999.250 NFOC.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 GR.CNL 107.750 TENS.CSG -999.250 SFLU. OIL -999.250 OPHI.FO¢ -999.250 NFDC.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 GR.CNL 8¢.563 TENS.CSG PAGE: 7 1894.559 142.750 5728.000 6.955' 28.934 1'77.625 ~1-103 1638.978 88.875 546,8.'000 -999.250 -999.250 -999.250 -99'9.25~0 -999.250 -999-250 5¢88.~000 -999.250 -999.250: -999.25:0 -999.250! -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999'250 -999.250 5260'000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 5204.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 5200.000 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA ;COMPUTING CENTER DEPT. SP.DIL RHD8. FDC CALI.FDC T N P Ho CN L RCFT.CNL C ALI. CNL DEPT. SP.OIL RHOB.FDC C RL !. FDC TNPH.CNL RCFT.CNL CALI.CNL DEPT. SP.OIL RHOB. FDC C AL I. FOC TNPH.CNL RCFT.CNL CALI.CNL DEPT. S P. O Z L CALI. FOC T N P H. C N L RCFT.CNL CRLI.CNL DEPT., SP.OIL RHOB.FOC C AL I. FOC TNPH.CNL RCFT.CNL CALI.CNL DEPT,. SP.D[L RHOB.FDC CALI.FOC TNPH.CNL RCFToCNL CALIoCNL 6800.000 I L D. D I L -999.2 .~,0 GR.. O'IL -99'9.250 DRHO.FDC -999.250 GR.FDC -999.250 TNRA.CNL -999.250 CNTC.!CNL -999.250 'TENSoCNL 6700.000 ILO. OIL -999-250 GR-OIL -999.250 DRHO.FDC -999. 250 GR.FOC -999.250 TNRA.CNL '-999-250 CNTC.CNL -999-250 TENS.:CNL 6600.000 I L D. O I L '-999. 250 GR.DIL -999.250 DRHD.FDC -999. 250 GR-FOC -999. 250 TNRAo~CNL -999.250 CNTC.CNL -999- 250 'TENS.CNL 6500.000 'ILO.OIL -999.250 GR.:O Il -999.250 ORHO.FDC -999. 250 GR.FOC -999-250 TNRA.CNL -999.250 C=NTC.CNL -999.250 TENS.CNL 6400.000 ILO.OIL -999.250 GR.DIL -999.250 DRHO.FOC -999.250 GR.FOC -999.250 TNRA.CNL -999.250 CNTC.CNL -999.250 TENS.CNL 6300.000 ILD.OIL -999.250 GR.DIL -999.250 ORHO.FOC -999.250 GR.FDC -999.250 TNRA.CNL -999.250 CNTC.CNL -999.250 TENS.CNL DEPT. 6200.000 ILO.OIL SP.DIL -999.250 GR.OIL RHOB..r=DC -999.250 ORHO.FDC CALI. FOC -999. 250 GR. FOC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL 14-NOV-1989 11:50 -999.250 IL)I.OIL -999'250 TENS.OIL -999.250 FFOC.FOC -999.250 TENS.FDC - 999. 250 NPOR.CNL -999' 250 CFTC.CNL -999. Z50 GR.CSG - 999..250 -9'99. 250 -999.250 -999. 250 - 99 9.250 -999.250 81. 500 -999°250 ILM.DIL -999.250 -999.2510 TENS.OIL -999.250 -999.250 FFOC. FDC -999.250 -999.250 'TENS.. :F~)C -999.250 -999.250 NPOR.CNL -999.250 -999. 250 CFTC.CNL -999.250 -999. 250 GR.CSG 101.250 -999.250 ILM.OIL -999.250 :TENS'OIL -999.250 FFOC.FOC -999.250 TENS. FOC -999.250 NPOR.'CNL -99!9.250 CFTC.~CNL -999.250 GRoCSG -999.250 - 999.250 -999. 250 -999.250 - 999.250 -999.250 76. 375 -999.250 ILM-DIL -999.250 -999.250 TENS.OIL -999.250 -999.25.0 FFOC.FOC -999.250 -999.250 TENS.FDC -999..250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.2.50 -999. 250 GR.CSG 94.000 -999.250 ILM.DIL -999.250 -999.250 'TENS.OIL -999.250 -999. 250 FFDC.. FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999,.250 -999.250 CFTC.CNL -999.250 -999. 250 GR.CSG 81.438 -999.250 ILM. DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FOC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 8[.750 -999.Z50 ILM.OIL -999.250 -999.Z50 TENSoDIL -999.250 -999.250 FFOC.FDC --999.250 -999.250 TENS.FDC -999.250 -999.250 NPORoCNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 63.281 SFLU.OIL DP'HI,FOC NFD:C.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SiF!LU.OIL DPHI,.FOC ;NFDC.FDC NPHI.CNL RCNT. CNL GRoCNL TE~NS.CSG SFLU..OIL DPHI.FDC NFOC.FDC NPHI.CNL RCN~T.CNL GR.CNL TENS.CSG SFLU.OIL OPHI.FOC NFOC.FDC NPHI.CNL RCNT-CNL GRoCNL TENS.CSG SFLU.OIL OPHI.FDC NFDC.FOC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.OIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU. DIL DPHI.FDC NFOC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG PAGE: -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 5168.000 -999.250 -999.250 -999.250 -9=99.250 -999.250 -999.250 5152.000 -999. 250 -999. 250 -999.250 -999.250 -999.250 -999.250 5:120. 000 -999.250 -999. 250 -999.Z50 -999.250 -999.250 -999 · 250 5168.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 50¢4'000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4960.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4924.000 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER DEPT. SP. OIL RHOB. FDC CALI.FDC T N P M. C N L RCFT.CNL CALI.CNL 6!00.000 ILD. DIL -999.250 GR.DIL -999'250 DRHO.FDC -999. 250 GR.FDC -999.250 TNRA. CNL -999.250 CNTC.CNL -999.250- TENS.CNL O E P T. 6000.000 I L D. D I L SP.OIL -999.250 GR.OIL RHOS.FDC -999.250 DRHO.FDC CALI.FDC -999.250 GR.FOC TNPH.CNL -999. 250 TNRA.CNL RCFT. CNL -999.250 CNTC.CNL C A L I. CN L -999.2 50 T E N S. C NL O EPT. 59 00.000 I LO.. D.IL SP.OI1 -999.250 GR.DIL RHOB.FDC -999.250 ORHO. FDC CALI.FDC -999.-250 GR. FOC T N:PM' CN :L - 999.250 T N R A. C N L RCFT.CNL -999.250 CNTC.CNL CAL!.CNL --999.250 TENS.CNL DEPT. 'SP.DIL RHOB.FDC C AL I. FDC T NPH.. C NL RCFT.CNL C AL I. CNL 5800. 000 'ILD.DIL -999.250 GR.DIL -999. 250 DRflO. FOC -999. 250 GR.FOC -999.250 TNRA.CNL -999.250 CNTC.CNL -999.250 TENS.CNL DEPT. 5700.000 ILO'OIL SP.D[L -999.250 GR.DIL RHOB.FDC -999.250 DRHO.FDC C ALIoFDC -999.250 GR.FDC TNPMoCNL -999.250 TNRA.CNL RCFT.CNL -999. 250 CNTC.CNL CALIoCNL -999.250 TENS.CNL DEPT. SP.DIL RHOB.FDC CALI.FDC TNPH.CNL RCFT.CNL C~LI.CNL DEPT. SP.OIL RHOB.FDC CALI.FDC TNPH.CNL RCFT.CNL 5600.000 ILO.OIL -999.250 GR.DIL -999.250 DRHG.FDC -999.250 GR.FDC -999.250 TNRA.CNL -999.250 CNTC.CNL -999.250 TENS.CNL 5500.000 ILO.OIL -999.250 GR.OIL -999.250 DRHO.FDC -999.250 GR.FOC -999.250 TNRA.CNL -999.250 CNTC.CNL 14-NOV-1959 11:50 -999.250 ILM'OIL -999.250 TENS.OIL -999.25.0 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL - 999. 250 CFTC. C NL -999' 250 GR.CSG -999.250 ILM.OIL -999.250 TENS.OIL -999.250 FFDC'FOC -999.250 TENS.FDC -999.250 NPOR.CNL - 999.250 C F T C. C N L -999.250 GR.CSG -999.2<50 ILM.DIL -999.250 TENS. OIL -999.250 FFOC.FDC -999.250 TENS.FOC -999.250 NPOR.CNL -999.2510 CFTC. CNL --999.250 GR.CSG -999o250 ILM. DIL -999.250 TENS.OIL -999.250 FFDC.FDC -'999.250 TENS.FOC --999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -999.250 ILM.DIL -999.250 TENS.OIL -999.250 FFDC.FDC -999°250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -999.250 ILM.OIL -999.250 TENS.OIL -999.250 FFOC.FOC -999.250 TENS.FOC -999. 250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -999.250 ILM.DIL -999.250 TENS.OIL -999. 250 FFOC.FOC -999.250 TENS.FOC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 -99 9.250 -999.250 -999.250 -999.250 -999.250 5'8. 656 999'250 -999.250 -999.250 -999.250 -999.250 -999.250 7 5. -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 82. 563 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 98. 063 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 105.563 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 86.500 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 S FLU. O I L DPHI. FDC N F DC. FO C NPHI. C NL · RCNT.CNL GR- CNL TENS.CSG SFLU.DIL OPHI.FOC NFDC.FDC NPHIoCNL RCNT.CNL GR.CNL TENS.CSG SFLU. OIL DPHI.FDC NFDC. FDC NPH I ' CNL RCNT.CNL GR. CNL T :E N S. C S G SFLU-DIL DPHI.FDC N F D C - F D C N P H I. C NL RCNT.:CNL GR.CNL TENS.CSG SFLU.OIL DPHI. FDC NFDC.FDC N PHI. CNL RCNT.CNL GR.CNL TENS.CSG SFLU.OIL OPHI. FDC NFDCoFDC NPHI .CNL RCNT.CNL GRoCNL TENS.CSG SFLU.DIL OPHI.FDC NFDC.FOC NPHI.CNL RCNT.CNL GR.CNL PAGE: 9 -999'250! -999-250 -999'250' -999.250 -999.250 -999'250 48¢0.000 -999.250 -999.250 -999.250 -999.250 -999.250 47~0'000 -999.250 -999.250 -999.290 -999.250 -999.250 -999.250 4720.000 -999.250 -999.250 -99.9.250~ -99'9.250 -999.250 -999.250 ¢632.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ~692.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ¢672.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .IS TAPE VERIFICATION LISTING ,CHLUMBERGER ALASKA COMPUTING CENTER CALI.CNL -999.250 TENS.CNL DEPT- 5400.000 ILO.OIL SP.DIL -999.250 GR.OIL R H 0 B. F D C - 99'9:. 2 50 D R HO'. F DC CALI-FOC -999.250 GR.FOC TN'PH.CNL -999.250 TN:RA.CNL RCFT.CNL -9'99.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL D E P T 5300.000 ! L O. O I L S P o O I L -'999 ' 250 G R. 01 L RHOB.~DC -999.250 DRHO.FOC C A L I. F O C - 999.25 '0 G R. F O C TNPH-CNL -999.250 TNRAoCNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999. 250 TENS.CNL DF. PT. 5200.000 ILO. OIL SP. DIL -999.250 GR.DIL RHOB.FDC -999.250 DRMO. FOC CALI.FOC -999.2S0 GR,,FOC TN'PHoCNL -999.250 TNRA°CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT,. 5100.000 ILO.OIL SP.DIL -999.250 GR.DIL RHOB. FDC -999.250 DRHO'FDC CALI. FDC -999.2 50 GR.,FDC TNPH.CNL -999. 250 TNRA.CNL RCFT.CNL -999. 250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 5000.000 ILO.OIL SP. OIL -999.2 50 GR.OIL RHOB.FDC -999.250 DRHO. FDC CALI. FDC -999. 250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPTo ¢900.000 ILO.OIL SP.OIL -999.250 GR.OIL RHOB. FDC -999.250 DRHO.FDC CALI. FDC -999. 250 GR. FDC TNPHoCNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C.~LI.CNL -999.250 TENS.CNL DEPT. 4800.000 ILO. OIL SP.OIL -999.250 GR.DIL RHOB.FDC -999.250 DRHO.FDC CALI.FDC -999.250 GR.FDC TNPHoCNL -999.250 TNRA.CNL 14-NOV,-1989 11=50 -999.250 GR.CSG 79.188 -999.2.5.0 ILM.DIL -99'9.250 TENS.OIL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC'CNL -999. 250 GR.CSG -999.250 -999.250 -999.250 -999.250 - 999.250 -999.250 -999. 250 -999.250 - 999. 250 -999. 250 -999.250 -999. 250 -999.2.50 -999. 250 -999. 250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ILM..DIL T E N S. O I L FFDC. FDC TENS. FDC NPOR.CNL CFTC,CNL GR.CSG ILM.DIL TENS.OIL FFOC.FDC TENS.FOC NPOR.CNL CFTC-CNL GR.CSG ILM. DIL TENS.OIL FFOC'FDC TENS.FDC NPOR.CNL CFTC.CNL GR.CSG ILM.DIL TENS.DIL FFDC.FDC TENS.FDC NPOR.CNL CFTC.CNL GR.CSG IL#.OIL TENS.OIL FFOC.FDC TENS.FDC NPOR.CNL CFTC.CNL GR.CSG ILM.OIL TENS.OIL ~FDC.FDC TENS.FDC NPOR.CNL -999.250 -999.250 -999.250 -999. 250 -999.250 -999- 250 80.375 -999.250 ,-999. 250 -999.250 -999.250 -999.250 81.625 -999.250 -999.250 -999.250 -999.250 -999. Z 50 -999. ,250 81.375 -999. 250 -999.250 -999..250 -999.250 -999.250 -999. Z 50 66.000 -999.250 -999.250 -999°250 -999.250 -999.250 -999.250 72.750 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 57.063 -999.250 -999.250 -999.250 -999.250 -999.250 TENS. CSG F L U. 01 L DPH. I- FDC F O C. FD C PHI. CNL RC NT. CNL G R' C N L E N S. C $ :G SFLU. OIL DPHI. FDC NFOC. FDC NPHI. CNL R C N T. C N L G R o CNL TENS.CSG SFLU.DIL DPHI.FOC NFDC. F'DC NPH I. CNL R CNT. C N L GR.C:NL T E N $. C S G S FLU. OI'L D P HI. FOC NFDC.FDC NPHI. CNL RCNT.CNL GR. CNL TENS.CSG SFLU.DIL OPHI.FDC NFDC.FOC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL OPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DZL DPH[.FDC NFDC.FDC NPHI.CNL RCNT.CNL .PAGE: 10 4584'000 -999.250. -999.250 -999.250 -'999.25!0 -999.250 -999.250 4500.