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Home My WebLink About189-094 • STATE OF ALASKA • ' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gasp SPLUG❑ Other ❑ Abandoned 2 ` Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development 2 • 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.: 12/7/2016 • 189-094/ -3110-LN} 3.Address: 7.Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 10/15/1989 50-103-20115-00 ^ 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 144'FNL,94'FEL,Sec 11,T1ON, R8E, UM 10/22/1989 KRU 2K-16 Top of Productive Interval: 9.Ref Elevations: KB:154 17. Field/Pool(s): 1581'FSL, 1222'FEL,Sec 11,T1ON, R8E, UM GL: BF: Kupurak River Field/Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1362'FSL, 1294'FEL,Sec 11,T1ON, R8E, UM 7802/6454 ADL 25588 • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 498310 y- 5938160 Zone- 4 7915/6545 ALK 2674 TPI: x- 497184 y- 5934606 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 497112 y- 5934387 Zone- 4 December 7, 1904 1400/1397 5. Directional or Inclination Survey: Yes ❑ (attached) No EI 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) I 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 RECEIVED s \.M' APR 2 6201? N/A JAN 0 4 2011 AOG GC 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 36 115 36 115 24 170 sx AS II 9 5/8 36 J-55 35 3235 35 2926 12 1/4 1100 sx AS III,450 sx Class G 7 26 J-55 33 7888 33 6524 8 1/2 250 sx Class 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 7455 7375 MD/6115 TVD Perforations Plugged: Ag2A,40a4.+C 7534-7546 MD 6241-6250 ND - 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. 7534-7547 MD 6241-6251 ND Was hydraulic fracturing used during completion? Yes❑ No III 7602-7610 MD 6295-6301 ND t2 J-4-1 I‘P Per 20 AAC 25.283(i)(2)attach electronic and printed information 7634-7674 MD 6320-6352 ND DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Lt- TOC=7,408'KB 25 bbls Class"G"(tubing) TOC-IA=1520'KB,TOC tubing= 199 bbls Class"G"(tubing x IA) 1650'KR TOC @ Surface Arctic Set 1 73.5 bbls(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 Casino Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate —► Form 1Q-407 R vis 1/2015 CONT�vU D ON P GE 2 Submit ORIGINIAL only/. 'Cd 1/246 V-rt- `�/Z�//� /� 4(2y�, RBDMS ti JAN 9 2317 �6 • 28.CORE DATA Conventional Core(s): Yes ❑ No El Sidewall Cores: Yes ❑ No Rj 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 TVD Well tested? Yes ❑ No El Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1400 1397 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval N/A N/A information, including reports,per 20 AAC 25.071. Formation at total depth: N/A N/A 31. List of Attachments: Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontoloaical report.production or well test results.per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Simek CcD 263-1431 Email: Jill.Simek@cop.com Printed Name: G. L.Alvord Title: Alaska Drilling Manager Signature:—7- Phone: 265-6120 Date: 1-1- 12-i I L' t4 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and 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-16 Plug and Abandonment December 14, 2016 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 2K-16, commencing operations on September 20, 2016 and completing the Plug and Abandonment on December 9, 2016. Operations involved pumping 25 bbls of Class "G" cement in the 7" casing, across the Kuparuk perforations, and up into the 3-1/2"tubing. Top of Cement(TOC) was tagged at 7,408' KB. Tubing was then punched at 7,341 - 7,345' KB and 199 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 1,650' KB and a cement bond log indicated TOC in the IA to be at 1,520' KB. Tubing was punched at 1,490 - 1,494' KB and 63.5 bbls of ArcticSet 1 (AS1) cement was pumped down the tubing and up the IA, followed by a downsqueeze of 10 bbls AS 1 in the production casing x surface casing annulus (OA). Top of cement in the tubing and IA was determined to be at surface while OA TOC was 95.5'. A 6.25 bbl top job was performed in the OA to bring cement 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 field Well Service Report is attached. � a 1 2K-16 PTD 169-094 Copyright 2016 All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use.Copying for any other purpose or by any other party is prohibited without the express consen. of ConocoPhillips Alaska,Inc. • • 4 2K-16 PTD 189-093 No Copyright 2016 All rights reserved. 2K-16 PTD This photograph is provided to the Copyright a AOGCC with permission to copy for its with perm ;photograp _ own use. Copying forany other � :' purpose or by any other partyexpress is Copying �+ prohibited without the consent of ConocoPhillips Alaska,Inc. 4 • • Start Date Last 24hr Sum RECEIVED APPROVAL FROM AOGCC INSPECTOR BRIAN BIXBY,WELDED MARKER PLATE ON,REMOVED SHORING BOX AND STAIRS, 12/7/2016 BEGAN BACKFILLING. 12/6/2016 P&A;POURED.06 BBL OF PORTLAND TYPE 1 CEMENT TO TOP OFF CONDUCTOR. 12/5/2016 P&A;TOPPED OFF CONDUCTOR WITH 2.6 BBLS OF PORTLAND TYPE 1 CEMENT. 12/4/2016 P&A:DUG EGRESS,SET STAIRS,CUT CASINGS AND REMOVED WELLHEAD. 12/3/2016 P&A:REMOVED JEWELRY,CUT AND REMOVED STANDING PLATE AND DUG TO 15'. 11/30/2016 P&A-REMOVED TREE 11/22/2016 P&A PREP-CEMENTING OA TO SURFACE 11/21/2016 P&A PREP-MIT OA(FAIL) 11/19/2016 P&A PREP 11/16/2016(SEC)BLED T TO OPSI,IA&OA TOC,IA&OA FL FOR P&A,PRESSURED OA TO 400 PSI BEFORE FAILING MIT, 11/12/2016(SEC):T,IA&OA DDT TO 0 PSI(ALL PASSED). T TOC @ 66". PUMPED 5 BBLS HEC GEL DOWN THE OA FOLLOWED WITH 10 BBLS 15.7#AS1,SWAPPED TO PUMPING DOWN THE TUBING TAKING RETURNS OFF THE IA.PUMPED TILL WE GOT 15.7#AS1 AT THE TANKS. WEIGHED CEMENT WITH MUD SCALE AT THE TANK FARM. 15.6 PPG AT THE TANKS,SHUT DOWN. TOTAL CEMENT DOWN THE TUBING UP THE IA 63.5 AND 10 BBLS 15.7 PPG DOWN THE OA. 11/9/2016****READY FOR LRS IN 48 HR***** MIRU. RIH WITH SCMT. TOP OF CEMENT IN IA FOUND AT 1520'. PULL OUT OF THE HOLE. RIH WITH PUNCHER. PUNCH HOLES IN 11/8/2016 TUBING FROM 1490'-1494'. LRS CIRCULATE FLUID AT 1.8 BPM AND 2000 PSI. PULL OUT OF THE HOLE. RDMO. JOB COMPLETE. 