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999o250 4-¢0B.000 -999-250 -999.250 -999'25'0 --999.250 -999-250 -999'250 4364.000 -999.250 -999.25'0 -999.250 -999.250 -999.250 -999.250 435:2.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ~340.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ~304.000 -999.250 -999.250 -999.250 -999.250 -999.250 IS TAPE VERIFICATION LISTING CHLUfl~ERGER aLASKa, COMPDTING ,CENTER RCFToCNL -999. 250 CNTC.CNL CALIoCNL -999.2S0 TENS.CNL DEPT. SP.OIL RHO8., FDC CiL I. FDC TNPH.CNL RCFT.CNL ,CALIoCNL ~ 700,. 00'0 -999.250 -999' 250 -999.250 -999.25:0 -999.250 -999.2S0 ILD.DIL G R. :D T L O. RHO.FOC GR. FDC TNRa. CNL CN TC. C NL TENS.CNL DEPT.. SP.DIL R H 0 B. FD C C aL !. FDC T N P H.. C N L RCFToCNL CALI.CNL 4600. 000 -999° 250 -999.250 -999.250 -999- 250 -999' 250 -999.250 ILO.OIL G:R.O[L DRHO .FDC GR o F DC TNRA.CflL CN TC. C NL TENSo~CNL DEPT. SPoOIL RHOB o FDC CaLI..FDC TNPH.CNL RCFToCNL CALI.CNL 14-NOV-1989 11:50 DEPTo SP.D[L RHOB.FDC CALIoFDC TNPH.CNL RCFT.CNL CALI.CNL -999'2.50 CF'TC.CNL '-999.250 -999.250 GR.~CSG 67.938 DEPT. SP.DIL R HOB.. FOC CALIoFOC TNPH.CNL RCFT.CNL C/~LI.CNL -999. 250 ILM.Ot~L -999. 250 TENS.OIL -999. 250 FFOC.FDC - 999.2 S 0 T E N $. F O C -999. 250 NPOR.CNL -999. g50 CFTC.C NL -999. 250 GR.CSG -999,'250 -999.250 -999.250 -999.250 '999°250 999. Z 50 66.0 O0 -999.250 ILM.OIL --999.250 -999.250 TENS.OIL -999.250 .-999.250 FFOC.,FOC -999.250 -999.250 TENS,.FOC -999°250 -999.250 NPOR.CNL -999,250 -999.250 CFTC.CNL -999°250 -999oZ50 GRoCSG 53.688 4.50,0.000 ZLO.'DIL -999.. ZEO ILM'DIL '999.250 -999.250 GR.DIL -999,.250 TENS.DIL -999oZ50 -999.250 ORHO.FOC -999,.250 FFDCoFDC -999°250 -999.250 GR. FOC -999.250 TENS. FDC -999.250 -999.25:0 TNRA.CNL -999.2S0 NPOR.CNL -9'99.250 -999.250 CNTC.CNL .-999.250 CFTC.CNL -999.250 -999.250 TENS.CNL -999°250 GR.CSG 93.563 4400.000 ILO.OIL -999'250 ILM. OIL -999.250 -999'.250 GR.DIL -999.250 TENS.OIL -999.Z50 -999.2S0 DRHO.FDC -999o2S0 FFDC. FDC -999.250 -999.250 GR.. FDC -999.250 TENS. FBC -999.250 -999.250 TNRA.CNL -999°250 NPOR.CNL -999.250 -999.250 CNTC.CNL -999. 250 CFTCoCNL -999.250 -999.250 TEflS.CNL -999. ZEO GR.'CSG 79.188 ILO.OIL GR.DIL DRHO.FDC GR.FDC TNRA.CNL CNTC.CNL TENS.CNL -999.250 ILM.OIL -999.250 -999.250 TENS.OIL -999.250 -999°250 FFDC.FOC -999.250 -999°250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999°250 CFTC.CNL -999.Z50 -999°250 GR.CSG 76.125 4300.000 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 DEPT. 4200.000 ILO.OIL -999°250 ILH.DIL -999.250 SP.Olt -999.250 GR.OIL -999.250 TENS.OIL -999.250 RHGBoFOC -999.250 DRHO.FDC -999°250 FFDC.FDC -999.250 CALI.FDC -999.250 GR.FDC -999°250 TENS.FOC -999.250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCFToCNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 CALIoCNL -999.250 TENS.CNL -999°250 GR.CSG 71.938 DEPT. SP.D[L RHOB.FDC CALI.FDC 4100.000 -999.250 -999.250 -999.250 -999.250 ILM.OIL -999.250 TENS.OIL -999.250 FFDC.FDC -999.250 TENS. FDC ILO.OIL GR.OIL DRHO.FDC GR.FDC -999.250 -999.250 -999.250 -999.250 GR.CNL TENSoCSG $ FLU. O I L DPHI. FD C NFOC o F DC NPHI .CNL R C NT. C NL G R- CNL TENS.CSG SFLU.OIL DPHI.FDC NFOC.FDC NPHI.CNL R C N T. C N L G R .. C N L TENSoCSG SFLU.DIL DPHI.FOC NFOC- FDC NPMI.CNL R CNT. C NL GE .CNL TENS.CSG SFLU. DIL OPHI.FOC N F O C .. F D C NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.OIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU. DIL DPHI.FDC NFOCoFDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.mOC NFDC.FDC NPHI.CNL PAGE: 11 -999.250 4228.0010 -999.25:0 -999.250 -999.250 -999.250 -999.250 -999.250 4 080. 000 -999. 250 -999.250' -999. 250 -999..Z50 -999. 250 -999. Z50 4132.000 -999. 250 -999. ZSO -999.250 -999.25'0 -9 99.o 250 -999.250 4010.000 - 999.250 -9 99.250 -999.250 -999-250 -999.250 -999. Z 50 3890.000 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 3844.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3760.000 -999.Z50 -999.250 -999.250 -999.250 ,IS TAPE VER[F'ICAT[ON LIS'TING ,CHLUM~ERGER ALASK. A.CONPUTING CENTER= T N P H o C N 'L R C F T- C NL CALZoCNL D E P T.. SP.DIiL RHOBo FDC C AL Io FDC TNPHoCNL R C F T o C N L C AL I. CN L DEPT. SP. RHOB. FOC CALL. FDC T NPHo CNL RCFTo CNL CALI.CNL O EPT. SP. OIL RHOB. FDC C AL I. FOC T N'P H. C N L RCFTo CNL CALI.CNL DEPT. SP.OIL RHOB.FOC CALI.FOC TNPH. CNL RCFT.CNL CALI.CNL DEPTo SP.DIL RHOB.FDC CALIoFDC T NPH. CN:L RCFT.CNL CALI.CNL DEPT. SP.OIL RHOB.FDC CALI.FDC TNPH.CNL R CFTo CNL CALI.CNL -999.250 '-999- 2 SO -999 o 2 50 · ¢000. 000 -999.250 -999.250 -999.250 -999.250 -999'250 -999.2 50 390'0. 000 -999.250 -999.250 - 999.250 -999. Z 50 -999.250 -999.250 3800.000 -9 99.2 50 -999.250 -999.250 -999.250 -999.250 -999.250 3700°000 -999.250 -:999.250 -999.2 50 -999. 250 -999.250 -999°250 3600.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3500.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 TN R A. C N L CNTC. C NL TENS.CNL I L D. O I L G R. O I L DR HO o FDC GR.FOC T N R A. C N:L CNTCoCNL TENS.CNL ILO.OIL GR.DIL DRHO.FDC GR. FOC TNRR.CNL CN TC. CNL TENS.CNL ILO. OIL GR*DIL ORHO. FOC G R. F O C TN R A * C NL CNTCoCNL TENS.CNL I L D. O I L GR.DIL DRHO.FOC GR.FDC TN~A.CNL C NTC. C NL TENS.CNL ILO.OIL GR.DIL ORHO.FOC GR.FDC TNRA.CNL CNTCoCNL TENS.CNL ILO.OIL GR.DIL DRHO.FDC GR.FDC TNRA.CNL CNTC.CNL TENS.CNL 14-NOV-1989 11:50 .-999. 250 NPOR.CNL -999..250 -999.250 CFTC'CNL 999,250 - 999.250 G R . C S G 7 6.750 -999.250 IIM.OIl -999.,250 TENS. OIL -999.250 FFOC'FOC -999. 250 TENS:' FOC -999.250 NPORoCNL -999.250 CFTC'CNL -999. 250 GR.C,SG -999.250 ILM.DIL -999.250 TENS.OIL -999.250 FFDC. FOC -999. 250 TENS.FDC -999.250 NPDR.CNL -999.250 CFTC.CNL -999. 250 GRoCSG -999°250 ILM.OIL -999.. 250 TENS.OIL -999.250 FFOC.FDC -999. 250 TENS. FDC -999. 250 NPOR.CNL -999,,,250 CFTCoCNL -999.250 GR.CSG -999.250 ILM.DIL -999.250 TENS.OIL -999.250 FFOC,FDC -999.250 TENSoFDC -999.250 NPORoCNL -999.250 CFTC.CNL -999.250 GR.CSG -999.250 -999.250 · -99'9. gE0 -999. Z50 -999° Z50 -999.. 250 7 2.563 -999. 250 -999° 250 -999° 250 -999.250 -999.250 -999.250 53. 844 -999. ,250 - 999 o 250 - 99 9.250 -999°250 -999.250 -999°250 50.219 -999.250 -999°250 .-999.250 -999.250 -999.250 -999.250 56.344 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 FFDC.FOC -999.250 -999.250 TENSoFDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 63.969 -99g.250 ILM. OIL -999.250 -999.250 TENS.OIL -999.250 -999.250 FFDC.FDC -999.250 -399.250 TENS.FOE -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 64.313 RCNT.CNL ~GR.CNL TENS.CSG SFLU. DIL DPHI.FDC NFDC.FDC NPH'I.CNL RCNT.CNL GRoCNL TENSoCSG SFLU.DIL :O ,~ H I. F D C N F DC o FOC NPHI. CNL R C N T :. C N L GR. CNL TENS.CSG S PHI. FOC FL~: .OIL D N F DC o FD C NPHIoCNL R ~C NT . C'NL GR. CNL TENSoCSG SFLUoOIL OPHI.FOC NFOC.FDC NPHI.CNL R C NT .. C NL GR .CNL TENS.CSG SFLU.OIL DPHI.FOC NFDC°FBC NPHI.CNL RCNT.CNL GR.CNL TENS .CSG SFLU.DIL D~HI.FDC NFDCoFDC NPMI.CNL RCNT.CNL GR.CNL TENS.CSG PAGE: 12 -.999.25~0 -999.250 3744.000 ,-999. ,250 -999.250 -999.250 -999' 250 -999. 250 -999. 250 3744 , 000 -999.'250 -999.250 -999.250 -999.250 -999.250 -999-2.50 370~.000 -9'99.250 -999° 250 -999.250 -9'99. 250 -999.250 -999.250 3674. 000 -999-250 -999. 250 -999. 250 -999.250 -999.250 -999.250 3640.0 O0 -999.250 -999.25'0 -999.250 -999.250 -999.250 -999.250 3554.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3504.000 IS TAPE VERIF!CATIDN LISTING CHL:UMBERGER ALASKA COMPUTING CENTER DEPT. 3400.000 ILO-OIL SP.O[L -999.250 GR. =OIL RH13B:. FOC -999.250 DRMO.FDC CALI.FDC -999.250 GR.FDC TNPH..CNL -999. 250 TNRA.CNL R C F T. C N L - 999.250 C N T C. C NL CALI.CNL -999.Z50 TENS.CNL DEPT. 3300. 000 ILO.OIL SP. OIL '-9 99.2 50 GR. DI~L RHOB.FOC -999. 250 DRHO.FOC CALI.FDC -999.250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT..CNL -999.250 CNTC.CNL C AL'I.CNL -999.250 TENS.CNL DEPT. 3200. 000 ILO.DIL SP. OIL -999.250 GR.DIL RHO~.FDC -99'9.250 DRHO.:FOC C AL I. FDC - 999.250 GR. FDC TNPH.C'NL -999.250 TNRA.CNL RCFT.CNL -999'250 CNTC.~CNL CALIoCNL -999. 250 TENS.CNL OEPT. 3100,000 ILO. OIL SP-DIL -999. 250 GR.OIL RHOB.FOC -999.25,0 ORHO.FOC CALI. FDC -999.250 GR.FDC TNPH.CNL -999. 250 T:NRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 3000.000 ILO.OIL SP.OIL -999.250 GR.DIL RHOB.FDC -999.250 DRHO.FDC CALI.FDC -999. 250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 2900. OOO ILO. OIL SP. DIL -999.250 GR.DIL RHO~.FOC -999.250 DRHO.FDC CALI.FDC -999. 250 GR.FDC TNPM.CNL -999.250 TNRA.CNL RCFT. CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 2800.000 ILD.D!L SP.DIL -999.250 GR.OIL RHOBoFDC -999.250 ORHO.FDC C ALI. FDC -999.2 50 GR. FDC TN'PH. CNL -999. 250 TNRA.CNL RCFT.CNL -999. 250 CNTC.CNL CALI.CNL -999.250 TENS.CNL lC-NOV-1989 11:50 -999.250 ILM. DIL -999.250 -999.250 TENS.OIL -999-2:50 -999.250 FFDC.FDC -999.250 -999.250 TENSoFDC -999.250 -999.25:0 NPO'R.CNL -999.250 -999.250 CFTC. CNL -999.250 -999.250 GR.CSG 71.S75 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250! -999.250 FFDC.FO~C -999.250 -999.250 TENS.FDC -999'250 -999,.250 NPORoCNL -999,.250 -999.250 CFTC.CNL -999.250 -99'9.250 GR.CSG 38.219 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 FFDC.FDC .-999.Z5:0 -999.250 TENS'FDC -999.250 -99'9.250 NPOR.CNL -999.250 -999.250 CFT'C.~CNL -999.Z50 -999.250 GR.CSG 25.797 -999.250 ILM.DIL - 999..250 T E N S. D I L -999.250 FFDC.FDC -999.250 TENS.FOC -999.250 NPOR.CNL -999.250 CFTC.CNL -999. 250 GR.CSG -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 48.031 -999.250 ILM.DIL -999.250 -999.250 TENS. OIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999°250 CFTC.CNL -999.250 -999. 250 GR.CSG 40. 844 -999.250 ILN.DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FOC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CflL -999.250 -999°250 GR.CSG 39.969 -999.250 ILM. DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 FFOC.FDC -999.250 -999.250 TENS.FOC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999o250 -999.250 GR.CSG 47.313 SFLU.DIL DPHI.FDC NFDCoFDC NPHI.CNL RCNT.CNL GR-CNL TENS.CSG SFLU. DIL DPHI'FDC NFDC.FDC NPHI-CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL OPHI.FDC NFDC.FDC 'NPHI.CNL RCNT.CNL G!RoCNL TE:NS..CSG SFLU.DiL DPHI.FOC NFDC. FDC N PH I. C NL RCNT. C~NL GR. CNL TENS. CSG SFLU.OIL DmHI.FDC NFDC.FDC N,~HI .CNL RCNT. CNL GR. CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC N~OC.FOC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG PAGE: 13 -999.250 -999.,250 -999.250 -'999'250 -999.250 -999.250 34'70'000 :-999'250 -999.250' -999.250 -999.250 -999'25:0 -999.250 :3330.000 -999. 250 -999:- 25:0 -999.250 -999.25:0 -999. 250 -999.250 3354.000 -999.250 -999.250 -999.250 -999'25:0 -999.250 -999.250 3214.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3180.