11/7/2016(MISC):ATTEMPT TO CIRC T X IA(NO COMMUNICATION). MIRU. RIH W/4'LOADED TUBING PUNCH WITH MED PUNCHER,4 SPF. TAGGED TOP OF CEMENT AT 1650'.PERFORATED INTERVAL 1620' -1624'. CCL TO TOP SHOT=6.6'. CCL STOP DEPTH=1613.4'. LOG CORRELATED TO RKB ON WELL SCHEMATIC. LRS 11/6/2016 UNABLE TO ESTABLISH CURCULATION AFTER PUNCH. RIGGED DOWN FOR NIGHT. TAG TOC @ 1617'SLM.MIT-T*PASSED*,MIT-IA*PASSED*,DD/NO FLOW TEST TBG*PASSED*,DD/NO FLOW TEST IA*PASSED*. 11/4/2016 READY FOR E-LINE 10/29/2016 PUMP 199 BBLS 15.8 CEMENT DOWN TUBING TAKING RETURNS FROM I/A.READY FOR SLICKLINE TAG. MIRU. RIH WITH TUBING PUNCHER. PUNCH HOLES IN TUBING FROM 7341-7345'. CIRCULATION TEST RESULTS: 2 BPM,1700 PSI 10/17/2016 ON TUBING,1200 PSI ON IA. PULL OUT OF THE HOLE. RDMO. JOB COMPLETE. STATE WITNESSED TAG&TEST(LOU GRIMADI); TAG TOC @ 7390'SLM; MITT(PASS); PASSED DDT AFTER 2 ATTEMPTS. READY 10/15/2016 FOR E-LINE PENDING PROCEDURE REVIEW. 10/14/2016 TAG TOC @ 7408'RKB(TARGETED TOC 7257'); OBTAIN GOOD 15 MIN.TEST&RE-TAG @ SAME. IN PROGRESS. SET CEMENT RETAINER AT 7425;SQUEEZE 23.5 BBL,15 PPG CEMENT BELOW RETAINER @ 0.6 BPM,3656 PSI;LAY IN 1.5 BBL CEMENT ABOVE RETAINER 7425'-7264'; CIRCULATE 20 BBL GEL CONTAMINATE AND CIRCULATED TO SURFACE WITH SLICK DIESEL; 10/12/2016 JOB COMPLETED 9/20/2016 PERFORMED SRIT(ABLE TO GET UP TO 2.25 BPM @ 3000 PSI),MITIA TO 1500 PSI(PASS)&DDTIA(PASS) TAG TD @ 7655'SLM(EST.18'OF RAT HOLE); DRIFT TBG W/2.74"X 16'DMY DRIFT DOWN TO 7437'RKB. READY FOR INJECTIVITY 9/20/2016 TEST,MITIA,&DDTIA. • • Start Date Last 24hr Sum RECEIVED APPROVAL FROM AOGCC INSPECTOR BRIAN BIXBY,WELDED MARKER PLATE ON,REMOVED SHORING BOX AND STAIRS, 12/7/2016 BEGAN BACKFILLING. 12/6/2016 P&A;POURED.06 BBL OF PORTLAND TYPE 1 CEMENT TO TOP OFF CONDUCTOR. 12/5/2016 P&A;TOPPED OFF CONDUCTOR WITH 2.6 BBLS OF PORTLAND TYPE 1 CEMENT. 12/4/2016 P&A:DUG EGRESS,SET STAIRS,CUT CASINGS AND REMOVED WELLHEAD. 12/3/2016 P&A:REMOVED JEWELRY,CUT AND REMOVED STANDING PLATE AND DUG TO 15'. 11/30/2016 P&A-REMOVED TREE 11/22/2016 P&A PREP-CEMENTING OA TO SURFACE 11/21/2016 P&A PREP-MIT OA(FAIL) 11/19/2016 P&A PREP 11/16/2016 (SEC)BLED T TO OPSI,IA&OA TOC,IA&OA FL FOR P&A,PRESSURED OA TO 400 PSI BEFORE FAILING MIT, 11/12/2016 (SEC):T,IA&OA DDT TO 0 PSI(ALL PASSED). T TOC @ 66". PUMPED 5 BELS HEC GEL DOWN THE OA FOLLOWED WITH 10 BBLS 15.7#AS1,SWAPPED TO PUMPING DOWN THE TUBING TAKING RETURNS OFF THE IA.PUMPED TILL WE GOT 15.7#AS1 AT THE TANKS. WEIGHED CEMENT WITH MUD SCALE AT THE TANK FARM. 15.6 PPG AT THE TANKS,SHUT DOWN. TOTAL CEMENT DOWN THE TUBING UP THE IA 63.5 AND 10 BBLS 15.7 PPG DOWN THE OA. 11/9/2016 ****READY FOR LRS IN 48 HR***** MIRU. RIH WITH SCMT. TOP OF CEMENT IN IA FOUND AT 1520'. PULL OUT OF THE HOLE. RIH WITH PUNCHER. PUNCH HOLES IN 11/8/2016 TUBING FROM 1490'-1494'. LRS CIRCULATE FLUID AT 1.8 BPM AND 2000 PSI. PULL OUT OF THE HOLE. RDMO. JOB COMPLETE. 11/7/2016 (MISC):ATTEMPT TO CIRC T X IA(NO COMMUNICATION). MIRU. RIH W/4'LOADED TUBING PUNCH WITH MED PUNCHER,4 SPF. TAGGED TOP OF CEMENT AT 1650'.PERFORATED INTERVAL 1620' -1624'. CCL TO TOP SHOT=6.6'. CCL STOP DEPTH=1613.4'. LOG CORRELATED TO RKB ON WELL SCHEMATIC. LRS 11/6/2016 UNABLE TO ESTABLISH CURCULATION AFTER PUNCH. RIGGED DOWN FOR NIGHT. TAG TOC @ 1617'SLM.MIT-T*PASSED*,MIT-IA*PASSED*,DD/NO FLOW TEST TBG*PASSED*,DD/NO FLOW TEST IA*PASSED*. 11/4/2016 READY FOR E-LINE 10/29/2016 PUMP 199 BBLS 15.8 CEMENT DOWN TUBING TAKING RETURNS FROM I/A.READY FOR SLICKLINE TAG. MIRU. RIH WITH TUBING PUNCHER. PUNCH HOLES IN TUBING FROM 7341-7345'. CIRCULATION TEST RESULTS: 2 BPM,1700 PSI 10/17/2016 ON TUBING,1200 PSI ON IA. PULL OUT OF THE HOLE. RDMO. JOB COMPLETE. STATE WITNESSED TAG&TEST(LOU GRIMADI); TAG TOC @ 7390'SLM; MITT(PASS); PASSED DDT AFTER 2 ATTEMPTS. READY 10/15/2016 FOR E-LINE PENDING PROCEDURE REVIEW. 10/14/2016 TAG TOC @ 7408'RKB(TARGETED TOC 7257'); OBTAIN GOOD 15 MIN.TEST&RE-TAG @ SAME. IN PROGRESS. SET CEMENT RETAINER AT 7425;SQUEEZE 23.5 BBL,15 PPG CEMENT BELOW RETAINER @ 0.6 BPM,3656 PSI;LAY IN 1.5 BBL CEMENT ABOVE RETAINER 7425'-7264'; CIRCULATE 20 BBL GEL CONTAMINATE AND CIRCULATED TO SURFACE WITH SLICK DIESEL; 10/12/2016 JOB COMPLETED 9/20/2016 PERFORMED SRIT(ABLE TO GET UP TO 2.25 BPM @ 3000 PSI),MITIA TO 1500 PSI(PASS)&DDTIA(PASS) TAG TD @ 7655'SLM(EST.18'OF RAT HOLE); DRIFT TBG WI 2.74"X 16'DMY DRIFT DOWN TO 7437'RKB. READY FOR INJECTIVITY 9/20/2016 TEST,MITIA,&DDTIA. z KUPD 2K-16 ConocoPhillips t Well Attribu Max Angi D TD Alaska.,Irz<. - Wellbore API/UWI Field Name Wellbore Status nel C) MD(ftKB) Act Btm(ftKB) canoc4h ipt. 501032011500 KUPARUK RIVER UNIT PROD 44.17 2,700.00 7,915.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 2K-16,1/3/2017 4'20:10 PM SSSV:TRDP 25 11/22/2015 Last WO: 40.19 10/23/1989 Vertical schematic.(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,670.0 7/27/2016 Rev Reason P&A WELL pproven 1/3/2017 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread -A."-CONDUCTOR;47.1-115.0- ' CONDUCTOR 16 15.062 47.1 115.0 115.0 62.50 H-40 WELDED Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ' . SURFACE 95/8 8.921 47.1 3,234.6 2,925.7 36.00 J-55 BTC APERF;1,490.0-1,494.0 I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Cement Plug;47.1ftK8 PRODUCTION 7 6.276 471 7,888.0 6,523.6 26.00.1-55 BTC 1~ ' 1 Tubing Strings I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..-Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection wTUBING 31/2 2.992 47.1 7,454.9 6,177.9 9.30 J-55 EUE-MOD Completion Details Nominal ID SAFETY VLV;1,803.2 # Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 1,803.2 1,783.1 21.53 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 7,361.9 6,104.4 37.89 PBR BAKER 80-40 PBR w/10'STROKE w/4"SEAL BORE 3.000 GAS LIFT;2,4271 7,375.5 6,115.1 37.86 PACKER BAKER HB RETRIEVABLE PACKER 2.890 '. 7,442.8 6,168.3 37.67 NIPPLE OTIS 2.913"XN NIPPLE w/2.75"NO GO 2.750 E 7,454.2 6,177.4 37.64 SOS BAKER SHEAR OUT SUB 2.992 Perforations&Slots Shot Dens SURFACE;47.1-3,234.6) 1 7 1 Top(ftKB) Btm(ftKB) Top(TVD) Btm(TVD) (shots/ ( ) (ftKB) (ftKB) Zone Date k) Type Com 1,490.0 1,494.0 1,484.5 1,488.3 A-4,2K-16 11/8/2016 4.0 APERF PUNCH HOLES IN TUBING GAS LIFT,4,5374 7,341.0 7,345.0 6,087.9 6,091.1 A-4,2K-16 10/17/2016 4.0 APERF PUNCH HOLES IN TUBING FROM 7341- 7345'.CIRCULATION GAS LIFT;5,779.1 TEST RESULTS:2 BPM,1700 PSI ON TUBING,1200 PSI ON iti 1 IA GAS LIFT,6,491.47,534.0 7,546.0 6,240.7 6,250.2 C-4,2K-16 4/25/1997 6.0 RPERF 2.5"HSD DP;60 deg ph . t 7,534.0 7,547.0 6,240.7 6,251.0 C-4,2K-16 6/26/1994 6.0 IPERF 2.125"EnerJet;90 deg GAS L,FT,6 919 9 ph;+/-45 deg orient 7,602.0 7,610.0 6,294.8 6,301.2 A-5,2K-16 4/25/1997 6.0 APERF 2.5"HSD DP;60 deg ph ,^�".v 7,634.0 7,674.0 6,320.3 6,352.3 A-4,2K-16 6/30/1990 4.0 APERF 180 deg phase,12 deg 10 CCW orient GAS LIFT.7,317.1 Cement Squeezes Top(TVD) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 7,415.0 7,888.0 6,146.3 6,523.6 Cement Plug 10/12/201 25 bbls,15.8 ppg cement(23.5 bbl below retainer+ il 6 1.5 bbl laid on top of retainer) APERF;7,341.0-7,345.0- 1,643,0 7,345.0 1,631.5 6,091.1 Cement Plug 10/28/201 199 BBLS 15.7 PPG Cement Plug;1,643.0 61(136 47.1 1,494.0 47.1 1,488.3 Cement Plug 11/19/201 10 BBLS 15.7 PPG AS1 INTO OA 6 15 BBLS 15.7 PPG AS1 INTO TUBING PBR;7,361.9 48 BBLS 15.7 PPG AS1 INTO IA PACKER,7,375.5 ' '`-'' Mandrel Inserts Pst at( on Top(TVD) Valve Latch Port Size TRO Run _N Top(5KB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,427.1 2,329.1 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/23/2012 GAS LIFT,7,397.8 2 4,537.4 3,901.2 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/23/2012 3 5,774.1 4,868.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/23/2012 4 6,491.4 5,422.7 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/22/1990 5 6,919.9 5,756.6 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/23/2012 6 7,317.1 6,069.1 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/25/2012 7 7,397.8 6,132.8 CAMCO MMG-2 1 1/2-PROD DMY BK 0.000 0.0 6/14/1990 Close h NIPPLE;7,442.8 Notes:General&Safety End Date Annotation 11/3/2010 NOTE:View Schematic w/Alaska Schematic9.0 SOS;7,454.2 1/15/2013 NOTE: IA x OA ON GAS(NO GASLIFT ALLOWED),OA x FORMATION 12/7/2016 NOTE:PLATE 4'BELOW TUNDRA LEVEL 47.1'RKB 12/7/2016 NOTE:REMOVED WELL HEAD 8 WELDED MARKER PLATE ON,REMOVED SHORING BOX AND STAIRS RPERF;7,534.0-7,548.04 (PERF;7,534.0.7,517.0 12/7/2016 NOTE:FINAL P&A COMPLETED 12/7/2016 APERF;7,602.0-7,6100 r WStrIkAPERF;7,634.67,674.0 . 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C $lig L '0 �� d m rl N N O n O N M ate+ Z b O O N O N > r N N + > E (0 1- , r� a s N r N N N N CCUT a rC 1 rl -5 n, N C C N ✓i 1.1 O C/3 a Ltb < , , , L L I I I I I I I I _ I-- a a z I I i • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ve-rl 1011-itl G, DATE: October 16, 2016 P. I. Supervisor /1 FROM: Lou Grimaldi SUBJECT: Wellbore Plug Abandonment Verification Petroleum Inspector KRU 2K-16 PTD 1890940, Sundry 316-447 Kuparuk River Field/Unit; CPAI Saturday, October 15, 2016: I witnessed the tag and pressure/drawdown tests on a wellbore plug for well abandonment on CPAI well 2K-16 in the Kuparuk River Unit. Plug Tag: I met Eddie Zemba (CPAI rep) on location this morning and after a short safety meeting the Halliburton wireline operator, Logan Burley, ran in the hole with a 2.25-inch drive down bailer. The zero point for the W/L tools this morning was the Tubing Hanger Flange (THF) which was noted as +31.1 feet on the wellbore drawing. ,i The tools were run into a depth of 7389 ft where they fetched up hard. I had the operator jar down a few times and made no noticeable footage. I requested they withdraw the tools slowly as not to wash any sample out of the bailer. The tools arrived at surface and the bailer end was within 1 foot of the original zero at the THF. The bailer was empty save for some wellbore fluid and the bottom (muleshoe) was dented somewhat indicating fetching up hard downhole. There were no indications of cured or clabbered cement. .✓ Pressure Test: Little Red pumping services provided the pressure test. There was not a calibrated test gage available this morning but a new 4" 2K strain gage with 10 psi subdivisions was used. There was 10 psi showing on the gage when it was in the box. It was agreed that as long as they pressure tested significantly higher than the minimum of 1500 psi I would accept the 10 psi offset. There was 660 psi on the tubing with fluid to surface. To raise the pressure to 1700 psi, 0.43 bbl's of 80-degree diesel was used. This was observed for 30 minutes with 70 psi lost in the first 15 minutes and 10 psi in the second 15 minutes. The tubing was bled back to 660 psi (original pressure) and approximately the same amount of fluid was returned. Drawdown Test: The rest of the pressure was bled down to 0 psi (10 psi offset at 0 on gage) and observed for 30 minutes with a 40 psi gain (non-linear). This pressure was bled to a bucket with approximately 2-3 quarts returned. Another 30-minute drawdown was observed with a 10 psi increase observed, again this was bled to a bucket with approximately 1 quart returned. The 3rd 30-minute drawdown produced no observed pressure buildup and no fluid returned. Attachments: Operator Pressure Test Report SCANNED APR 0 72017 2016-1015_Plug_Verification_KRU_2K-16_1g.docx 1 of 1 0 410 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reoq(cialaska.gov. AOGCC.Inspectorst alaska.gov phoebe.brooks@alaska.qov chris.wallace(c@alaska.gov OPERATOR: ConocoPhillips Alaska,IncZee�h (C:�t—711'4' FIELD/UNIT/PAD: Kuparuk/KRU/ 2K Pad lL DATE: 10/15/16 OPERATOR REP: Burley-HES AOGCC REP: Lou Grimaldi Packer Depth Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min. Well 2K-16 Type Inj. N ' TVD 6,115 Tubing 660 1,700 1,630 1,620 Interval o P.T.D. 1890940 - Type test P Test psi 1528.75 Casing 0 5 5 '5 P/F P ''' Notes: Slickline to tag TOC and perform MIT against OA 45 45 45 45 cement per Sundry 316-447 Well 2K-16 Type Inj. N TVD 6,115' Tubing 660 10 40 50 Interval OA, �N P.T.D. 1890940 Type test M Test psi 1528.75 Casing 0 0 0 0 P/F F HCl Notes: Gauge was identified as being 10 psi off OA 45 45 45 45 2.5 quarts returned during bleed back Well 2K-16 Type Inj. N TVD 6,115' Tubing 50 10 20 Interval 0 P.T.D. 1890940 Type test M Test psi 1528.75 Casing 0 0 0 P/F F 1. 