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3040.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3044.000 ,IS TAPE VERIFICATION LISTING ;CHLUMBE~GER AiLASKA COMPUTING; CENTER DEPT. : SP. OIL R H O B. F O C CRLI. FDC TNPH.CNL RCFT. CNL C a L I' C NL DEPT. SP. OIL RHOB.. FDC C A L I o F D C TNPH.CNL RCFT.CNL CALI.CNL O E 'P ~T. SP.DIL RHOB. FDC C AL I. FD C T N PM. C NL RCFT.CNL C ALI. CNL DEPT. SP.OIL RHOBoFDC CALI.FDC TNPH. CNL RCFT. CNL CALI.CNL DEPT. SP. DIL RHOB.FDC CALI.FOC TNPM.CNL RCFT.CNL CALI.CNL DEPT. SP.OIL RHOB.FDC C~LI.FDC TNPHoCNL RCFT.CNL CALI.CNL DEPT. SP-DIL RHOB.FDC CALIoFDC TNPH. CNL RCFT.CNL 2700.000 -999.250 - 999.250 -999.250 -99'9.250 - 999.250 -999-250 2600.000 -999.250 -999.250 · -999.250 -999. 250 -999.250 -999.250 2500.000 -999.250 -999.250 -999.250 -9 99.250 -99'9. 250 -999.250 2400.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2300.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2200.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2100.000 -999.250 -999..250 -999.250 -999.250 -999.250 iLO.OIL GR.DIL DR HO. FDC GR. FDC TNR.A .CNL C N'T C. C N L TENS.CNL ILO. OIL GR. O IL OR HO. F DC GR. FOC T N R A. C NL CNTC oCNL TENS.CNL ILD.:OIL GR. 'OIL DRHO, FDC GR. FOC TN R A o CNL CNTC. CNL TENS .CNL ILD.DIL GR.DIL DR MO. FDC GR. FDC TNRAoCNL CNTC. CNL TENS .CNL I'LOo 0 IL GR.OIL DRHO.FOC GR. FDC TNRA.CNL CNTC.CNL TENS.CNL ILO.OIL GR.OIL DRMO.FOC GR.FDC TNRA.CNL CNTC.CNL TENS .CNL ILO.OIL GR.OIL ORHO.FDC GR.FDC TNRA.CNL CNTC.CNL 14.-N 0 V-1989 ! I: 5:0 -999. 250 -999.250 -999.250 -999.250 -999' 250 - 999.25-0 -999.250 -999.250 -999.250 · - 999. 250 '-999.250 -999.250 -'999.250 -999° 250 -999.250 -999.250 -999.250 -999.250 -999°250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 I LMo O IL TENS.OIL FFDC. FOC TENS.FOe NPOR.CNL CFTCoCNL GR.CSG ILM'OIL TENS.OIL F F DC. F O C TENS. FDC NPOR.CNL C FTC ' C NL GR .C SG ILM. DIL TENS.OIL FF DC ' F DC TENS'FDC N P OR'. C N L CFTC. C NL GR.CSG I L M. D ! :L T E N $. D I :L FFDC'FDC TENS'FDC N P O R. C N:L C FTC. C NL GR.CSG ILM.DIL T E NS. D'IL FFOC. F DC TENS.FOC NPOR. C NL CFTC.CNL GR.CSG ILM.DIL TENS.OIL FFDC.FDC TENS.FOC NPOR.CNL CFTC.CNL GR.CSG ILM.DIL TENS.OIL FFOC.FDC TENS.FDC NPOR.CNL CFTC.CNL -999. 250 -999. 250 -999.2 50 -999.250 -999. ZSO -999.250 34. :344 '-999.250 -999.250 - 99 9.250 -999.250 -999-250 -999.250 31.016 -999.250. -999.250 - 999.250 -999.250 -999.250 -999.2 50 28.828 -999.250 -999.250 -999.25:0 -999.250 -999.250 -999.250 23.344 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 36.313 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 26°359 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 ;FLU. OIL DPHIoFDC FOC. FDC P H I. C N L C NT. CNL G R. C N L TENS.CSG SFLU. OIL DPHI. FDC NFDC.FDC NPHI.. CNL RCNT.CNL GR.CNL TENSoCSG SFLU.DIL DPHI. FDC NFDC. FDC NPHI. CNL RCNT. CNL GR. CNL TENS.CSG S FL U. D I L DPHI. FDC 'NFOC. FDC NPHI.CNL RCN'T.CNL GR .CNL TENS.CSG S FLU. D I L DPHI.FDC N FDC. FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FOC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU. DIL DPHI.FDC NFDC.FDC NPHIoCNL RCNT.CNL GR.CNL PAGE: 14 -999- 2 50 -999.250 -999. 250 -999. 250 -999.25:0 -999.250 2934.000 -999. 250 -999.250 -999'250 -999. 250 -999.250 -999.2510 2894. 000 -999. 250 -999.250 -999. 250 -999.250 -999.Z50 -999. 250 2860. 000 -999,25:0 -999.250 -99'9.250 -999.250 -999.250 -999.250 2824.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2794.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2764.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 IS TAPE VERIFICATION lISTING CHL:UM~.~ERGER ALASKA COMPUTING CENTER l~-NQV-1989 11:50 C A L I . C N L -999.2 $ 0 T E N $ . C N L - 999.250 G R . C $ G DEPT. SP. Oil EHOO.FOC C AL I. FDC T NPH. CNL R CF T. CNL iC AL I- CNL DEPT. SP.DIL RHO B. FOC C ALI. FDC TNPH.CNL RCFT.CNL C AL I. CNL 2000. 000 ILO. - 999.2 50 G R. D I L -999.250 OEHO. FDC -999. 250 GR. FDC -999.250 TNR~,.CNI -999.250 CNTC.CNL -999.250 TENS.CNL 1900-~000 ILO. O IL -999.250' GR.OIL -999.250 DRHO.FDC -999.250 GR.FOC -999.250 T~N~A.CNL -999.250 CNTC'CNL -999.250 TENS.CNL 36.031 OEPT. SP.OIL R H O B. F D C C ~:L I. FDC T NPH. CNL R CFT. CNL C At I. CNL -999.250 ILM.DIL -999.-250 -999.250 TENS'OIL -999.250 -999.250 FFDC. FDC -999.250 -999°,250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999. 250 CFTC.C N[ -999. Z50 -999. 250 GRoCSG 3~.469 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -:9'99.250 FFDC.FDC -999.250 - 99'9. 250 TENS.FDC -999.250 -999.250 NPOR..CNL .-999.250 -999.:250 CFTC..CNL -999.250 -999,.250 GR.CSG 36.875 1800.000 ILD.DIL -'999.250 ILM.DIL -9'99.250 -999.,250 GE.OIL -999.250 TENS.OIL -999.250 -999.250 ORHO.FDC -999.,250 FFOCoFDC -999.250 -999'250 GR. FDC -999.250 TENS.FDC -999.250 -999.250 'TNRA.CNL -999.250 NPOE.CNI -999.250 -99:9. 250 CNTC.CNL -999.250 CFTCoCNL -999.250 -999.250 TENS.CNL -999.250 GR.CSG 33.53i DEPT. 1700.000 ILO.OIL .-999.250 ILM.OIL -999.250 SP. OIL -999.250 GE.OIL -999.250 TENS.OIL -999..250 RHOB.FDC -999.250 ORHO.FDC -999.250 FFOC.FOC -999'250 CALIoFDC -999.250 GR.FOC -999.250 TENSoFOC -999.250 TNPH.CNL -:999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCFT-CNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 CALI.CNL -999.250 TENS.CNL -999.Z50 GR.CSG 31.281 DEPT. SP.DIL RHOB.FDC CALI. FDC TNPH.CNL RCFT.CNL CALI.CNL 1600.000 ILO.OIL -999.250 ILM. DIL -999.250 -999.250 GR.OIL -999.250 TENS.OIL -999.250 -999.250 DRHO.FDC -999.250 FFDC.FDC -999.250 -999.250 GR.FDC -999.250 TENS.FDC -999.250 -999.250 TNRA.CNL -99:9.250 NPOR.CNL -999.250 -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 -999.250 TENS.CNL -999.250 GR.CSG 15.547 DEPT. 1500.000 ILO.OIL -999.250 ILM.DIL -999.250 SP.DIL -999.250 GE.OIL -999.250 TENS.OIL -999.250 RHOBoFOC -999.250 DRHO.FOC -999.250 FFDC.FOC -999.250 C~II.FDC -999.250 GR.FDC -999.250 TENS.FO' -999.25Q TNPH.CNL -999.250 TNRA.CNL -099.250 NPOR.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 CALI.CNL -999.250 TENS.CNL -999.250 GR.CSG 28.578 TENS.CSG SFLU-DIL OPHI. FOC NFDC. FDC NPHI.. CNL R: C N T. C N L GR.CNL TENS.CSG SFLU.OIL DPHI.FDC NFDC.FOC NPHI.CNL RCNT.CNL GRoCNL TENS.CSG SFLU.OIL DPHI.FOC NFOC.FDC NPHIoCNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GE. CNL TENS.CSG SFLU.DIL OPHI.FOC NFOC.FDC NPHI.CNL RCNT.C'NL GR.CNL TENS .CSG SFLU.DIL DPHI.FDC NFDC.FOC NmHIoCNL RCNT.CNL GR.CNL TENS.CSG DEPT. 1400.000 ILO.OIL -999.250 ILM.DIL -999.250 SFLU.DIL SP.OIL -999.250 GE.OIL -999.250 TENS.DIL -999.250 DPHI. FDC RHOB.FOC -999.250 DRHO.FDC -999.250 FFDC. FDC -999.250 NFDC.FDC CALI.FDC -999.250 GR.FDC -999.250 TENS.FDC -999.250 NPHI.CNL TNPH.CNL -999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCNT.CNL PAGE: 15 Z750.. 000 -999. 250 - 99'9 - 25:0 -999.250 -'999' 250 -999.250 -999. 250 2634.000: -999. 250 -:999.250 -999. 250 -999 - 250 -999' 2'50 -999.250 2634'000 -999 · 25'0 -999.250 -999.250 -999. 250 -999. 250 -999 o 250: 2584.:000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2540.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2550.000 -999.250 -999.250 -99~.250 -999.250 -999.250 -999.250 2474.000 -999.250 -999.250 -999.250 -999.250 -999.250 .IS TAPE VERIFICATION LISTING ~CM'LUMBERGER ALASKA COMPUTING CENTER RCFT. CNL C AL I. CNL -999.250 CNTC.CNL -999.250 TENS.CNL DEPT, SP, R H O 8. F O C C Al I, FDC TNPH. C NL RCFT,CNL CALI.CNL ! 300- 000 ILO,, OIL -999,250 GR.DIL -999,250 gRMO.FDC -999,250 GR.FDC -999.250 TNRA.~CNL -99'9.250 CNTC.CNL -999.250 TENS.CNL DEPT o SP, OIL RHOB.,FOC C AL I, FD C TNPH,CNL R C FT,. CNL C A.L I. C N L 1200,00:0 ILO,OIl -999,250 GR,DIL -999.250 ORHO,FDC -999.250 GR.FDC -999,250 TNRA,CNL -999. 250 CNTC.CNL -999.250 TENS.CNL DEPT. 1[00.000 ILO.OIL SP.OIL -999.250 GR-DI:L ~,HOB. FDC -999.250 DRHO'FDC CALIoFDC -999.250 GR. FOC TNPHoCNL -999,250 TNRA,CNL RC'FT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT, 1000. 000 ILO, OIL SP, OIL -999,250 GR,DIL RHOB.FDC -999.250 ORMO.FDC CALI.FDC -999.250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999,250 TENS.CNL DEPT. 985.000 ILD.DIL SP.DIL -999.250 GR.DIL RHOB.FDC -999.250 DRHC,FDC CALI.FDC -999.250 GR. FDC TNPH. CNL -999,250 TNRA.CNL RCFT.CNL -999.250 CNTC'CNL CALI.CNL -999.250 TENS.CNL END OF DATA Ii-NOV-lO89 11:50 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 30.516 -999.250 ILM. DIL -999.250 TENS,OIL -999,250 FFDC,FDC -999,250 TENS.FOC -999.250 NPO:R.CNL -999..250 CFT~C.CNL -999.250 GR.CSG -999.250 -999.250 -999,250 -999.250 -999°250 -999.250 17.188 -999,250 ILM. D!L -999,250 -999,250 TENS.OI~L -99'9,250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.25:0 -999,250 NPDR,CNL -999.250 -999.250 CFTC.CNL -999.250 -999,250 GR.CS'G 24.906 -999,250 ILM-DIL -999.250 TENS,,DIL -999,250 FFDC, FDC -999.250 TENS'FOC -999.250 ;NPOR,CNI -999,250 CFTC.CNL -999.250' GR.CS~G -999.250 -999.250 -999.250 -999.250 -999. 250 -999,250 18,359 -999,250 ILM-DIL -999,250 -999,250 TENS,OIL -999,250 -999.250 FFDC.FDC -999.250 -999,250 T'ENSoFOC -999.250 -999,250 NPOR,CNL -999,250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 31.000 -999,250 ILM.DIL -999,250 -999,250 TENS.OIL -999,250 -999,250 FFDCoFDC -999,250 -999,250 TENS,FDC -999,250 -999,250 NPOR,CNL -999,250 -999,250 CFTC.CNL -999,250 -999.250 GR.CSG 26.688 GR.CNL T E'N S .. C S G SFLU. OIL OPHI.FDC NFDC,FOC NPHI.,CNL ECNT,CNL GR,CNL TENS.CSG SFLU.OIL DPHI.FDC NFOC.FDC NPHI.CNL RCNT-CNL GR.CNL TE'NS.CSG S FLU. O I L DPMI, FDC NFDC, FDC NPHI, CNL R C N T. C N L GR, CNL TENS.CSG SFLU,DIL O:P. HI,FDC NFDC,FOC NPHI,CNL RCNToCNL GR.CNL TENS.CSG SFLU.OIL DPHI,FDC NFOC,FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG PAGE: -999, 234.0' -999. - 999. -999. -999. '- 99' 9. -999. 2260. -999. -999' -999. -999. -999' -999.. Z21~0. -999' -999~ -999. -999. -999. -999. 216¢. -999' -999, -999, -999, -999, -999' 2110. -999. -999, -999. -999, -999, -999. 