2q1 tiS00tni t,..)It Z Notes: 2nd attempt,inspector ok with gauge 10 psi off OA 45 45 45 1.5 Pints returned durin bleed back Well 2K-16 Type Inj. N TVD 6,115' Tubing 20 10 10 10 Interval O /,e/1ti 31V1.0 ). 3 P.T.D. 1890940 Type test M Test psi 1528.75 Casing 0 0 0 0 P/F P Notes: 3rd attempt,gauge still 10 psi high OA 45 45 45 45 No fluid returned during bleed back Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT KRU 2K-16 10-15-16.xls yOF T�� • • ��y�� THE STATE Alaska Oil and Gas F Of T A Conservati®n Commission tst£=- 1/,,741-1674* _== SKA 333 West Seventh Avenue _t _ C Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 oFALAS ' Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek Staff Well Integrity Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-16 Permit to Drill Number: 189-094 Sundry Number: 316-447 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, Cathy '. Foerster Chair DATED this 464 of September,2016. RBDMS ix SEP 1 6 2016 • ill RECEIVED • STATE OF ALASKA AUG 30 ib,.) , ALASKA OIL AND GAS CONSERVATION COMMISSION PT'S 71('5 1 J b APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon , Plug Perforations r Fracture Stimulate r Repair Well r Operations Shutdow n r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program 1--- Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: r- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development 189-094 • 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20115-00 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes r No 17 J KRU 2K-16 ' 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 TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,915' • 6,545' - 7802' • 6454' • 3433 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 115' 115' Surface 3,200' 12" 3,235' 2926' Intermediate Production 7,855' 7" 7,888' 6519' Liner Perfora onIR a th MD(ft): - 4) Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 73 7674' 6320'-6352' 3.5" J-55 7,454' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): BAKER HB RETRIEVABLE PACKER • 7376'MD/6115'TVD CAMCO TRDP-1A-SSA SAFETY VALVE - 1803'MD/1783'TVD 12.Attachments: Proposal Summary ❑ Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory r Stratigraphic r Development pi• Service r 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 9/16/2016 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG r GSTOR E SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned 1 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 Jill.Simekconocophillips.com Printed Name Jill Simek Title Staff Well Integrity Engineer Signature -.NI ..Sy L___' Phone 263-4131 Date 08/29/16 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\tP ^ 417 Plug Integrity n/ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Er } / Other: / ,,00 a o cj d C v vu< r* �t Gf 5 Yr U / r di �} 0CleZ_ kr. fYLff5 Y /' Post Initial Injection MIT Req'd? Yes ❑ No ill Spacing Exception Required? Yes ❑ No V Subsequent Form Required: / D — Ifr :' RBDMS cu' SEP 1 6 2016 APPROVED BY Approved by: Q P COMMISSIONER / THE COMMISSION Date: 9_/�� '•r i/I 1177— !l 2I l(`-' ( Submit Form and Form 10-403 Revised 11/2015 0 I GP � d�ag�ic tion is valid for 1 months from the date of approval. GY//6 Attachments in Duplicate • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 25 August 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 Producer 2K-16(PTD#: 189-094). 2K-16 was originally drilled and completed in 1990 as a 3- 1/2"single producer. In July 2010,it was discovered that the well had a surface casing leak. It was shut- in from July 2010 until January 2013. Since 2013,2K-16 has been seasonally producing without lift gas due to the surface casing leak. Without lift gas,2K-16 is a low producing well. However,the rig workover to gain lift gas has been deemed as uneconomical. In lieu of riaworkover,a coiled tubing drilling campaign at 2K-11 is planned to recover the 2K-16 reserves./Furthermore,a grassroots well is planned at 2K,to utilize the-21K-16 location and reuse flowlines,we ouse an. o er aci i i-s. v,1 ou any ure u 1 an. a nee. o recover the 2K- 1-6—location, K- 6 location,a P&�of the well is recommended. P The well has 9-5/8"surface casing to 3,234.6'KB and 7"production casing to 7,888.0'KB. There is 3- 1/2"tubing with a packer at 7,375.5'KB. Three sets of Kuparuk perforations are at 7,534.0'-7,547.0'KB, 7,602.0'-6,610.0' KB,and 7,634.0'-7,674.0'KB. Per this procedure,P&A operations will be performed with coiled tubing to set a cement retainer at approximately 7,425'KB and 24.9 bbls pumped into the 7"casing,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 7,257'KB. Holes will then be punched in the tubing,above Plug#1 Top of Cement(TOC)at approximately 7,234' KB,and 94 bbls of cement will be pumped fullbore to place cement in the tubing and tubing x production casing annulus(IA). TOC of Plug#2 is calculated to be 1,700'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 and IA. A cement downsqueeze will follow to place approximately 174 linear feet of cement in in the surface casing x production casing annulus(OA). The well will then be excavated 4 feet below 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. Sincerely, J. 1 Simek ell Integrity Engineer CPAI Drilling and Wells (0/10 90 0 w ti�q Tti wcr� waf (O 'c.j Ivo { �v��u cG�^6 /�qk e ►t Prav`'4f I9I, yo G0 . f/9;., I ill 0(1,3 Coverer! ahcare d (S f A wGU SD 7-44 r set, 9/40 roes 14,,c4/ C94 6e drlllr'/ al/ 14'`t1.ACk` // ahs jt:�y w�l I ofra:n ({f Qr vu Cvr/tn 41, ,h�, /crv�� if 70 Auld qil ow fi, ,'yveti re& , fro* * pOOL fq// • ConocoPh i I I i ps 2K-16 P&A Permit to Drill #: 189-094 Per this procedure, P&A operations will be performed with coiled tubing to set a cement retainer at approximately 7,425' KB and 24.9 bbls pumped into the 7" casing, 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 7,257' KB. Holes will then be punched in the tubing, above Plug#1 Top of Cement (TOC) at approximately 7,234' KB, and 94 bbls of cement will be pumped fullbore to place cement in the tubing and tubing x production casing annulus (IA). TOC of Plug #2 is calculated to be 1,700' KB. Tubing will be punched above Plug #2 TOC and a third cement plug (Plug #3) will be pumped fullbore, to bring cement to surface in the tubing and IA. A cement downsqueeze will follow to place approximately 174 linear feet of cement in in the surface casing x production casing annulus (OA). The well will then be excavated 4 feet below original ground level, wellhead and cellar removed, and site backfilled with gravel/fill to ground level. Proposed P&A: Slickline/ Little Red: Objective: MIT-IA, DDT-IA, injectivity test, drift for cement retainer 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU SL and PT Equipment as required. 