2130, t6 250 000 250 25O 250 250 250 250 0 00 .250 250 ZSO 250 250 250 O00 250 250 250 250 250 250 250 250 25:0 25O 250 25O 000 25O 25O 25O 25O 250 25O 000 IS TAPE VERIFICATION LISTING CHLUMBERGER aLASKA COMPLETING CENTER 14-NOV-1989 11:50 PAGE: 17 **** FILE TRAILER **** FILE NAME : EDIT .0Ol SERVICE : FLIC VERSION : 001A02 DATE : 89/11/14 MAX REC SIZE : 102,4 .FILE TYPE : LO LAST FILE : **** ~F~LE HEADER FILE NAME : :EDIT ,.002 SERVICE : FLIC VERSION : O01A02 DATE : 89/11/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE , * FILE - EDIT.O02 * ARCO ALASKA, INC. , KUPARUK , 2K- 18 * 50-103-20117-00 , HIGH RESOLUTION PASS DATA , * DATA SAMPLED EVERY -.1000 FEET , DATA INCLUDED - * TOOL EXTENSION TOOL , TYPE USED NAME * FOC .FDH FORMATION DENSITY 7913' TO 7453' * CNT-A/D/H .CNH COMPENSATED NEUTRON 7899· TO 7453~ .IS TAPE VERIFICATION LISTING ;CHLUMBERG~R ALASKA COMPUTING CENTER 14-NO'V-1989 11 '.150 PAGE: 18 TABLE TYPE : CONS TUNI VALU DEFI CN AR:CD ALASKA, INC,, FN KUPARUK WN 2K - lB APIN 5 O- 10 3-2:0117- O0 FL ],94e FNL & 94m FEL SECT TOWN 1ON RANG COUN NORTH SLOPE STAT ALASKA N ATI A WITN DIXON/LOWEN SON 548373 PDAT MSL E PD FT 0. LMF RKB A P O F T 154. E K B FT · 1 54. EOF FT 1 53. EGL FT 113. TOO FT 7960. STEM OEGF -gOO. Z5 COMPANY NAME FI ELD NAME WELL NAME API SERIAL. NUMBER FIELD LOCATION SECTION TOWN SM I P' RANGE COUNTY STATE OR PROVINCE NATION WITNESS'S NAME SERVICE ORDER NUMBER PERMANENT DATUM LOG MEASURE[:) FROM TABLE TYP~ : CURV DEFI DEPT DEPTH CHANNEL N,~ME [:)PHI DENSITY POROS ]~TY RHOB BULK DENSITY DRHO DELTA RHO FFDC FAR FDC COUNT RATE NFOC NEAR FDC COUNT RATE CALI CALIPER GR GAMMA RAY TENS TENSION NPHI NEUTRON POROSITY TNPH THERMAL NEUTRON POROSITY TNRA CALIBRATED THERMAL NEUTRON RATIO NPOR NEUTRON POROSITY OUTPUT FROM AN APPLICATION PROGRAM RCNT RAW CORRECTED NEAR THERMAL COUNTS RCFT RAW CORRECTED WAR THERMAL COUNTS CNTC CORRECTEO NEAR THERMAL COUNTS CFTC CORRECTEO FAR THERMAL COUNTS GR GAMMA RAY CALI CALIPER TENS TENSION IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER l~-NOV-19Bg 1I:50 PAGE: 19 DATA FORMAT SPECIFICATION RECOil] -~* SET TYPE - 64EB TYPE REPR CaOE V 8, LUE I 66. 0 2 66 0 3 ?3 80 4 66 1 5 66 6 73 ? 65 $ 68 0.099 g 65 FT 11 66 1Z 1Z 68 13 66 0 14 65 ~T 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ 'LOG TYPE CLASS MOO NUMB SAMP ELE:M CODE (HEX) DEPT FT 548373 O0 DPHI FDH PU 548373 07 RHOB FOH G/C3 548373 07 DRHO ~OM G/C3 548373 07 FFOC FOH CPS 548373 07 NFDC FDH CPS 548373 07 CALI FOil IN 548373 OT GR FDH GAPI 5&8373 07 TENS FDM LB 548373 07 NPHI CNH PU 548373 07 TNPH CNH PU 548373 07 TNRA CNH 548373 07 NPOR CNH PU 548373 07 RCNT CNH CPS 545373 07 RCFT CNH CPS 548373 07 CNTC CNH CPS 5483 73 07 C~TC CNH CPS 548373 07 GR CNH GAPI 548373 07 CALI CNH IN 548373 07 TENS CNH LB 548373 07 000 O0 0 2 I I 4 68 0000000000 635 21 0 Z I I 4 68 0000000000 3'50 OZ 0 Z 1 I 4 68 0000000000 356 O1 0 2 I 1 4 68 0000000000 354 02 0 2 i I 4 68 0000000000 354 01 0 2 I I 4 68 0000000000 i80 01 0 2 I I 4 68 0000000000 310 01 0 2 I I 4 68 0000000000 635 21 0 2 I I 4 68 0000000000 890 O0 0 2 I I 4 68 0000000000 890 O0 0 2 I I 4 68 0000000000 420 01 0 2 I I 4 68 0000000000 890 O0 0 2 I I 4 68 0000000000 420 O1 0 2 1 I 4 68 0000000000 420 01 0 Z I I ~ 68 0000000000 420 O1 0 2 I 1 4 68 0000000000 420 01 0 Z I I 4 68 0000000000 310 O1 0 2 I 1 4 68 0000000000 280 O1 0 Z I I 4 68 0000000000 635 21 0 2 I 1 4 68 0000000000 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA. COMPUTING CENTER :,I,:. ID AT A DEPT. 7951.200 OPHI.FDH FFDC-FDH 1497'000 NFDCo:FDH T E N S' F O H 3990.000 N P H I - C N H NPOR.CNM 35. 596 RCNT. CNH CFTC..CNM 8!8. 218 GR. CNH OEP'T. FFDC. FDH TENS.FDH NPOR.CNH CFTC.CNH :DEPT. FFDC. 'FOH TENS.FDH NPOR.CNH CFTC.CNH DEPT. FFDC.FDH TE'NS.FDH NPOR. CNM CFTC.CNH DEPT. FFDC. FDH TENS.FDH NPOR.CNH CFTC.CNM DEPT. FFOC.FOH TENS.FOH NPOR.CNH CFTC.CNH DEPT. FFDC.FDH TENS.FDH NPOR,.CNH CFTC-CNH 7900.000 DPHI.FDH 51Z 8.500 N~F 0 C. ~F O H 5768.000 NPHI.CNH 38.5¢5 RCNT.CNH 770. 767 GR.CNH 7800.000 ' OPHI.FDH 401.750 NFOC.FOH 5648.000 NPHI.CNH BT. 371 RCNT. CNH 756o409 GR.CNH 7700.000 OPHI.FDH ¢30.750 NFOC.FOH 5492.000 NPHI.CNH 35.916 RCNT.CNH 870. ! '87 G R . C N H 7600-000 DPHI.FDH 463,.250 NFOC.FDH 5 ! 2. 0.000 N P H I. C N it 27.236 RCNT-CNH 1402.780 GRoCNH 7500.000 DPH[.FOM 564.00-0 NFDC. FDH 5680. 000 NPHI. CNH 39.494 RCNT.CNH 665.847 GR.CNH 7423. 899 DPHI.FDH 238.875 NFDC.FDH 5340.000 NPHI.CNH 49. 550 RCNT. CNH 377.462 GR.CNH END OF DATA 14-NO¥-lgB9 11:50 3'1.974 961..000 39.688 2349.936 t40.250 1¸2., 635. 39. 2375. 1 ¢ O. . 532. 36. 2158. 110o 577. 37- 2370. 107. 10. 595. 3252. 95. 637. 41. 2025. 141. 30. 164. 53. 1428. 86. 2:38 5OO 9~94 515 250 974. 000 226 957 O00 721 5OO 3O,4. 787 813 138 50O 73,~ 651 50O 562 5O0 783 4.68 625 276 625 518 897 875 RHOB.FOH CALI'FDH T N P H. C N H R C F T. C N H C AL I. C NH RHOB.FDM CALI .FOH T N P H. C N H R C F T. C .NH C A L I. C N H RHOB.FDH CALI.FOH 'TNPH. CNH RCFT.CNH CALI.CNH RHOB"'FDH CALIoFDH TNPHoCNH RCFT.CNM CALIoCNH RHOB. FDH C ALI. FOH TN PH. C NH RC F T. C NH CALI.CNH RHOB. FDH CALI.FOH TNPH.CNH RCFT.CNH CALI.CNH RHOB. FDH CALI"'FDH TNPH.CNH RCFT.CNH CALI.CNH 2-122 3.2. 52 35.596 720. 823 3.252 2.448 6.867 38"'043 677.582. 4.867 2.502 6.219 36.98:3 632.887 6. Z19 2.506 6.258 35.1ZZ 808.500 · 6. 258 Z. 4.8:3 6.285 26.651 1272.030 6.2.85 ?..410 7.008 37.826 666.4.17 7. OOB 2.150 6.281 49.370 390.240 6.281 DRHD.FOH GR.FOM TNRA.CNH CNTC.CNH TENS.CNH D, RHO.FDH GR.FDH TN,RA.CNH CNTC.CNH TENS.CNM DRflO. FDM G R. FDH TNRA.CNH CNTC"'CNH TEN S. CNH DRHO.FDH GR.FDH TNR~.CNH C NT C. C N H T E N S. C N H DRHO. FD M GR.FDH TNRA.CNH CNTC. CNH T E NS., CNH DRHO.FDH GR.FDH TNRA.CNH CNTC.CNH TENS.CNH ORHO.FDH GR.FDH TNRA.CNH CNTC.,CNH TENS.CNH PAGE:' ZO 0.153 2.977 Z398.325 399 O. 000 0.056 140.250 3.091 2380.298 5768.000' -0.002 110.000 2.966 228B.290 564.8'000 0.03I 107.813 3.027 .:2530.087 5¢g2.000 0.037 95.500 2.440 3308.326 5120.000 0.044 141.625 3.317 2076.595 5680.000 -0.565 86.875 3.914 1438.673 5340.000 IS TAPE VERIFICATION LISTING CHLUMBERGER aLASKA COMPUTING CENTER 14-NOV-1989 11:50 PAGE: Z1 **** FILE TRAILER FILE NAME : EDIT SERVICE : FLIC VERSION DATE : ~9/11/14 MAX REC :SIZE : 1024 FIL~ TYP~ : LO LAST F~L~ **** TAPE 'TRAILER **** SERVICE NaME : EOIT DATE : 89/11/14 ORIGIN : FLIC TAPE NA~ : 7353~ CONT'INUAT!DN ~ : 1 COMMENT : ARCO ALASKA~ INC. ,KUPARUK e2K - 18 ~50-103-20117-00 **** REEL TRAILER SERVICE NAME : ~DIT DATE : 89/11/1~ ORIGIN : ~:LIC REEL NAME : T353~ CONTINUATION ~ : PREVIOUS REEL : COMMENT : RRCO ALASEA, INC. ~KUP~RUK ~ AL~SK~ CgMPUTING CEN'TER · ~ ....... SCHLUMBERGER ......... ~ COMPANY NAME : ARCO ALASKA, INC. 'WELL NAME : 2K- 18 :IELD NAME : KUPA~UK BOROUGH : NO. RTH SLOPE STATc~. : ~L~,SK~ AP[ NU~51E~ : ~E~ERENCE NO : 73:534 IS 'TAPE VERIFICATION LISTING ,. C~UTING C:NT~R CMLUMB~RG=R ALASKA-.~.~ .... ~ ' 30-NOV'-1989 09:09 ***# REEL HEADER SERVICE N~ME : EOIT DATE : OR~GIN : PLIC REEL NAME : 'CDNTINU~TIg~L~ ': ~REVIDUS ~E : COMMENT : ~RCO ~LASK~ INC. ~KUP~,RUK ,2K- 18 ~50-103-Z0117-00 SERVICE NAME : OAT[ : ORIGIN : FL!C CONTINUATION PREVIOUS T~PE ~ ARCO ALaSKa, INC ,KUF~RUK ,2K- 18 ,50-103-2011~'-00 COMMENT ,:*** F FILE NA~E : :EOtT .00t SERVICE VERSION : O01~O~ DAT~E : ~9/11/30 MAX ~C S!Z~ : 1024 FILE %YP~ : LO LAST FILE : COMOANY N~ME: ~RCO ALaSKa, INC. WELL: 2K - 18 FIELD: KUP~RUK BOROUGH: NO~TH SLOPE STATE: ~L ~SK.A A~I NUM~E~q: 50-1,33-20117-00 LgC&T!gN: 19~~ FNL g 94~ FEL S~CTION: 11 TOWNSHIP: ION RANG:_: IS TAPE VERIF'[C~TION LISTING CHLUNBERG~ER ALASK, 5 COMPUTING CENTER 30-NOV-1989 PAGE: P~RMANENT D~TUM: MSL ELEVATION: 0 LOG MEASURED FROM RKB 154 ~,SOVE PERMANENT DATUM !ELEVATIONS K!5: t54 ~ AT_ :LO GG RUN NUM~ER: TO DRILLER: T'D LOGGER: 01-NOV-i989 7960 7949 CASING: 7" 26 L5 2 DRILLER DEi,~TH ~F ?458 BIT SIZE: 5 1/,.8" TYPE FLUID ~N HOLE: LSND POLYMER ~ENS~ZTY: 10.1 VISCOSITY: 40 PH: 8.5 FLUIO L~SS: MUD R !£S ISTZVZ'TY: FILTRATE RESISTIVITY: MUD C~KE RE~SISTZVITY: 3.48 @, 55 2. g 5 ~ 65 3.35 @ 64 TIME CIRCULAT'ION ENOEO: 19,~30 01-NOV 'TIME LOGGER ON 5OTTOM: 00:44 O2-NDV M~XIMUM TEMP RECORDSO: 154 ~L 0 G G t N G O I S T R I C T: LOGGING ENGINEEr: WITNESS: PRUDHOE FRIT,ZKE DIXON/:LOWEN 'TOOL NUMBERS: IEM 134B ~SGC 2479 CNC 1238 OIC NLM t335 PGS 508 DIS 1~57 PGC 1041 FIELD REMARKS: Ng STANDOFFS USED ON THE giT BECAUSE OF THE SM~LL HOL~ SIZE. ~AT~!X DENSITY = 2.65 G/CC.~ ~LUID DENSITY = 1.0 G/CC. NEUTRDN M~TRIX = SAND, HOLE CQRRECTION = C~LIPER. P~O EL'EV~,T~ON = 118 FEET. HIGH RESOLUTION P~SS LOGGED BUT NOT PRESENTED ON =ILMS. NO BOWSPRING USED ON CNL DUE TO SMALL HOLE SIZE. M&XIMUM DEVIATION = 42.~ DEGREES @ Z$Og' THE SP W4S NOISEY AND ERRATIC IN INTERV.~ FROM 7790' TO ?852'. ON THE 1.2" P~SS, THE TOOL W~S STICKING IN INTERVAL FROM 7790, TO 7852' THE GAMM& RAY AS WELL NOT REPEAT WEL~ IN INTERVal FROM 7860' TO THEY ~PPESREO TO ~E RELATED. POSSISLY LOOSE ROCK FROM THE SIDE DF HOLE MAY H~VE F~LLEN IN ON THE TOOL. N3 FURTHEq mASSES WERE MAOE ~S PER CLIENT REQUEST. HIGH PESOLU'T[DN PASS W~S USED AS THE REPEAT SECTION. D&T~ JOB STARTED: T-NOV-89 JOB REFERENCE NO: 7353~ TAPE VERIFICATION LISTiNS CHLUM~E~G~R AL~$K~ CCMPUTiN~,~ CENTER 30-NO'V-IgS9 OD:OD PAGE: LO:P/ANA: KOHRING CgMPU'TING CENTER REMARKS: THIS CORRECTED TAPE R~PL~CES THE LIBRARY TAPE DATED I~-NOV-$go E~RONEOUS S~IKES ~N THE OIL/G~ FROM T550 Tg 7525' WERE REMgVEgo FILE- iEDIT.O01 ARCO ALASKA, !NC. KUPARUK 2K - 1~ 50-103-20117-00 MAIN ',~ASS LBG DATA O~TA SAMPLED EVERY -.5000 F~ET OATA INCLUOED- TOOL EX TENS ION TOOL TYP~E USED NAME OIT-O .OIL FDC .FOC CNT-~/O/H . CNL GR .CSG DUAL INDUCTION SFL FORMATION D~NSZTY COMPENSATED NEUTRON GAMMA RAY 7938' 'TO 7453' 7913' TO 7453' TBg9' TO 7~53' 7~07' TO 990' T~BLE TYPE : CONS TUN~ V AL U D: F I CN FN WN APIN FL SECT TOWN RANG COUN STAT NATI WITN SON PD~T ARCO ALASKA~ INC. KUP,~RUK 2K- 1~ 50-103-20117-00 lO4" ~NL & 94' 1ON NORTH SLOPE ~LASK~ USA ~ IXgN/LOWEN 5~8373 ~SL COMPANY N~ME FIELD NAME WELL NAME API SERIAL NUMSER =IELD LOC~TION SECTION TOWNSHIP RANGE COUNTY STATE gR PROVINCE NATION WITNESS' NAME SERVICE ORDER NUMBER PERMANENT OATUM IS TAPE VERIFICATION LI.STING CHLUM~ERGER .aLASKA CgMPUTIN~ CENTER 30-NOV-1989 09:09 PAGE: TUNI VALU OEFI E PD FT L MF APO FT EKE. FT E DF PT Ertl FT TOD FT B t I FT TLI FT TCS TLA~ STEM DEGF O. RKB 154. 154. 153. 113. 7960. 7 938. 990. 19:30 Oi-NDV 00:44 02-NOV -999.25 LOG MEA'SURED FROM BOTTOM LOG INTERVAL TOP LOG INTERVAL TIME CIRCULATION 'STOPPED TIME LOGGER AT BOTTOM TABLE TYPE : CURV DEPT ILO ILM SFLU S P GR TENS D PHI RHOB DRHO FFDC NFDC C ~L I GR TENS NPHI TNPH TNRA NPOR R CNT RCFT CNTC C;TC GR CALI TENS G~ TENS OEFI DEPTH CHANNEL NAME DEE~ INDUCTION STANOa~D PROCESS~50 RESISTIVI'TY MEOIUM INDUCTION STAND~RD PROCESSED RESISTIVITY SFL RESISTIVITY (UNAVER~ED) SPONTANEOUS POTENTI~,L GAMM~ R~Y T'E N S I O N DENSITY ~O~DS[TY BULK DENSITY DELTA RHO FA~ FgC COUNT ~TE NEAR FgC COUNT RATHE GA~ RAY TENSION NEUTRON ~O~OS ['TY THERNAL NEUTRON POrOSiTY CALZ~RATED THE~N~L NEUTRON NEUTRON ~OROS[TY OUTPUT FRON ~N APPLZCET[ON ~RgGRA~ ~AW NEAR CNT COUNTS R~W ~R CNT COUNTS CORRECTED NEaR THERmaL COUNTS CORRECTED ~R THERMAL COUNTS CALIPE~ TENSION G~M~ ~, q~Y TENSION IS 'TAPE VERIFIC.~TI~N LISTINS CHLUMBERG~R ALASK~ COMPUTING CENTER 30-NOV-1989 O9:Og PAGE: DATA ~ORM~T SPECIFIC~TIEN RECORD ~ SET TYPE - 64EB ~ TYPE 1 66 Z ,66 3 73, 4 66 5 66 6 73 7 65 8 68. 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 REPR CODE VALUE 0 0 '1 O. 5 ~T 9 0 FT ! 0 ~ SET TYPE - CHAN ~ ,IlIltitIllllItIllI'II NAME SERV UNIT .SERVICE AP1 AP1 ADI ~PI FILE NUMB NUMB SIZE REPR IO ORDER :~ LOG 'TYPE CLASS MOD NUMB SAMP ELEM DEPT FT 548373 O0 ILO DII ~HMM 548373 07 ILM DIL CHMM 54837) 07 SFLU DIE OHMM 5,48373 07 SP OIL MV 545373 07 GR OIL G~PI 54~373 07 TENS OIL LB 548373 07 DPHI FOC PU 548373 RHO~ FDC G/C3 .548373 07 DRHO FCC G/C3 548373 07 FFD.C FDC CPS 54~3'73 07 NFDC FD.C C~S 548373 07 CALI FDC IN 548373 07 GR FOG GAPI 54 93T3, 07 TEN5 FDC LB 548373 07 NOHI CNL PU 54~373 07 TNPH CNL PU 549373 07 TNRA CNL 549373 07 NPOR CNL PU 548~T3 RCNT CNL CmS 548373 07 RCFT CNL CPS 54~37B 07 CNTC CNL C~S 5483T3 CFTC CNL C°S 548373 07 G~ CNL GAP~ 548373 07 CALI CNL IN 549373 07 TENS CNL L3 54:~373 07 CODE OOO O0 0 I 1 1 4 68 120 46 0 1 1 1 4 68 120 .44 0 1 1 1 4 68 220 Ol 0 1 1 I 4 68 010 O1 0 1 1 1 4 68 310 O1 0 1 1 1 4 68 635 Z1 0 1 1 1 4 68 635 2't 0 1 1 1 4 68 350 OZ 0 I I I 4 68 356 O1 0 1 1 1 ¢ 68 354 OZ 0 I 1 1 4 68 354 O1 0 1 1 1 4 68 280 O1 0 1 1 I 4 68 310 O1 0 I 1 I 4 68 635 21 0 1 1 1 4 68 890 O0 0 1 1 1 4 68 890 O0 0 1 1 1 4 68 4.20 Ot 0 I 1 I 4 68 890 O0 0 1 1 1 4 68 420 O1 0 1 1 1 4 68 420 O1 0 1 1 1 4 68 420 O! 0 1 1 1 4 68 420 O1 0 1 I 1 4 68 310 O1 0 1 1 I 4 68 280 O1 0 1 1 1 4 68 635, Zl 0 I 1 1 4 68 PROCESS (HEX) 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O00000OO00 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O00000OO00 0000000000 0000000000 OOOO000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS TAPE VERIFIC~TIgN LISTING CHLUMBERGER A.L~;SK4 COM~PUTIN~ CENTER 30-NOV-1989 09::09 PAGE: NAME SERV UNI'T SER:VZCE API API Ami API FILE NUMB NUMB SIZE REPR ORDER ~ EgG TYPE CLASS MOD NUMB SAMP ELEM CODE GR ~CSG GAPt 548373 07 3,10 01 0 I ! 1 4 68 TENS CSG L5 548373 OT 635 21 0 I 1 I 4 68 ~PROCESS (HEX) 0000000000 0000000000 DEPT- 7957. 000 ILO. OIL 1. 974 I~LM. OIL 1.746 SP.DIL -22.531 GR.DIL 119.~438 TENS.OIL 384~.0'00 RHOB. FDC 2.5'35: DRHO.~DC 0.186 FFDC.FDC 588.500 CALI.FDC 5.781 GR.FDC 119.438 TENS.FDC 3844.000 TNPH.CNL 138.4,44 TNRA.CNL 3.162 NPOR.CNL 38.444 RCFT.CNL 663.4~4 CNTC.CNL 2145.169 CFT:C.CNL ~53.131 CALI..CNL 5.781 TENS.CNL 3844.000 GR.CSG -999.250 DEPT. 7900.000 ILO.OIL ,2.9'73 ILM. DIL 3.030 SP,.DIL -25.469 GR.DZL ~I19.]75 TENS.OIL 6128.000 RHCE.FDC 2.403 gRHD. FDC 0.058 FFDC.FOC 593.000 CALI.FDC 6.063 GR.FOC 119.375 TENS,.FOC 6128.000 TNPH.CNL 35.788 TNRA.CNL 3,.018 NPOR.CNL 35.082 RCFT.CNL 690.854 CNTC.CNL 2']17.656 CF'TC.CNL 787.376 CALI.CNL 6.063 'TENS.CNL 6128.000 GR.CSG - 999~.,25.0 DEPT. 7800.000 ILO.OIL 3..421 ILM.DIL 3.472 SP.DI~L -49.000 GR.DIL 115.000 TENS.OIL 5752.900 RHDB.FDC 2.519 DRHD.FDC 0.025 FFDC..FgC 411.500 CALI..FOC 6.1~1 GR.FDC 115.000 TENS.FDC 5752.000 TNPH.CNL 38.241 TNRA.CNL 3.167 NPOR.CNL 37.030 RCFT.CNL 635.711 CNTC.CNL 2279. 783 CFTC.CNL 73,4.076 CALI.CNL 6.191 'TFNS.CNL 5'75Z.000 GR.CSG -999.250 DEPT. 7700.000 ILO.OIL 4.113 ILM. DIL 4.317 SP.DIL -40.000 GR.DIL t12.438 TENS.OIL 5552.000 RHOB.FDC 2.47~ DRHO.FDC -0.002 FFDC.FOC 429.750 CALI.FDC 6.273 GR.FOC 112.438 TENS. FDC 5552.000 TNPH.CNL 32.865 'TNRA.CNL 2.809 NPOR.CNL 35.248 RCFT.CNL 842.7~2 CNTC.CNL 2623.782 CFTC.CNL 949.743 CALI.CNL 6.273 TENS.CNL 5552.000 GR.CSG -999.250 DEPT. T~O0.O00 ILO.OIL 8.927 ILM.DIL 8.499 SP.DIL -39.500 GR.OIL 100.000 TENS.OIL 5412.000 RHOB.FDC 2.4~8 DRHC.FDC 0.019 FFDC.FDC 482.750 CALI.FDC 6.266 GR.FDC 100.000 TENS.FDC 5412.000 TNPH.CNL 27.110 TNRA.CNL 2.480 NPOR.CNL 27.96~ RCFT.CNL 1209.647 CNTC.CNL 3326.833 CFTC.CNL 1393.527 CALI.CNL 6.2~6 TENS.CNL 5412.000 GR.CSG 109.563 DEPT. 7500.000 ILO.OIL 2.675 ILM.DiL 2.693 SP.DIL -41.000 GR.DIL !42.750 TENS.DIL 5724.000 RHOB.F~C 2.453 gRHC.FDC 0.994 FFDC.FDC 573.000 CA:LI.FDC T.008 GR.FDC 142.750 TENS.FDC 5724.000 SFLU.DIL DPH'i. FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.OIL OPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU. OIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL ~TENS.CSG SFLU.DIL DPHI.FDC NFOC.mDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL D~HI.FDC NFDC.FCC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DmHI.EDC NFQC.FDC NPHi.CNL 1.693 6.998 752.500 40.299 2297.853 119.,435 -999.250 3.2 84 14.958 659.000 37.357 2309.168 119.375 · -999.250 4.070 7.960 564.500 .39.9~ Z295.089 115.000 -999.250 4.499 I0.65! 542.000 33.288 2425.967 112.438 -999.250 8.182 12.242 586.000 28.361 3182.746 100.000 5748.000 2.845 ll.gZo 681.500 42.743 IS TAPE V~RIFZCAT'~ON LISTING 'CHLUNiBE~RGER ~LAS:KA CO~PtJTING CENTER TNPH.CNL 37.6<~6 TNRA.CNL RCFT.CNL 544.4'84 CNTC.CNL C~,LI.CNL 7.008 TENS.CNL DEPT. 7400. 000 ILD. OIL SP..gIL -I6.453 GR.CI~L RHOB.FDC 2.173 DRHO.FOC C4. LI. FDC 6.156 G~.FgC TNPH.CN:L 40.650 TNRA.CNL RCFT.CNL 516. 193 CNT~C. C:NL C~LI.CNL 6.!56 TENS.CNL D OPT. 7300. 000 ILO. OIL SP.DI'L -999.250 GR.DIL RHD~.FDC -999.250 gRHO.FgC CALI.FDC -999.2'50 GR.FgC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -99:9.250 CNTC.CNL CALI.CNL '-999.250 TENS.CNL DEPT. 7200. 000 iLO.OIL SP. OIL -9 99.250 GR.DIL RHOB.FDC .-999.250 DRHDoFDC CALI.FDC -999. 250 GR. FOC TNPH.CNL -999.250 TN~,AoCNL RCFT.CNL -999.2 50 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 7100.000 ILO.OIL $~.gIL -999.250 GR.DIL RHOB.FDC -999.2~0 gRHO.FOC CALl. FDC -999.2 50 OR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C~LZ.CNL -999.250 TENS.CNL DEPT. 7000.000 ILO.OIL SP.DIL -999.250 OR.OIL RHDD.~DC -999.250 ORHO.FOC CALI.:DC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 6900. O O0 ILD. DiL SP.DIL -999.250 GR.DIL RHC~.FDC -999.250 DRHD.FDC CALI.'FDC -999.250 GR. FOC TNPH.CNL -999.2 50 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C4LI.CNL -9'99.250 TENS.CNL 3g-NOV-1989 09:09 3.369 NPDR.CNL 2043.729 CFTC.CNL 5 72,4. 000 GR.CSG 17.902 ILM. DIL 88.375 TENS.OIL -0.51,7 FFDC.FDC 88. 875 TENS-FDC 3- 229 NPOR.CNL 1749. 522 CFTC.CNL 5288,.§00 gR.CSG 40. 143 557.734 144. '500 2000.000 5288.00O 25,~+. 125 5288.000 42.787 537.166 61.750 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.. 250 -999.250 FFDC.FDC -999.250 -9'99.250 TENS. FDC -999.250 -999.250 NPOR.CNL -999.250 -999. 250 CFTC.CNL -999..250 -'999. 250 GR.CSG 102.438 -99'9.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS. FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 - 999. 250 GR.CSG 201:. 250 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999. !50 FFDC.FDC -999.250 --999..~50 TENS.FDC -999.250 -999.Z50 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.Z50 GR.CSG 94.375 -999.250 ILM.DIL -'999.250 -'999.250 TENS.DIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999. 250 CFTC.CNL -999.Z50 -999. 250 GR. CSG 107.750 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 ~:FDC. FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 - 999. Z5 O GR. C SG 84. 563 RCNiT.CNL G~.iCNL TENS.CSG SFLU.OIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG S~LU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLUoDIL D'mHI.FOC NFDCoFDC NPMI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI,-FDC NFOC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SmLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DmHI.:OC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG PAGE: 1894.559 142.750 5728..00~0 6.955 28.934 177.625 1635.978 88.875 5468.000 -999.2!50 -999.250 -999.250 -999.2!50 -999,°250 -999.250 5488.000 -999.250 -'999.250 -999.250 -999. 250 -999.250 -999.25C~ 5412.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 5260.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 5204.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 5200.000 IS TAPE VER!FICATIgN LISTING CHLUM~E~GER ~L~SK.~ COMPUTING C~NTER 30-NOV-1989 09:09 DEPT. 5800.000, ILO. OIL -999.250 ILM.DIL -999.250 SP.DIL -999.2!50 GR.DIL -999.250 TENS.OIL -999.250 RHOB.FD~C -999.250 DRHO.FDC -999.250 FFOC.FOC -999.250 CALI. mDC -999.250 GR.FOC -999.250 'TENS.FDC -999.250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPDR.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 C~LI.CNL -999.250 TENS.CNL -999.250 GR.CSG DEPT. 6700.000 ILO.OIL -'999.250 ILM.DIL .-999.250 SP.DIL -999.25,0 GR.OIL -999.250 TENS.git -999.2'50 RHOB.FDC -999.250 DRHg:. FDC -999.250 FFDC..FDC -999.250 CAL!.~DC -999.250 GR.FOC -999.250 T~NS.FgC -999.250 TNPH.CNt -999.250 TNR~.CNL -999.250 NPOR.CNL -999.250 RCPT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 C~LI.CNL -999.250 T~NS.CNL -999.250 GR.CSG 101.250 DEPT. 6600.000 ILD.DIL -999.250 ILM. DIL -999.250 SP.DIL -99'9.250 GR.DIL -999.250 'TENS.OIL -999.250 RHOB.FDC -999.250 gRHD.~DC -999.250 ~FDC.FDC -999.250 CALI,. FDC -999.250 GR.FDC -999,.250 TENS. FDC -999.250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPORoCNL -999.250 RCFT. CNL -999.250 CNTC.CNL -999,. 250 CFTC.CNL -999.250 C.ALI.CNL -999.~50 TENS.CNL -999.250 GR.CSG 76.375 DEPT. 6500.000 ILO.OIL -999.250 ILM. DIL -999.250 SP.DIL -999.250 GR.gIL -999.250 TENS.DIE -999.250 RHOB.FOC -999.250 DRHO.FDC -999.250 FFDC.FDC -999.250 CALI.FDC -999.250 GR.FDC -999.250 TENS..FDC -999.250 TNPHoCNt -999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 CAL!.CNL -999.250 TENS.CNL -999.250 GR.CSG 94.000 SFLU.DIL DPHI.FDC NFDC. FOC N P H Z. C N L RCNT.CNL GR oCNL T'<ENS.CSG SFLU.DIL DPHt. FDC NFDCoFDC N PHI. CNL RCNT.CNL GR.CNL TENS.CSG SFLUoDIL DPH'I. NFDC.FDC NPHI .CNL R CNT. CNL GR. C NL TENS.CSG S F:LU. D I t DPH I. FDC NFDC.FDC NPHt. CNL RCNT.CNL GR.CNL TENS.CSG DEPT. 6~O0.OOO ILO.OIL -999.250 ILM.DIL -999.250 SFLU.DIL SP.DIL -999.250 GE.OIL ,-999.250 TENS.OIL -999.250 DPHI.FDC RH~B.FDC -999.250 ORHO.FgC -999.250 FFDC.FgC -999.250 NFDC.FDC CALI.FDC -999.250 GR.FDC -999.250 TENS.FDC -999.250 NPHI.CNL TNPH.CNL .-999.250 TNRA.CNL -999.250 NPgR.CNL -999.250 RCNT.CNL RCFT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 GR.CNL CALI.CNL -999.250 TENS.CNL -999.250 GR.CSG B1.438 TENS.CSG -999.250 ILM.DIL -999.250 TENS.OIL -999.250 FFDC.FDC -999.250 TENS. FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 81.750 DEPT. 6300.000 ILP.DIL SP.OIL -999.250 GR.DIL RHOB.FDC -999.250 DRHC-.FDC CALI. FDC -999.250 GR. FgC TNPH.CNL -999.250 TNRA.CNL RC~T.CNL -999.2 50 CNTC.CNL C~LI.CNL -999.250 TENS.CNL SFLU.DIL DPHI. mDC N~=DC. MDC NPHI.CNL RCNT .CNL GR.CNL TENS.CSG DEPT. 6200.000 ILO.OIL -999.250 ILM.DIL -999.250 SFLU.DIL S~.DIL -999.250 GR.gIL -999.250 TENS.OIL -999.250 DPHI.FDC RHOB.FDC -999.250 DRHO.FDC -999.250 FFDC.FDC -999.250 NFDC.FDC C,~LI.FCC -999.250 GR. F,.gC -999..~_50 TENS.FDC -999.250 NPHI.CNL TNPH.CNL -999.250 TN'~.CNL -999.250 NPOR.CNL -999.250 RCNT.CNL RCFT.CNL -999.250 CNTC.CNL -999.25D CFTC.CNL -999.250 GR.CNL C~LZ.CNL -999.~_50 TENS.CNL -999.250 r~R.CSG 6~.28! TENS.CSG PAGE: -9'99.250 -999.250 -999.250 -999.250 -999.250 -999.250 5168.000 -999.250 -999.250 .-999.250 -999.250 '-999.250 -9'99.250 5152.000 -99 '9.250 -999.250 -999.250 -99'9.250 .-999.250 -999.250 5120.000 -999.250 .-999.250 -999.250 -999.250 -999.250 -999.250 5168. 000 -999.250 -999.250 -999.;)50 -999.250 -999.250 -999.250 5044.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4960.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4924.000 IS TAPE VERIFICATION LISTING CHLUM'BE~GER .~L.~SK4 COMPUTING C~NTfR DEPT. 6100.0 O0 I~D. OIL Sm. DIE ,-999.2!50 GR. DI~ RHOS.