3. RIH with bailer for tag. 4. RIH with 2.74" x 15' dummy mechanical cement retainer tool string, down to 7,425' KB. Attempt with a 10' toolstring if the first drift is not successful. 5. Using LRS, perform step rate injectivity test with diesel from 0.5—3 BPM, in '% BPM increments, up to a Max Pressure of 3,000 psi, to ensure adequate rates for cementing operations. Record Results. 6. Perform MIT-IA to 1,500 psi. Report issues and results to PWS. 7. Perform DDT-IA. Report issues and results to PWS. 8. RDMO. Schlumberger Coiled Tubing/Cementing: Objective: Plug 1 —Set cement retainer at 7,425' KB. Place a cement plug in 7" casing, across the open perforations and into tubing. Bring Top of Cement (TOC) in tubing to approximately 7,257' KB. JS • 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: • 7" casing volume from 100' below perfs to cement retainer: (7,774.0'-7,425') x 0.03826 = 13.4 bbl • 3 %2"tubing volume from cement retainer to 7,257' KB: (7,425'-7,257') x 0.008697 = 1.5 bbl • Squeeze volume: 10 bbl • Total volume: 13.4 + 1.5 + 10 = 24.9 bbl 1. Ensure an approved sundry has been received from AOGCC. 2. Contact Schlumberger a week before the scheduled P&A date, to allow adequate time e f or pilot testing of the P&A cement t desi n. (Lucas Skinner Fred Kitterman @ 659-6121 or 659-2434). The job is designed for 24.9 bbls of 15.8# UniSLURRY* 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 7/28/2016 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 cement retainer, taking returns up the CT x Tubing annulus. Do not pump while RIH. 7. Set cement retainer at approximately 7,425' KB (in full tubing joint below the packer), or as deep as the retainer will safely drift. 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 SLB Cement Equipment and PT surface lines as required. 11. Pump 10 bbls fresh water spacer 12. Pump 13.4 bbl of UniSLURRY* + 10 bbl 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 1.5 bbl cement above retainer. Fill tubing, taking returns up the coil tubing x tubing annulus. Keep 50' to 100' of cement around coil, then pump and pull to 7,257' KB. 15. POOH above TOC 16. Circulate CTU clean. 17. RDMO Js Slickline/ Little Red Objective: Tag TOC, MIT-T, DDT 1. WOC for 48 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. Notify the AOGCC Inspector of the timing of the cement plug tag and pressure testing. TAG MUST BE AOGCC WITNESSED. PROVIDE 24HRS NOTICE FOR INSPECTOR. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU SL and PT Equipment as required. 4. RIH and tag TOC @ approximately 7,257' KB. Record results and report tag depth to Well Integrity Engineer. 5. RU LRS and PT Surface Equipment as required. 6. Perform MIT-T to 1,500 psi. Record results. 7. Perform DDT on Tubing. Record results. 8. Report issues & results to Well Integrity Engineer. 9. RDMO 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 EL and PT Equipment as required. 3. RIH with 2" x 4' tubing punch, 4 spf; reference 7/28/2016 schematic and tubing details for depth correlation. 4. Punch at approximately 7,230'-7,234' KB or at middle of first full joint above tagged TOC. 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. Schlumberger Cementing: Objective: Plug 2 - Place a cement plug in tubing and IA from perforations (approximately 7,234' KB)to 1,700' KB. Cement Volume Calculations: • Tubing: (0.008697 bbl/ft) * (7,234'-1,700' KB) = 48.1 bbl • 3-1/2" x 7"Annulus: (0.02636 bbl/ft) * (7,234'-1,700' KB) = 145.9 bbl JS • • • Total volume = 48.1 + 145.9 = 194 bbl • Displacement volume: (1,700' KB) * (0.008697 bbl/ft) = 14.8 bbl- 10 bbl spacer= 4.8 bbl 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. Ensure a 5"foam ball is loaded into the tree prior to the cement job. 3. MIRU cementers. Ensure to rig up a cement clean up line using an isolation valve and "T" connection off the tree. 4. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from the 3 1/2" x 7" (IA) annulus. Also ensure that there is a way to pump down the IA in case the tubing pressures up. 5. PT surface equipment as required 6. Establish circulation with seawater/brine 7. Pump 10 bbls fresh water spacer 8. Pump 194 bbls of 15.8 ppg UniSLURRY*. • Assumes tubing punch at 7,230'-7,234' KB. Recalculate based on actual tubing punch depth. 9. Drop 5" Foam Ball 10. Pump 10 bbls fresh water spacer 11. Displace with 4.8 bbls diesel to leave Top of Cement in tubing and IA at 1,800' KB. 12. Shut down SLB pumps and close in Tubing and IA. Do not overdisplace. 13. Wash up SLB cement pumps and clean up surface lines. 14. RDMO Slickline/ Little Red Objective: Tag TOC, MIT-T & MIT-IA, DDT 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 SL and PT Equipment as required. 4. RIH and tag TOC @ approximately 1,700' KB. Record results and report tag depth to Well Integrity Engineer. 5. RU LRS and PT Surface Equipment as required. 6. Perform MIT-T to 1,500 psi. Record results. 7. Perform MIT-IA to 1,500 psi. Record results. 8. Perform DDT on Tubing and IA. Record results. 9. Report issues & results to Well Integrity Engineer. 10. RDMO JS • • E-line/ Little Red Objective: Punch 31/2" tubing 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 e-line and PT Equipment as required. 3. RIH with 2" x 4' tubing punch, 4 spf; reference 7/28/2016 schematic and tubing details for depth correlation. 4. Punch 30' above TOC, as close to mid joint as possible. 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 Schlumberger Cementing: Objective: Plug 3 - Place a cement plug in tubing and IA from tubing punch (-1,700' RKB) to surface. Cement Volume Calculations: • 3-1/2" x 7"Annulus: (0.02636 bbl/ft) * (1,700' KB) = 44.8 bbl • Tubing: (0.008697 bbl/ft) * (1,700' KB) = 14.8 bbl • Excess = 10 bbl • Total volume = 44.8 + 14.8 + 10 = 69.6 bbl 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU SLB Cement Equipment, ensuring that hardline is rigged up to pump down the tubing and take returns to a tank from the 3'/2" x 7" annulus. 3. Tie in cement wash up lines, and isolation valves that will allow for surface lines to be flushed when cement is seen at surface. 4. PT surface equipment as required. 5. Pump 10 bbls fresh water spacer. 6. Based on theoretical tubing perforations, pump 69.6 bbl 15.7# ArcticSet* 1 (AS1). • AS1* volume assumes tubing punch depth of 1,700' KB. Recalculate volume based on actual punch depth. 7. Monitor returns on surface, taking samples and checking pH/density. 8. Once good cement returns are verified on surface (use mud scale for cement density measurement), shut down and open up the surface bypass line to flush all lines with water. JS • • 9. Wash up SLB cement pumps. 10. Pump wellhead volume at 0.5 bpm (count pump strokes) a. Wellhead volume needs to be calculated before job and agreed upon with co-rep and SLB field personnel 11. RDMO Schlumberger Cementing: Objective: Plug 4 — Downsqueeze 7" x 9-5/8" Annulus (OA) from surface to approximately 174' KB. Cement Volume Calculations (TOC at surface): • 7" x 9-5/8"Annulus: (0.02971 bbl/ft) * (174' KB) = 5.2 bbls • Excess: 5.2 bbl • Total volume = 5.2 + 5.2 = 10.4 bbl 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. Pressure test SLB lines 3. Line up down surface casing 4. Pump 5 bbl of water as spacer ahead at 5 bpm 5. Pump 10.4 bbl of ArcticSet* 1 (AS1) at 2 bpm 6. Line up to open top 7. Pump 5 bbl of water to clear SLB lines at 5 bpm 8. Line up down surface casing 9. Pump wellhead volume at 0.5 bpm (count pump strokes) a. Wellhead volume needs to be calculated before job and agreed upon with co-rep and SLB field personnel 10. RDMO Little Red: Objective: DDT 1. WOC for 48 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. RU LRS and PT equipment. 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. JS •• • 10�4� 4. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent bee ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. 6. Perform Top Job and verify that cement is at surface in all strings. AOGCC witness and photo document required. 7. Send the casing head w/stub to materials shop. Photo document. 8. Weld 1/4"thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips 2K-16 PTD # 189-094 API # 50-103-20115-00 9. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo document final location condition after all work is completed. Js s KUP OD 2K-16 ConocoPUIlips 4 Well Attrib Max Ang D TO • Alaska,Inc. Wellbore APUUWI Field Name Wellbore Status ^ncl(-) MD(ftKB) Act Elbe(NCR) r_onxoPhlhps f 501032011500 KUPARUK RIVER UNIT PROD 44.17 2,700.00 7,915.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 26-16.8/11/20161:46:57 PM SSSV:TRDP 25 11/22/2015 Last WO: 40.19 10/23/1989 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,670.0 7/27/2016 Rev Reason:H2S,TAG pproven 7/28/2016 hi - ll asmg rings HANGER,31.1 I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread II CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED 115 Descnption OD(in) ID p) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(ILen . Grade Top Thread �� ! Cooing SURFACE 9 5/8 8.921 35.0 3,234.6 2,925.7 36 00 J 55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len Len .Grade Top Thread PRODUCTION 7 6.276 33.0 7,888.0 6,523.6 26 00 J-55 BTC ��' �f� Tubing Strings - CONDUCTOR,36 x115.0Tubing Description 'String Ma...'ID(in) 'Top(ftKB) 'Set Depth(ft..f Set Depth(ND)(...IWt(IbHt) (Grade 'Top Connection TUBING 31/2 2.992 31.1 7,454.91 6,177.9 9.30 J-55 EUE-MOD Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) SAFETY VLV;1,803.2 !o. 31.1 31.1 0.03 HANGER FMC GEN IV TUBING HANGER 3.500 1,803.2 1,783.1 21.53 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 7,361.9 6,104.4 37.89 PBR BAKER 80-40 PBR w/10'STROKE w/4"SEAL BORE 3.000 GAS LIFT:2,42717,375.5 6,115.1 37.86 PACKER BAKER HB RETRIEVABLE PACKER 2.890 7,442.8 6,168.3 37.67 NIPPLE OTIS 2.913"XN NIPPLE w/2.75"NO GO 2.750 7,454.2 6,177.4 37.64 SOS BAKER SHEAR OUT SUB 2.992 E Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com SURFACE,350-3,234.6* • 7,534.0 7,546.0 6,240.7 6,250.2 C-4,2K-16 4/25/1997 6.0 RPERF 2.5"HSD DP;60 deg ph GAS LIFT;4,537.4 7,534.0 7,547.0 6,240.7 6,251.0 C-4,2K-16 6/26/1994 6.0 IPERF 2.125"EnerJet;90 deg ph;+/-45 deg orient 111 7,602.0 7,610.0 6,294.8 6,301.2 A-5,2K-16 4/25/1997 6.0 APERF 2.5"HSD DP;60 deg ph GAS LIFT;6,774.1 7,634.0 7,674.0 6,320.3 6,352.3 A-4,2K-16 6/30/1990 4.0 APERF 180 deg phase,12 deg CCW orient Mandrel Inserts GAS LIFT;6,491.4 St III N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sem Type Type (in) (psi) Run Date Com GAS LIFT;6,9199 1 2,427.1 2,329.1 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/23/2012 2 4,537.4 3,901.2 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/23/2012 .11 3 5,774.1 4,868.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/23/2012 4 6,491.4 5,422.7 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/22/1990 5 6,919.9 5,756.6 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/23/2012 GAS LIFT;73171 6 7,317.1 6,069.1 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/25/2012 7 7,397.8 6,132.8 CAMCO MMG-2 11/2 PROD DMY BK 0.000 0.0 6/14/1990 Close MI d Notes:General&Safety End Date Annotation 11/3/2010 NOTE:View Schematic w/Alaska Schematic9.0 PBR;7,361 9 ill 1/15/2013 NOTE: IA x OA ON GAS(NO GASLIFT ALLOWED),OA x FORMATION PACKER,7,375.5 GAS LIFT;7,397.8 • NIPPLE,7,442.8 3 RR SOS.7,454.2 . RPERF;7,534 .0.7,546 0 'PERF;7,534.0-7,547 II APERF;7,602.0-7,610.0 APERF,7,634.0-7,674.0 PRODUCTION;33.0-7,888.0 S • , P&A Diagram: 2K-16 Plug & Abandonment PTD#: 189-094 Current Completion Proposed P&A AiL --,:kiii:::remt;-.45-a2.,, Fourth Plug(Q4)174'KB . .._______ . --- to... 18-"W_5#1-1-40 Cm-Mucky @ 1 15-KB Al L 6 aftlitiws-s,v.i . 