~DC -999..250 DRH~.FDC CALI. FDC --999.2'50 G~. FDC TNPH.CNL -:999.250 TNR~.CNL RCFT.CNL -999.250 CNTC.CNL CAL~.CNL -999.250 TENS.CNL DEPT. 6000. OOO IlO. DI~L SP. DIL -999. 250 GR.D'IL RHO~.FDC ,-99'9.250 gRHO.FDC CAL!. FDC -999. 250 GR. FDC TNPH.CNL -999. 250 TN~A.:CNL RCF'T. CNL -9 99. 250 CNTC.CNL CA:LI.CNL -999.250 TENS.CNL DEPT. 590D. OOO ILO.OIL SP.DIL -999. 250 GR. OIL RHC~.FDC -999.250 DRHg. FDC CALI. FDC -999.250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999. 250 CNTC.CNL C~LI.CNL -999.250 TENS.CNL DEPT. 5800.0 O0 ILD.DIL SP.DIL -ggg.250 gR.OZL RHOB.FDC -999.250 ORHO.FD:C CALI.FDC -999. 250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -99~.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 5700.000 ILD.DIL SP. OIL -999.250 GR. OIL RHU~.FDC -999.250 ORHC.FDC C:~LI. FDC -999. 250 GR. FDC TNPH.CNL -999.250 TNR~.CNL RCFT.CNL -999.250 CNTC.CNL C=~LI.CNL -999.250 TENS.CNL DEPT. 5600.000 ILD.DIL Sm. OIL -999.250 GR.DIL RHDB.=DC -999.250 DRHD.FDC C AL I. :DC -999.2 50 GR. ~DC TNPH.CNL -999.250 TNR~.CNL RCFT.CNL -9'99.250 CNTCoCNL CALI.CNL -999.250 TENS.CNL DEPT. 5500.000 ILD.OIL SP. OIL -999. 250 GR. C!t RHUB.:DC -999.250 DRHO.FDC CALI. ~DC -9 99. 250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL 30-NDV-1989 09:09 -999. 250 !tM. OIL -999. :250 -999. 250 TENS.OIL -99'9.250 -999.250 ~FDC.FDC -999.250 -999. 250 TENS. FDC -999. ,250 -999.250 NPOR.CNL -999.250 - '999.250 C F T C. C N L - 99 9..Z 50 -999. 250 GR.CSG 58.~56 · -999.2:50 IIM. DIL -999.250 -9'99.250 TENS.OIL -999.250 '-999.250 FFDC.FOC -999.250 -999.250 TENS. FDC -999.250 -999.2'50 NPOR.CNL -999.~250 -999.250 CFTC.CNL -999.250 -999. 250 GR.C SG ? $.435 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -99'9.250 -999.250 FFDC.FDC -999.250 -9'99. 250 TENS.FDC -999.250 -999.250 NPDR.CNL -99'9.250 -999.250 CFTC.CNL -999.250 -999.250 GRoCSG 8~.563 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL '-999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FOC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNt -999.250 -999. 250 GR.CSG 98. 063 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -99'9.250 ~FDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999. 250 NPOR.CNL -999.250 -999. ,250 CFTC. CNL -999. 250 -999. 250 GR. C SG 10 5. 563 -999.250 ILM.OIL -999.250 -999.250 TENS.OIL -999.250 -999.250 ~FDC.FDC -999.250 -999.250 TENS.FOC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 86.500 -999.250 ILM.OIL -999.250 -999.250 TENS.DiL -999.250 -999.250 :FOC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 SFLU. DIL DPHI.FDC NFDC.EDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC:.FDC <N P H I. C NL RCNToCNL G R o C N t TENS.CSG SFLU.OIL DPHI,.~DC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC. FDC NPHI.CNL RCN'T.CNL GR.CNL TE~S.CSG SFLU.DIL OPHI.FDC NFDC.FDC NPHI.CNL RC~T.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG S~LU.DIL DPHI.~DC NFgC.~DC NPHI.CNL RCNT.CNL GR.CNL -999.250 -999.250 -999. Z 50 -999.250 -g 99.250 -9gg. 250 ~84'0. 000 -999.250 -999.250 -'999.250 -999.250 -999..250 -999.250 4780.000 -99'9.250 ,-999.250 -999.250 -999.250 -9'919.250 -999.250 ~720.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4632.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4692.000 -999.250 -999.250 -999.250 -999.250 -999.250 -ggg.zso 4672.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 IS TAPE:, VERIm~C~'TION~ ~ LISTING~ CHLUMBERGER AL~SK4 COMPUTING CE?NTER CAL'I.CNL -999.250 TEN.S.CNL DEPT, 5400,000 ILD,D IL SP, 9!L -9 99.2 50 GR,DIL RHDB.FDC -999.250 DRHD.FDC C a, LI. FDC -999. 250 GR. FDC TNPH.CNL -999.250 TNR~.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 5300.000 IL~.DIL SP.DIL -999.250 GR.DIL RHOB,FDC '-999,250 DRH~.FDC CALI.FDC -999.250 GR.FOC TNPH.CNL -999,250 TNRA.CNL RCFT.CNL -999.250 CNTCoCNL CALI.CNL -999.250 TENS.CNL 30-NOV-1989 09:09 · -999,. 250 GR. CSG 79.188 -999.250 ILM.D!<L -999 250 -999. 250 TENS.OIL -999.250 -999.250 FFDC,FDC -999.250 -999.250 TENS.FDC -999.25,0 -999.250 NPOR.CNL -999.2.50 -9'99,250 CFTC.CNL -999,250 -999. 250 GR.CSG 80.375 -ggg, 2.50 ILM,DIL -999.250 -999,250 TENS,OIL -999,250 -999,250 FFDC,FOC -999,250 -999.250 TENS.FDC -g99. ZSO -999,250 N'PDR,CNL -999,250 -999.250 CFTC,CNL -'999.250 -999,250 GR,CSG 81,625 D~PT. 5200.000 ~LD.DIL -999.25D ILM.DIL -999.250 SP.DiL -999.250 GR.OIL -999.~5D TENS.OIL -999.250 RHDL~.FDC '-999. 250 ORHO.FDC -999.250 FFDC.FgC -999.250 CALI.FDC -999.250 GR.FDC -999.250 TENS.FOC -999.250 TNPH. CNE -999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCFT.CNE -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 CALI.CNL -999.250 TENS.CNL -999.250 GR.CSG 81.375 DEPT, 5100,000 ILO,OIL -'999,250 ILM,DIL -999,250 SP.. OIL -999.250 GR.DIL -999..250 'TENS.DIL -999.250 RHOB.FDC -999.250 DRHO.FDC -999 250 FFDC. FDC -999.250 C~LI.F'DC -999.250 GR.FDC -999.250 TENS.FDC -999°250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL -999. 250 CFTC.CNL -999.250 CAL!.CNL -999.250 'TENS.CNL -999.250 GR.CSG 66.000 DEPT, 5000,000 ILO,OIL -999,250 ILM,DIL -999,250 SP,DIL -999,250 ~R.,DIL -999,250 TENS,OIL -999,250 RHOB,FDC -999,250 DRHO,FDC -999,250 FFDC,FDC -999,250 CALI.FDC -999.250 GR.FDC -999.250 TENS.FDC -999.250 TNPH.CNL -999.250 TNRA.CNL -99:9.250 NP'OR.CNL -999.250 RCFT,CNL -999,250 CNTC,CNL -999,250 CFTC,CNL -999,250 C~LI,CNL -999,250 TENS.CNL -999,250 GR,'CSG T2,750 DEPT, 4900,000 ILD,DIL SP,DIL -999,250 GR,DIL RHDB.:DC -999.250 gRHD.FDC CALI. ~DC -9 99.2 ~0 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C~LI.CNL -999.250 TENS.CNL DEPT. &800.O00 ILO.OIL Sm. OIL -999.250 GR.DIL RHCB.FDC -999.250 ORHC.FOC C~LI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNR~.CNL -999,250 ILM,DIL -999,250 TENS,DIL -999,250 FFDC,FOC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999,250 GR.CSG -999,250 ILM,DIL -999.250 TENS.OIL -999.250 FFDC,FDC -999.250 TENS, FDC -999.250 NPOR.CNL -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 57.063 -999.250 -999,250 -999.250 -999.250 -)99.250 TENS,CSG SFLU,DIL DPHI, 'FDC NFDC.FDC N ? H I. C N L RCNT, CNL GR..CNL TiENS:oCSG SFLU,DIL DPHI, FDC NFDC,FDC N P H ii. C N L RCNT,CNL GR.CNL TENS.CSG SFLU,DIL DPHI,FDC NFDC,FDC NPHI ,CNL RCNT,CNL GR,CNL TENS,CSG SFLU,DIL OPHI, FDC NFDC,FDC NPHI,CNL RCNT,CNL GR.CNL TENS.CSG SFLU,DIL DPHI,FDC NFDC,FDC NPHI,CNL RCNT.CNL GR .CNL TENS.CSG SFLU,DIL DPHI,FDC NFDC,FDC NmHI,CNL RCNT,CNL GR.CNL TENS,CSG SFLU.OIL DPHI.FDC NFDC.FDC N~HI.CNL RCNT.CNL PAGE: 10 4584.000 -999.250 -999.250 -999.250 -9'99.250 -999.250 .-999.250 4500.000 -999.250 -999,250 -999,250 -999.250 -999.250 -999.250 4408,000 -999,250 -999,250 -999,250 -999,250 -999.250 -999°250 4364,000 -999.250 -999.250 -999.250 -999.2:50 -999.250 -999.250 4352.000 -999,250 -999,250 -999,250 -9'99,250 -999,250 -999.250 4340.000 -999,250 -999,250 -999,250 -999,250 -999,250 .-999,250 4304.000 -999,250 -999,250 -999,250 -999,250 -999.250 IS TAPE V'ERIFIC~TIgN LISTING CHLUM~EqGER ALASKA COMPUTING CENTER RCFT.CNL -g99.250 CNTC.CNL CALI.C'NL -ggg.250 TENS.CNL DEP'T. ~700. gO0 ILO.OIL SP. OIL -999.250 G~.OIL RHO~:. FDC -~99.250 ORHG.FDC C~L'I. FDC -999. 250 G~. FDC TNPH.CNL -g 99'. 250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.2 '50 TENS.CNL DEPT. 4600°000 ILO.OIL SP. DIL -999.250 G~.DI'L RHOB.FDC -999.250 DRHO.FDC CALI.FDC -999.250 GR..FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC..~CNL CALI.CNL -999.250 TENS.CNL DEPT. 4500.000 ILO.DIL SP.DiL -999.250 gR.DIL RHOB.FDC -999.250 gRHC. FDC C ALI. FDC -999.250 GR. FDC TNPH.CNt -999.250 TNRA.CNL RCFT.CNL -999,.250 CNTC.CNL CALI.CNL -999.2.50 TENS.CNL DEPT. 4400.000 ILO.OIL SP.DIL -999.250 GR.DIL RHGB.FDC -999.250 DRHO.FDC C~LI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. ~300.000 ILD.DIL SP.DIL -9g9.250 GR.DIL RHgB.FDC -999.250 gRHD.FDC CALI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -9g9.250 CNTC.CNL C~LI.CNL -999.250 TENS.CNL DEPT. 4200.0 O0 !LO. OIL SP. DIL -999.250 GR.DIL RHCB.FDC -9~9.250 DRHO.FDC C ALI. FDC -999.250 GR. FOC TNPH.CNL -999.250 TNR~.CNL RCFT.CNL -999.250 CNTC.CNL CAL!.CNL -999.250 TENS.CNL DEPT. ~100.000 ILO.OIL SP.DIL -999.250 GR.DIL RHC~.FDC -999.250 DRHC.FDC C&LI.FDC -999.250 GR.FDC 30-NOV-lO89 09:Og -999.250 CFTC.:CNL .-999.250 - 999. 250 GR. CSG 67. 938 -999.25D ILM.DIL -999.250 -999.250 'TENS.OIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FgC -999.250 -999.250 NPOR.CNL '-'999.250 -9'99:,.250 CFTC.CNL -999.250 -999.250 GR.CSG 66.000 -999.250 ILM.DIL -999.250 -99'9.250 'TENS.DIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FOC -999.250 -999.250 NPOR.CNL -999.250 -gg9.25D CFTC.CNL -999. 250 -999.25'0 GR. CSG 53. 688 -999.250 ILM,.DIL -999.250 -999.250 TENS.OIL -999.250 -999. 250 FFDC. FDC -999.25,0 -999.250 TENS. FOC -999.250 -999. 250 NPOR.CNL -999.250 -:999. 250 CFTC.CNL -999.250 - 999. 250 GR. C SG 93. 563 -999.250 ILM.DIL -999.250 -999.25,0 TENS.OIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 'TENS.FDC --999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 79.188 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.~250 ~FOC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL --999.250 - 999. Z 50 GR. C SG 76. 125 -q99.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NP9R.CNL -999.250 -999.!50 CFTC.CNL -999.250 -999.250 GR.CSG 71.938 -999.250 ILM.DIL -399.250 TENS.OIL -999.~50 ~FDC.FDC -999.250 TENS.FOC -999.250 -999.15~ -999.250 -999.250 GR.CNL TENS.CSG S FLU. g I t DPHI.FDC NFDC. FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RC~T.CNL GR.CNL TENS.CSG SFLU. DIL OPHI.FDC NFDC.FgC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NOHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL PAGE: 11 -999.2!50 4228.000 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 4080' 000 -999.25,0 -999.250 -999.250 -999.250 -999.250 -999.250 4132.000 -9'99.250 -999.250 -999.250 -999.25~0 -999.250 '-999.250 ~OlO.O00 -999. 250 -999.250 -999.250 -999.250 -999.250 -999. 250 38.90.000 -999.250 -9'99.250 -999.250 -999.250 -999.250 -999.250 3844.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3760.000 -o99.250 -999.250 -999.250 -999.250 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKia, COMPUTING CENTiE~ TNPH. CNL -999. 250 TNRA.CNL R C F T. C N iL - 999..250 C N T C. C N L CALI.CNL -999.250 TENS.CNL DEP'T. 4000. OOO ILO. OIL SP.OIL -999.250 GR. OIL RHOB.~DC .-999.2!50 DRHO.FOC DALI. FDC -999. 250 GR. FOC TNPH.CNL -999.250 TN~A.CNL RCFToCNL -999.250 CNTC. CN~L C~LI..CNL -9~9.250 TENS.CNL DEPT. 3900. 000 ILO. OIL SP.DIL -999.2 50 GR.D!L RHOB.FDC -999.250 DRHC.FgC C ~ L I. F D C - 999. ,250 G R. F O C TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C;~LI.CNL -999.250 TENS.CNL DEPT. 3800. 000 ILO. D!L SP.OIL -999.250 GR. OIL RHO~.FOC -999.250 ORHO.FDC CALl. FDC -999. 250 GR.FDC TNPH.CNL -999.250 TNR~.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 3700.000 ILO.OIL SP.OIL -999.250 GR., OIL RHO3.~gC -9'99. 250 DR, HO. F-DC DALI. FDC -999. 