15.714,ghttie.etTlswfwe Third Pkocl(T&IA) e'r'17'**5'476;';I'f'll 1,7i7 ArcbcSeti 1,70ff KB-Surface pVF:trel:1 41.':' bang Pinch: -1,7tG'EB SSSV @ 1.8037 KB Third F.A474 fr&LA)7234'-1,7Bff KB GLK DAY g 2,427.r KB a4:kwit.ro...;\ 1-5i3 ppg Class*G- WITA:t...0,44' 10-11M1 Ak KB.d..Ad ..,44,:„‘,,,,,,.kt:p-A L.._h. BB-Tr MU-55 Strface Cascrg qg 3234.6' 'AR41 'ite:MVi.Z.Iql WA kftg ke°ft ''',I,Nkk4.tit.*:klA fki:z4 Vtt..titA. -r 4i alit NAMti ? DAY 4,537.4'KB ,VNIO*Z4ft MAY 5774.1'KBA\NAZt-taw.,,M4 -1'51 .AW,, /a‘g )4' C ' r i=4 DAY 64g 1.4'KB DMY @ 6,0111cr KB talktal 77. 2k.,,,A0kLkAtAk:At.„. DMY ttp 7,31 7.1'KB :Fat, \vi,sttio%, , -ming Rrch:7237-7,234KB : .4 7'77.;-' Frst Hug CPerfs.Tubtng)7.774'-725T KB 15.8 Kg Class"G` Baker HE Retrievable Packer @ 7,3765 KB GL t DAY @ 7,397.8'KB 41tit! ,...!,. CMS a913'XN Nipple ve2.75"NO-GO @ ppoi Cement Retamer g 7.425 KB 7,442.8'KB 3-W 9..a$)J-55 Tubing Cg 7.454.8 KB 440re.„,.. ,1,A,..4 *to v4 ;,......_.. Pis: ----"5'-"a' ''.."(4,4,047,2,_—re _ -7==‘,. -- ..,.-:,,•i 7,53C0-7,547.ff KB '... ftileatt' .--- -,... "r- — 7.02.11-7BIDAI KB Ay Alii..541.9 P - ,r..3 — 7.634.0-7,874.ff KB - '1144606::e p. '-^- ..aill 16.. T 2EW L-80 Prcchiction Casing a 7aga-0.KB ytig JS 8-24-2016 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. /~Od'~-'~'¢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 Br~Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd ConocoPhillips ~as~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 1, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7t" Avenue, Suite 100 Anchorage, AK 99501 ~ r,, ,. ,:, , ~ ~ fr`~~F Commissioner Dan Seamount: d ~~ ~~6~ I~ ~~ ~~ ~~ ti~1~ SS,;;:, . ~, ~~~ ~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 21St. The corrosion inhibitor/sealant was pumped July 30tt', 31St 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/01/10 ~c ~v o-r own ell Name PI # TD # 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 26-13 50029211380000 1841040 64" 0.4 11" 7/21/2010 1.7 7/31/2010 2K-16 50103201150000 1890940 SF n/a 19" n/a 2.8 7/31/2010 2K-20 50103201200000 1891180 10" n/a 10" n/a 2 7/31!2010 2K-23 50103201250000 1900140 SF n/a 18" n/a 2.6 7/31/2010 2K-24 50103201220000 1891300 SF n/a 18" n/a 2.6 7/31/2010 2T-07 50103200690000 1861080 17" n/a 17" n/a 5.1 7/30/2010 2T-19 50103202140000 1950260 18" n/a 8" n/a 2 7/30/2010 2T-20 50103202150000 1950290 SF n/a 23" n/a 2.6 7/30/2010 2T-21 50103202120000 1950130 SF n/a 21" n/a 3.4 7/30/2010 2T-26 50103202230000 1950820 SF n/a 27" n/a 4.3 7/30/2010 2T-29A 50103202220100 2091360 SF n/a 29" n/a 7.7 7/30/2010 2T-30 50103202190000 1950570 SF n/a 30" n/a 6 7/30/2010 2T-31 50103202260000 1950990 30" n/a 30" n/a 6 7/30/2010 2T-36 50103202280000 1951020 SF 0.40 12" 7/21/2010 2.6 7/30/2010 2T-39 50103203920000 2011830 30" 0.54 14" 7/21/2010 4.3 7/30/2010 2T-201 50103202300000 1951220 60" 1.57 32" 7/21/2010 7.7 7/30/2010 2T-204 50103203270000 2000160 SF n/a 24" n/a 5.1 7!31/2010 2T-209 50103202810000 1982430 40" 1.20 19" 7/21/2010 4.8 7/31/2010 2T-218 50103204490000 2030170 31" 0.73 9" 7/21/2010 2.6 7/31/2010 2T-220 50103202830000 1982530 38" 0.49 19" 7/21/2010 5.1 7/31/2010 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 2K-16 Run Date: 5/4/2010 July 15, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K-16 Digital Data in LAS format, Digital Log Image file, Interpretation Report 50-103-20115-00 Production Profile Log 50-103-20115-00 1 CD Rom 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNIN OPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton ~ (~~~ ~ Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. ~ 4~~.33 Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto ny 3=-~ -~ ~' ~ ~~ ~~, Date: ~~! ~ ~~n', Signed: 4~+ 01/24/07 Schlumberger SCANNED JAN 3 () 2007 NO. 4121 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth .I/\N ? 9 ZOO7 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 I ~D¡ - t:/1 L( Field: Kuparuk Well Color CD Job# Log Description Date BL 1 C-111 11415647 RST WFL 10/29/06 1 2B-01 11536780 PROD PROFILE 01/04/07 1 2H-11 11539477 PROD PROFILE 01/04/07 1 2B-02 11538781 PROD PROFILE 01/05/07 1 3N-19 11538782 PROD PROFILE 01/06/07 1 2W-06 11538784 PROD PROFILE 01/08/07 1 1C-28 L 1 N/A GLS 01/16/07 1 2M-06 11628958 INJECTION PROFILE 01/20/07 1 1 C-117 11628954 INJECTION PROFILE 01/18/07 1 2K-16 11638814 PRODUCTION PROFILE 01/22/07 1 1Y-22 11638815 PRODUCTION PROFILE 01/23/07 1 2N-337 A N/A SBHP SURVEY 01/21/07 1 2M-26 N/A SBHP SURVEY 01/21/07 1 2M-03 N/A INJECTION PROFILE 01/22/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . ALASKA ~.,L AND GAS CONSERVATION COMIV,._.31ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other i2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 55.20 [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Duck Island Unit/Endicott P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2526' SNL, 809' WEL, SEC. 08, T11N, R17E, UM 3-15/K-33 At top of productive interval 9. Permit Number / Approval No. 189-094 2129' SNL, 3811' WEL, SEC. 04, T11N, R17E, UM 10. APl Number At effective depth 50- 029-21751-00 455' SNL, 3040' WEL, SEC. 04, T11 N, R17E, UM 11. Field and Pool At total depth Endicott Field / Endicott Pool 324' SNL, 2984' WEL, SEC. 04, T11N, R17E, UM 12. Present well condition summary Total depth: measured 14640 feet Plugs (measured) Top of Cement Plug at 12700'; Cement Retainer at true vertical 10180 feet 12750; Baker 3-3/8" IBP at 12825' (04/98) Effective depth: measured 12700 feet Junk (measured) true vertical 9944 feet Casing Length Size Cemented MD TVD Structural Conductor 92' 30" Driven 131' 131' Surface 2460' 13-3/8" 3730 cuft Permafrost 2516' 2516' Intermediate 12508' 9-5/8" 1150 cuft Class 'G' 12564' 9871' Production 2571' 5-1/2" 1248 cuft Class 'G' 14585 10215' Liner Perforation depth: measured Open: 12620' - 12636', 12654' - 12664', 12678'- 12688' Sqz: 12688'- 12698', 12770'- 12774' Isolated: 13050'- 130710', 13962'- 13995', 14022'- 14050', 14210 - 14261', 14460'- 14490' true vertical Open: 9903' - 9911', 9921' - 9926', 9933' - 9938' Sqz: 9938' - 9943', 9976' - 9976' Isolated: 10053' - 10097', 10112' ~ 10114', 10116' - 10118', 10130' - 10134', 10156' - 10161' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, 13Cr80 to 11783'; 5-1/2", 17#, 13Cr to 12004' Packers and SSSV (type and measured depth) 9-5/8" x 7" Liner Top Tie-Back packer at 12000'; 9-5/8" TIW 'HBBP' packer at 11794'; 9-5/8" x 4-1/2" Baker'S-3' packer at 11713'; SSSV Lar~~l~tlit~5~-- 13. Stimulation or cement squeeze summary I '~ ~ ~ ~ ~ v .