250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL .-999.250 CN:TC.CNL C~LI.CNL -999.250 TENS.CNL 30-NOV-IDB9 09:09 - 99 g. 12 !50 N P 0 R. C N L - 9 g 9.250 - 999. ~ 50 C F T C. C N t .-g g 9.250 -999. 250 GR. CSG 7 6. ?.50 -999.250 ILM.gIL -999.250 -999.250 TENS.DIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FOC ,-999.250 -999.250 NPOR.CNL --999.250 -999.250 CFTC.CNL -999.250 -999.250 Gg. CSG 72.563 -999.250 ILM.DI~L -999.250 -999.25.0 TENS. DIL -999. 250 -999.25'0 FFDC. FDC -999.250 -999.250 TENS.FgC -999.250 -999.250 N:POR.CNL -999.250 - 999. 250 CFTC.CNL -999.250 -999.250 GR.CSG 53.844 -9gg 250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 '-999.250 FFDC.FDC -999.250 -999.250 'TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 GR..CSG 50.219 -999.250 ILM.DIL -999.250 TENS.OIL -999.250 FFDC.FDC .-999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -99 g. 250 -999.250 -999.250 -999.250 -999.250 -999.250 56.344 RCNT.CNL GR.CNL TENS.CSG S FL U. OIL DP H I. FO C NFOC.'~DC NPHI.CNL RCNT. CNL GR. CNL TENS.CSG SFLU.DIL DPH I. FDC N'~DC. FDC NPHI .CNL RCNT.CNL GR. CNL TENS.CSG SFLU.DIL DPHI.. FDC N~DC. FDC NPHI. CNL R C N'T. C N L GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFOC.FDC NPHI.CNL RCNT.CNL G~.CNL TENS.CSG DEPT. 3600.000 ILD.DIL -999.250 ILM.DIL -999.250 SFLU.OIL SP.DIL -999.250 GR.DIL -999.250 TENS.OIL -999.250 DPHI.FOC RHOB.FDC -999.250 DRHD.FDC -999.250 FFDC.FDC -999.250 NFDC.FDC C~LI.. FDC -999.250 GR.FDC -999.250 TENS.FDC -999.250 NPHI.CNL TNPH.CNL -999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCNT.CNL RCFT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 GR.CNL CALI.CNL -999.250 TENS.CNL -999.250 GR.CSG 63.969 T.~NS.CSG DEPT. 3500.000 ILO.OIL -999.250 ILM.DIL -999.250 SFLU.DtL SP.DIL -999.250 GR.D!L -999.250 TENS.OIL -999.250 DPHI.FDC RHO~-.FDC -999.250 DRHO.FgC -999.250 FFDC.FDC -999.250 NFDC.FDC CALI.FDC -999.250 GR.FDC -999.250 TENS.FDC -999.~-50 NPH!.CNL TNPH.CNL -999.250 TN~A.CNL -999.250 NPOR.CNL -999.250 RCNT.CNL RCFT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 GR.CNL C~LI.CNL -999.250 TENS.CNL -999.250 GR.CSG 64.313 TENS.CSG PAGE: 12 -99 g . 250 -999. 250 3744. O00 .-999.250 -'999.250 -999.2:50 -999.250 -999.250 -999.250 3744.000 -99'9.250 -999.250 -999.250 -999.250 -9'99.250 -999.250 3704.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3674.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3640.000 -999.250 -999.250 -999.250 -999.250 -999.250 -g99.250 3554.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3504.000 IS 'TAPE VERIFICATION LISTING CHLUMBE, RGER ,ALASKa Cg)aPUTING CENTER DEPT. 3400.000 ILD.DIL SP.DIL -999.250 GR.DIL RHOB:.~gC -999.250 ORHg.FOC CALI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENSoCNL DEPT. 3'300. 000 ILO.OiL SP. OIL -999.250 GR.DIL RHOB.FDC -999.2,50 ORH~.FDC C.~LI. FDC -999.250 GR. FgC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL .-9,99.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPTo 3200. 000 ILD. OIL ]SP.DiL -999. Z50 GR. OIL RHOE.FDC -999.250 DRH~.FDC C ~LI.F'DC -999.250 GR. FOC TNPH.CNL -999.250 TNRA.CNL RCFT. CNL -999.250 CNTC..CNL CALI.CNL -999.250 TENS.CNL DEPT. 3'100.000 [LD..D[L S~-D~L -999.250 GR.DIL RHOB.FDC -999.250 DRHD.FgC C~LI.FDC -999.250 GR.FDC TNPH.CNL -999.250 'TNR~.CNL RCFT.CNL -999.250 CNTC.CNL C~LI.CNL -999.250 TENS.CNL DEPT. ]3000.000 ILO.OIL SP.D!L .-999.250 GR.OIL RHOB.FDC -999.250 DRHO.FgC CALI. FDC -999.250 GR. FOC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C~LI.CNL -999.250 TENS.CNL DEPT. 2900.000 ILD.DIL SP.DIL -999.250 GR.DIL RHG~.=DC -999.250 DRHD.FDC CALl. FDC -999.250 GR.FOC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C,~LI.CNL -999.250 TENS.CNL DEPT. 2800.000 ILD.DIL SPoDIL -999.250 SR.DIL RH~oFDC -999.250 DRHO.FDC C~LI.FDC -9'99.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL 30-NOV-Ig'B9 09:09 -999.250 ILM.OIL -999.250 -999.25:0 TENS.OIL -999.250 -999.250 FFDC.FOC -999.250 -999.250 TENS.FOC -999.250 -999.,250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 71.$75 -999.250 ILM. OIL '-999.250 -999.250 TENS.OIL -999.250 -999.250 F~FDC.FOC -999 250 -999.250 TENS. FOC -999.250 -999.250 NPOR.CNL -9'99.250 -999.250 C'FTC.CNL -999.250 -999. 250 GR.CSG 38. 219 -999.250 ILM.DIt -999.250 -999.250 TENS.OIL -999.250 -999.250 FFDC.FDC -999.250 -999. 250 TENS.FDC -999.250 -999.~50 NPOR.CNL -999.250 -999. 250 CFTC.CNL -999.250 - 999. 250 GR. CSG 25.797 -999. 250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999..250 FFOC.FO;C -999.250 -999.250 TENS.FDC -999.250 -999. 250 NPOR.CNL -999.250 -999..250 CFTC.CNL --999.250 -999.250 GR.CSG 48.031 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999. 250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 - 999. 250 GR. C SG 40 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 FFDC.FDC --999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 39.969 -999.250 ILM.DIL -999.250 TENS.DIL -999.250 FFDC.FDC -999.250 TENS.FDC -999. 250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 47.313 SFLU.DIL DOHI.FDC NF~C.FOC NPHI.CNL RCNT.CNL ~GR.CNL 'TENS.CSG SFL, U.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHi. FDC NFDC.FDC NPHI:.CNL R CNT. C NL G R. C N L T E N S. C S g SFLUoOIL DPHI.FOC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TE~S.CSG SFLU.OIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CS~ SFLU.DIL DPHI.FDC NFDC.FOC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG P A ~S E: 13 - g 99 -250 -999,250 -999,250 -999,250 -999,250 -999,250 3470.000 · -999,250 -999,250 -999.250 -999,250 -999,250 -999.250 3330°000 - 9 g 9.250 -9'99,250 .-g g 9.250 -999.250 - 999.2 50 -999,250 3354.000 -999.250 -999.250 -999.250 -999,250 -99'9,250 -999.250 32~4.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3180.000 -999,250 -999,250 -999.250 -999,250 -999,250 -ggg.250 3040.000 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 3044.000 IS TAPE VER'I~IC.&TION LISTING CHLUM=BE'RGER ALASKA CO~iPUTING CENTER DE PT. 2700. 000 ILO. OIL SP. OIL --999. 250 ,GR.DiL RHOB.FD'C -999.250 gRHg. FDC CALI,FDC '-ggg. 250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL £ALI.CNL -999.250 TENS.CNL DEPT. 2600. 000 ILO. OIL SP- OIL -999. 250 GR,OI'L RHOB.FDC -999o250 DRHO.FDC CALI, FOC -999. 250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TEN:S.CNL DEPT.. 25 00. 000 ILO.OIL SP. OIL -999. Z 50 GR.. OIL RHOBo'FOC -999.250 ORHO.FOC C ~,LI. FDC -9 99 . 2 50 GR. FDC TNPH.CNL -999.250 TNR~..CNL RCFT.CNL -999.250 CNTC.CNL C=~LI.CNL -999.250 TENS.CNL DEPT.. 2400.000 ILO.OIL SP. DIL -999.250 GR.OIL RHGS.FDC -99'9.2 50 DRHC.FO'C C~LI.FDC -999. 250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -9'99.250 TENS.CNL DEPT. 2300.000 ILO.OiL SP.DIL -999. 250 GR. GIL RHOB.FDC -999.250 ORHG. FD,C CALl. FDC -999. 250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999. 250 CNTC.CNL CALI.CNL -999.250 TENS.CNL OEPT. 22 00. 000 ILC. DIL SP.OIL -999.250 GR.DIL RHDB. FDC -999. 250 DRHD. FDC CALI. FDC -9 99. 250 GR. FDC TNPH. CNL -999.250 TNRA.CNL RCFToCNL -999. 250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 2100.000 ILO.OIL SP.DIL -999.250 GR.OIL RHOB.FDC -999.250 CRHO.FDC C ALI. FDC -gg9.250 GR. FDC TNPH.CNL -999.250 TNR~.CNL RCFT. CNL -g 99.250 CN TC. CNL 30-NOV-1989 09:09 -999.250 ILM.DIL -999.250 -999.250 TENS..'DIL -99'9 250 -999.250 FFD'C. FOC -999.250 -999.250 TEN$.FOC -'999:. ~250 -999.250 NPOR.CNL -999.250 -999. ZSO CFTC.CNL -999.250 --999. 250 GR.C SG 3 4. 344 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 rFDC.FOC -999.250 -999.250 TENS.FDC -99'9.250 -999.250 NPOR.CNL -999.~50 -999.250 CF'TC. CNL -999.250 -999. 250 GR.CSG 31.016 -999. 250 ILM.OIL -999. 250 · -999. 250 TENS.OIL -999. 250 -999.250 FFDC.FDC -999.250 -999.250 'TENS. FDC -999.250 -999. 250 NPOR:.CNL --999.250 -999.250 CFTC.CNL -999.250 -999. 250 GR. CSG 28.82'8 -999.250 ILM.DIL -999. 250 TENS.OIL -999.250 FFOC.FDC -999.~50 TENS.FDC -999.250 NPOR.CNL -999.7.50 CFTC.CNL -999. ZSO GR.CSG -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 2 3.344 -999.250 ILM.DIL -999.7.50 -999.250 TENS.DIL -999.250 -999.250 FFDC.FDC -999.250 -999. 250 TENS. FDC -999. 250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 36.313 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999. 250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999. 250 CFTC.CNL -999.250 -999.250 GR.CSG 26.~59 -999. 250 ILM.DIL -999.,250 -999.7-50 TENS.DIL -999.250 -999.250 F~OC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999. ]50 CFTC.CNL -999.250 SFLU.DIL DPHI. FDC NFDC.FDC NPHI.CNL RCNT,CNL GR. C NL TE NS. CSG SFLU.DIL D~HI.FDC NFDC. ~FDC NPHI. CNL RCNT.CNL GR.CNL TENS.CSG S FLU. OIL DPHI.FDC NFDC :. FDC NPH!. CNL RCNT.CNL GR..CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC N P H I. C N L R C NT. C NL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFOC.FDC NPHI.CNL R C N T. C N L GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.OIL OPHI. FDiC NFDC.-mDC NPHI.CNL RCNT.CNL GR.CNL PAGE: 14 -999.250 -999.250 -999.250 -999.250 -ggg. Z50 -999.250 2934,,000 -9 g 9.250 - 9 g g. Z 50 -99 g. 250 -999 . 250 -999. 250 -999.250 · 2894 . 000 -999.250 -999. 250 -999.250 -999. 250 -999.250 -999.250 2860.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2824.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2794.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2764.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 IS 'T~,PE VERI.~IC4TICN ~LISTING CHLUM~ERGER AL4SK,~ COMPUTING CENTER CALI.CNL -999,250 TENS,CNL DEPT, 2000. 000 ILO. OIL SP.DIL -999.250 GR. OIL RHOB.FDC -999.250 DRHG.FDC CAL!. ~DC -gg9.2 50 GR.FSC TNPH.CNL -999.250 TNRA.CN:L RCFT.CNL -999.250 CNTC.CNt CALI.CNL -999.250 TENS,CNE DEPT. 1900.0 O0 ILD. OIL SP. OIL -999.250 OR.OIL RHOB.FDC -999.250 ORHO.FDC C~LIo:~DC -999. 250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFToCNL -999.250 CNTC.CNL CALI.CNL -999.250 'TENS.CNL DEPT, !800. 000 ILO. DIL SP.DIL '-999.2 50 GR.DIL RHOB.FDC --999.250 gRHOoFDC C,~LI. FDC -999. 250 GR. FOC TNPH.CNL -999. 250 TNRA. C'NL RCFT.CNL -999.2 50 CNTC.CNL C~LI.CNL -999.2:50 TENS.CNL DEPT. 1700.000 !LD. DIL SP. OIL -999. 250 GR. OIL RHOB.FDC '-999.250 ~RHD.FDC CALI. FOC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C~LI.CNL -999.250 TENS.CNL DEPT. 1600.000 ILD.DIL SP. OIL -999.2 50 GR. OIL RHOB.FDC -999.250 DRHO.FDC CALI. FCC -999.2 50 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C~LI.CNL -999. 250 TENS.CNL DEPT. 1500.000 ILO.OIL SP. OIL -999.2 50 OR.OIL RHCB.FDC -999.250 ORHO.FDC C~LI.FDC -999. 250 GR.~C TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. !400.000 ILO.OIL SP.DIL -999.250 GR.DIL RHO~.FDC -999.250 D~HO.~DC C~LI.FDC -~99.250 GR.FOC TNPH.CNL -999.250 TNRA.CNL 30-NOV-lO89 09:09 '-999. 250 G~. C SG 35. 031 '-99'9.250 ILM. DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 FFDC.FOC -999.250 -999.250 TENS.FOC -999.250 -999.250 NPOR.CNL -99'9.250 -999. 250 CFTC.CNL -999.250 - 99'9. ,250 gR.CSG 3~.~69 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 FFOC.FDC -999.250 ,-999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999. 250 GR.CSG 3,6. 875 -999.250 ILM.DIL ,-999.250 -999.250 TENS.OIL -999.250 -999.250 FFOC.FOC -999.250 -999.250 TENS. F~C -99:9.250 -999.250 N~POR.CNL -999.:250 -999.250 CFTC.CNL -999.250 -999. 250 GR.CSG 33. 5131 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999,250 -999.250 FFDC.FgC -999.250 -999.25'0 TENS.FDC -999.250 -999.250 NPO~.CNL -999.250 -999.25.0 CFTC.CNL -999.250 -999. 250 GR'..CSG 31. 281 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 FFOC.FOC -g99.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -99'9.250 -999. 250 GR.CSG Z 5. 547 -999.250 ILM.DIL -999.250 TENS.OIL -999.250 FFOC. FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 28.578 -999.250 ILM.DIL -999.250 -999. 250 TENS.DIL -999.250 -999. 250 mFDC. FOE -999.250 -999. 250 TENS.FDC -999.250 -9'99.250 NPOR.CNL -999.250 TfNS.CSG S FLU. OIL DPHZ.FDC NFgC.FOC N PH I. CN L R C NT. C NL GR.CNL TENS .CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL D P H I. F D C NFDC. FDC NPHI.CNL RCNT.CNL GR.CNL TENS. CSG SFLU.OIL DPHI.FDC NmDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.C'SG SFLU.DIL DPHI.FDC NFDC.FOC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFOC.FDC NmHI.CNL RCNT.CNL 2750.000 -999.250 -999.250 -999.250 -999.250 -999.250 -'999.~50 2.6134.000 -999.250 -999. 250 -999.250 -999.250 -9' 99.250 -999.250 2634. 000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 258~.000 -999.250 -999.250 -999.250 -999.250 -999.250 .-999.250 2540.000 -999.250 -999.250 -999.250 -999.250 -999.250 -9.99.250 2550.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2474.000 -999.250 -999.250 -999.250 -999.250 -999.250 :iS TAPE' VERIFZ:C~T'ION LISTING CHLUMBERGER ~.LASKA COMPUTING CENTER RCFT.CNL -999. 250 ~r'NTC.. . CNL CALI. CNL -999.2 50 TENS.CNL D DPT. .t 3 00.0 O0 ILO .'D ,..IL SP.DIL -999.250 GR.DIL RHOB.FDC -999.2:50 gRHO.FOC C,4LI. FDC -999. 250 GR.FOC TNPH.CNI -999.250 TNRA.CNL RCFT.CNL -999. 250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 1200. DO0 ILD.D'IL SP. DIL -999.2 50 GR. C, IL RHOS. FDC -999.250 ORMD.FDC CAL!. FDC -999.250 GR. FDC TNPH.CNL -999.250 TN~AoCNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 1100o00 0 [LD.~IL SP. DIL -999. 250 GR. DIL RHDBo FDC -999.250 ORHD.FDC C &LI,. FDC -999.250 GR'. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.2.50 CN'TC.CNL CALI.CNL -999.250 TENS.CNL DEPT. !gO0.0 O0 ILD. DIL SP. DZL -'999.2 50 S~.OiiL RHOS.FDC -999.250 DRHD.FDC C ALI. FDC -999.2 50 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C~,LI.CNL -999.250 TENS.CNL DEPT. 9B5. 000 ILD.OIL SP.OIL -999.250 GR.DIL RH~.FDC -9'99.250 DRH~.F.gC CALl. ,=DC -999.250 GR. FDC TNPH.CNL -999.250 TN~A.CNL RCFT.CNL -999.250 CNTC.CNL C~LI.CNL -999.250 TENS.CNL END OF D~T~ -'--"-,.,.,- 30-NOV-1959 09:09 -999.2:50 CFTC.CNL -999' 250 GR.CSG -999.250 ILM. DIL -999. 250 TENS.DIL -999. 250 FFDC.FDC -999 250 'TENS.FDC -999.2.50 NPOR.CNL -999.250 CFTC. CNL -999.250 GR.CSG -999.250 ILM'DIL - 999. 250 TENS'OIL -999.250 FFDC.FDC -999.250 TENS.FDC -999.. 250 NPOR. CNL -999. 250 CFTC.CNL -999. 250 GE. CSG -999.250 ILM.DIL -999.250 TENS.OIL -999.250 FFDC.FDC -999.250 'TENS. FgC -999.. 250 NPOR.CNL -999. 250 CFTC.CNL -999. 250 GR.CSG -'999. 250 !LM.DIL -999.250 TENS.DIL -999.250 'FFDC. FD'C -999.250 TENS.FDC -99'9.250 NPOR.CNL -999. 250 CFTC.CNL -999.7_50 GR.CSG -999.250 ILM.OIL -999.250 TENS..D~L -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.25D GR.CSG -'99 30. -999. -999. -999 o -999. -999. -999. 17. '-999. -999. -999. -999. -999. -999. 250 5:16 250 250 25O 250 Z 50 250 I88 25O 250 25O 250 906 -999. 250 - 99 9. Z :50 -99 9. 250 -999.250 '-999.250 - 999.2:50 18.359 -999. -999. '-999. -999. -999. -999. ~1. -999. -999. - 99 9. -999. -999. -999. 26. 250 250 250 250 25O 250 000 25O 250 250 25O 25O 25O 688 GR.CNL TENS.CSG SFLU.OIL OPHI. FDC NFDC. FOC N PH I. CN:L RCNT.CNL GR. CNL TENS. CS G SFLU.DIL DPHI.FDC NFDC. FDC NPHI.CNL RCN'T.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC,.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SmLU.DIL DPHI.FDC NFDC.FDC NmHI.CNL RCNT.CNL GR.CNL TENS.CSG -999.250 2340.000 -999. 250 -999.250 -999. 250 -999.250 -999.250 2260. '000 -999.25' 0 -999.25.0 -999.250 -9 '99.2 .-50 -999.25~0 '-9'99.25.0 2210.000 · -999.250 -999.2-50 -999.250 -999.250 -999.250 -999.2.50 2164.000 -999.250 -999.250 -999.250 -999.250 -999.250 ZllO.O00 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2130.000 IS TAPE VER'IFICATIDN LISTING CHLUMBEP.,GER ~,LASKA CO~PUTiN~ .-30-NOV-19~9 09:09 PAGE :t 7 **** FILE TR,~ILER FILE NAME : EDIT .001 SERVICE .: ~L!C VERSION : O0'lA04 OATE : 89111/30 MA.× REC SIZE : FILE TYPE : LO LAST FILE **** FILE HEADER FILE NAME : EDIT .002 SERVICE : FLZC VERSIgN : OOIA04 DATE : MAX REC SIZE : 1024 FILE TYPE : LO L ,~ST FILE : FILE - ~DIT,OOZ ~RCO &LASKA, 'INC. KUPARUK 2K - 18 50-10~-Z011 HIGH RESOLUTION PASS DATA DATA S~MPLEO EVERY -.t000 FEET D~T~ INCLUDED - TOOL EXTENSZ'ON TYP~ USED FDC CNT-A/O/H oCNH TOOL FORMATIgN DENSITY COMPENSATED N=UTRON 7913' TO 7453' 7899' TO 7453' ,IS 'TAPE VERIFICATION LISTING ,CHLUMBERGER AL~SK~ COMPUTING CENTER 30-NOV-1989 09:09 PAGE: 18, TABLE TYP!E : CONS TUNZ CN FN WN APIN FL SECT TOWN RANG C OUN STAT NAT I WITN SON PDAT EPD L MF EKB EOF EGL TOD ST EM FT FT FT FT FT FT DEGF V ALU ARCO ALASKA, ZNC. KUPARUK 50-103-20117-00 1 94 t FNL ~ 94' ION NORTH SLOPE U S ~, D!XDN/LgWEN M SL O. RK8 154. !~4. 113. 796D. -999. ~5 D~FI 'COMPANY NAME FIELD NAME W E L L N A M E ~PI SERI,~L NU'MSER FI!ELD LOCATION SECTION TOWNSHIP RANGE ~CDUNTY STATE OR PROVINCE NATION WITNESS~ NAME SER¥'ICE ORDER NUMB~ER PERMANENT DATUM LOG MEi~SURED FROM TABLE TYP~ : CURV DEFI DEPT DPHI RHOB DRHO FFDC NFDC C,aLI GR TENS NIDHI TNPH TNR,a N PO R RCNT RCFT CNTC C=TC GR CALI TENS DEPTH CHANNEL N~ME DENSITY POROSITY BULK DENSITY DEL'TA RHD FAR FDC CC, UNT RATE NEAR FDC COUNT RATE CALII:'ER GAMMa, R~Y TENSION NEUTRON POROSITY THERMAL NEUTRON POROSITY C~L!BRATEg THErMaL NEUTRON R~TIO NEUTDON POqOSITY OUTPUT FROM ~N .~PPLICATIDN PROGRAM RAW NEaR CNT COUNTS RAW FAR CNT COUNTS CD'~.RECTED NEaR THERMAL COUNTS CORRECTED F~ THERmaL COUNTS GAM~ R~Y CAL!DE~ TENSION IS TAPE ViERIFZC~TION LISTING CHLUMBEPGER ~.LASK~.~ COMPUTING CENTER 30-NOV-1989 09:09 PAGE: 19 DATA FORMAT SPECIFICATION RECORO $* SET TYPE - 64E8 ** TYPE REPR CODE VALUE 4 86 5 86 ? 65 8 6~ 0.1 9 65 FT ! 1 66 ! 2 12 $8 13 66 0 14 65 ~ T 1S 66 68 16 66 1 0 66 I ** SET 'TYPE - CH,~,N ** NAM~ SERV UNIT SERVICE ~PI ~PI ~PI .~PI FILE NUMB NUMB SIZE REPR ID ORDE~ ~ ~LOG TYPE CLASS MOD NUMB SAMP ELEM COOL= PROCESS (HEX) DEFT FT 54~373 O0 DmHI FDH PU 548373 07 RHOB FDH G/C3 548373 07 DRHO FDH G/C3 548373 07 FFDC FDH CPS 5~8373 07 NFDC F~H CPS 54837~ 07 CALI FOH IN 54~373 07 GR FDH G~PI 548373 07 TENS FDH LB 54B373 07 NOHI CNH PU 548373 07 INPH CNH PU 549373 07 TNRA CNH 545373 07 NPC~ CNH PU ~48373 07 RCNT CNH CPS 549373 07 RCFT CNH CmS 5~373 07 CNTC CNH C~5 543373 07 CFTC CNH C~S 54B373 07 GR CNH G~PI 548373 07 CALI CNH IN 54~373 07 TENS CNH L5 $~8373 07 OOO O0 O 2 1 I 4 68 635 21 0 2 1 1 4 68 350 02 O Z 1 1 4 68 356 O1 0 2 1 1 4 68 354 02 0 2 I 1 4 68 354 O1 0 Z 1 1 4 6B 280 O1 0 Z 1 1 4 68 310 O1 9 2 1 1 4 68 635 Z1 0 2 1 I 4 68 890 O0 0 2 ! ! ¢ 68 Bi0 O0 0 2 1 1 4 68 ~20 O1 0 Z 1 1 4 68 890 O0 O 2 1 I 4 68 420 01 0 2 ! 1 4 68 420 O1 0 2 1 1 4 68 ~20 O1 O 2 1 1 4 68 420 Ol 0 Z 1 ! 4 68 310 01 'O 2 1 1 4 65 280 O1 g 2 1 I 4 68 635 21 0 2 1 1 4 68 0000000000 O00OO00000 0000000000 0000000000 0000000000 0000000000 O00000000O O00000000O 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ,IS T~.PE VERIF!CATiDN LISTING CHLUM~ERGER .~LASK,~ CO~!PUTING CENTER DEPT. 79!51.200 OPHI.FDH FFDC.FDH t497.000 NFDC.FOH TENS.FDH 3990.000 NPHI.CNH NPOR.CNH '35,,596 RCNT..CNH CFTC. CNH 818.21 8 GR. CNH D~PT,. 7900.000 OPHI.FDH FFDC.FOH 528.500 NFDC.FDH TENS.~DH 5768.000 NPHZ.CNH NPOR.CNH 3~.545 RCNT.CNH CFTC.CNH 770.767 GR.CNH DEPT. 7800.000 DPHI.FDH FFDC.FDH 403., .750 NFDC. FDH TENS.FDH 5648,,000 NPHI.CNH NPO~.CNH ~7.371. RCNT.CNH CFTC. CNH 756. 409 GR. CNH DEFT. 7700.000 DPHI.FDH FFDC.FDH 430.750 NFDC.FDH TENS.FDH !549:2.000 NPHI.CNH NPOR.CNH 135.916 ,qCNT.CNH CFTC. CNH 8 70.187 gR.CNH DEPT. 7600.000 DPHI.FDH FFOC.FDH 463.250 NFDC.FDH TENS.~DH 5120.000 NPHI.CNH NPOR.CNH 27.236 RCNT.CNH CFTC.CNH I4 02.780 GR. CNH DEPT. 7500.000 DPHIoFDH FFDC. FDH 564.000 NFDC.FDH TENS.~DH 5680.000 NPHI.CNH NPOR.CNH 39.494 RCNT.CNH CFTC.CNH 665.847 GR.CNH DEPT. 7423.900 DPHI.FDH FFDC.mDH 238.875 NFDC.FDH TENS.~DH 5340.000 NPHI.CNH NPOR.CNH 49.550 RCNT.CNH CFTC.CNH 377.462 GR.CNH END C~, OAT~ ** 30-NOV-lgS9 09:09 31.974 RHDB.FDH 961.000 CALI.FDH 39.688 TNPH.CNH 2349.936 RCFT.CNH 140,.250 CALI.CNH 12 238 RHDB. FDH 1635.500 C~!LI.FDH 3'9.994 TNPH.CNH 2375-515 RCFT.:CNH 140.250 C~Li.CNH 8.974 RHOB.FDH 532.000 C~LI.FDH 36.226 TNPH.CNH 2158.957 RCFT.CNH llO.OOO C~LI.CNH 8.721 RHOS.FDH 577.500 CALI.FDH 37.'304 TNPH,.CNH 2370.78'7 RCFT.CNH 107.813 CA:LI.CNH I0.138 RHOB.FDH 595.500 CALI.FDH 27.734 TNPH.'CNH 3252.651 RCFT..CNH 95.500 CALI.CNH 14.562 ~HOB.:DH 537.503 CALI.FOH 4t.783 T'NPH.CNH 2025.468 ~CFT.CNH 141.623 C~LI.CNH 30.276 RHOB.FDH 16¢.625 CALI.FDH 53.518 TNPH.CNH 1428.897 RCFT.CNH 86.875 CALI.CNH Z.12Z 3.252 35.596 720.823 3.252 2.448 4.867 38.043 677.58Z 4..867 2.502 6.219 36.983 63,2.887 6.219 2.506 6.258 35.12.2 808.500 6.258 2.483 6.285 25.551 1272.030 6.255 2.410 7.008 3 7. 826 666.417 7.008 2.150 6.281 49.370 390.240 6.281 DRHO.FDH GR.FDH 'TNRA.CNH CNTC.CNH TENS.CNH DRHQ.FDH GR.FDH TNRA.CNH CNTC.CNH TENS.CNH DRHO.~DH GR.FDH 'TNR~.CNH CNTC.CNH TENS.CNH DRHO. I:::DH G~.FDH TNRA.CNH CNTC. CNH TENS.CNH DRHO.FDH GR.FDH TNRA.CNH CNTC.CNH TENS.CNH DRHO.FDH GR.mDH TNR~&.CNH CNTC.CNH TENS.CNH DRHO.FDH GR.~OH TNR~.CNH CNTC.CNH TENS.CNH PAGE: 20 0.153 140.250 2.977' 2398.325 39'90.000 0.056 140.250 3.091 2380.298 5768.000 -O.OOZ 110.~000 2.966 2288.200 5648.000 0.031 107.8t3 3.0~7 2530.087 5492.000 0.037 9:5.500 2.4~0 3308.326 5120.000 0.044 141.625 3.317 2076.595 3680.000 -0.565 86.875 3.914 1438.673 5340.000 'TAPE VERIFI~C~T!DN LISTING ;CHLUMOERGER AL~SK& COMPUTING CENT~ER 30-NgV-19:89 09:09 PAGE: ~.' e,.~ FILE TR~ILE~ FILE NAME : EDIT .002 SERVI~CE : :~L IC VERSION : 'DATE : 89/11/30 M.~X REC SIZE : F ZLE TYPE : L~ST F'ILE SERVICE N~,ME : 'EDIT DATE : -89/11/30 ORIGIN : ~F:L IC T~PE N~E : 73!534 CONTINUATION ~ : 1 PREVIOUS TAPE : COMMENT : ~RCO ~LASKA, INC. ,KUP~RUK ,2K - 18 ,50-103-2011'7-00 ~ REEL TR',~ILER ~-~ SERVICE NAME : EDIT DAT'5 : 89/11/30 · ORIGIN : FLIC REEL NAME : 73534 CONTINUATION ~ : PREVIOUS ~EEL : COMMENT : ,~CO AL,~SKA, INC. ,K. UP,~UK ,2K - 18 ,50-103-.20117-00