--- ,-,. Intervals treated (measured) JUN 1 3 ZOO1 Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Commission Anchorage 14. ,Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble~*~ ~ Title TechnicalAssistant Date ~)~:).- l,~'-(~/ Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 Legal Well Name: 3-15 Common Well Name: 3-15/K-33 Spud Date: 9/25/1987 Event Name: WORKOVER Start: 4/22/2001 End: Contractor Name: DOYON Rig Release: Rig Name: DOYON 15 Rig Number: ::::i:.:.."'~::.. D~te:iii':.: ': :,?i:Fro:m'~::':?~:": ':' :':":' ~.:Toi!: ~?~s ~tiYi~" '~d~ '"~NpT':' phaSe Description of Operations 4/22/2001 18:00 - 22:00 4.00 MOB P PRE Moved off 3-25a/N-24 to rig mats on edge of location. Removed rig mats and herculite for wireline unit. 22:00 - 00:00 2.00 MOB P PRE Waiting on well to be prepped for rig move to 3-15. 4/23/2001 00:00 - 17:00 17.00 MOB P PRE Wait on Production for well prep - While waiting moved rig module lined up to pull over well 3-15 - cleaned up around well 3-25 well house - maintance on rig 17:00 - 20:30 3.50 MOB P PRE Lay herculite and mats for rig move. 20:30 - 22:30 2.00 MOB P PRE Pull rig overand spot on well 3-15 - move pit module and spot. 22:30 - 23:30 1.00 MOB P PRE slide floor over well 23:30 - 00:00 0.50 MOB P PRE Rig up 4/24/2001 00:00 - 06:00 6.00 BOPSUF P DECOMP Nipple down Tree. 06:00 - 13:30 7.50 BOPSUF,P DECOMP Nipple up BOP equipment. Make up crossover on hanger to inspect thread quality. OK. Remove same. Install spacer spool, riser and BOP stack. Nipple up. 13:30 - 16:00 2.50 BOPSUF,P DECOMP Make up test joint and attempt to test BOP's. Leak in wellhead because fluid coming out of annulus valve on Iow test. 16:00 - 20:00 4.00 BOPSUF N SFAL DECOMP Pull test joint and evaluate leak in tubing hanger. Found lock down screws would all tighten up 3/4 to 1 1/2 rounds to get to 600 ftlbs torque as required. Reinstall test joint. 20:00 - 00:00 4.00 BOPSUF P DECOMP Test BOPE. AOGOC represenative Lou Grimaldi waived witnessing the test. Test rams, valves, etc to 250 psi Iow and 3500 psi high. Annular to 250 psi Iow and 2000 psi high. 4/25/2001 00:00 - 04:30 4.50 BOPSUI~ ~ DEOOMP Finish testing BOPE. Rams, valves, choke floor tools, 250 psi Iow/3500 psi high. Annular to 250 psi Iow/2000 psi high. Witnessing of test by AOGCC rep Lou Grimaldi waived. Replaced manual valve on kill side and retested. Floor valved failed. Replaced and tested floor valve. 04:30 - 08:30 4.00 WHSUR P DECOMP Rig up to pull Two way check, Jet wellhead to clean off trash. Pull TWO with Wellhead Maintenance. 08:30 - 09:30 1.00 PULL P DECOMP PJSM. Change out to longer bails. Pick up 7" landing joint and install in tubing hanger. 09:30 - 11:00 1.50 PULL P DECOMP PJSM. Rig up Schlumberger Wireline. 11:00 - 13:30 2.50 PULL P DEOOMP RIH w/12' of 80 grain string shot to 12,000'. Run strip correlation. Shot string shot across pup from 11,780'-11,792'. POOH. 13:30 - 20:00 6.50 PULL ~ DECOMP PJSM. Rig up pack off and pump in sub. Pull tubing in tension and set slips. Hookload at 300k. Tubing in air plus 30k plus Top Drive. RIH with 4 7/16" chemical cutter to 11785'. Correlate and shot. No surface indication of fire for 15 minutes. Then we felt a shock while Schlumberger was POOH. 20:00 - 21:00 1.00 PULL ~ DECOMP PJSM. Rig down pack off to pull cutter. Schlumberger laid down cutter. All signs it fired correctly. 21:00 - 21:30 0.50 PULL P DECOMP Rig up on landing joint and verify cut. PU 235k, SO 200k. Release Schlumberger. Rig up to circulate and filter fluid. 21:30 - 00:00 2.50 PULL P DECOMP Circulate and filter wellbore fluids with Baroid filtering unit. Rig down Schlumberger while circulating. 4/26/2001 00:00 - 05:00 5.00 PULL P DEGOMP Circulated 1-3 bpm while filtering 9.2 ppg brine. Brine out of filter unit 11 NTU, Brine in pits 33 NTU and brine out of hole 80 NTU. Filtered two complete hole volumes. 05:00 - 00:00 19.00 PULL ~ DECOMP Rigged up Camco spooling unit to pull out of hole. Laid out Printed; 5/24/2001 2:43:28 PM Legal Well Name: 3-15 Common Well Name: 3-15/K-33 Spud Date: 9/25/1987 Event Name: WORKOVER Start: 4/22/2001 End: Contractor Name: DOYEN Rig Release: Rig Name: DOYEN 15 Rig Number: D~. F~ ~o Hours ~iv[~ Cod~: NpT phase . Description of Operations 4/26/2001 05:00 - 00:00 19.00 PULL P DECOMP tubing hanger. Pulled out of hole with 5-1/2" chrome tubing. At jt. #229 of 286 to pull out of hole. All control line bands accounted for. 4/27/2001 00:00 - 03:00 3.00 PULL P DECOMP Finished pulling out of hole laying down 5" chrome tubing. Laid down 286 full joints and 3' of cut pup joint. Recovered 4 steel bands and 19 rubber clamps. Rigged down tubing handling equipment. 03:00 - 05:00 2.00 PULL ~ DECOMP Rigged up and RIH with 9-5/8" pack-off pulling tool. Engaged pack-off. Bled off pressure on annulus. Backed out lock down screws. Pulled 10-20-30-40K and worked pack off free with 42K. Pulled 9-5/8" pack off. Installed new 9-5/8" pack off and ran in lock down screws. Tested pack-off to 5000 psi. 05:00 - 06:30 1.50 BOPSUF; ~ COMP Pull 7" X 4" VBR in top set of rams. Install 3-1/2" solid block rams. 06:30 - 07:30 1.00 BOPSUR P COMP Pressure tested lower 3-1/2" x 6" rams and upper 3-1/2" solid rams to 250 psi/3500 psi. 07:30 - 08:30 1.00 RUNCOI~P COMP Rigged up Halliburton slick line unit and lubricator. 08:30 - 14:30 6.00 RUNCO~ F' COMP Made up 8.375" gauge ring and junk basket and ran in hole. Tagged top of tubing stump at 11792' WLM. Pulled out of hole and recovered small piece on junk in junk basket. 1/4" around and approximately 4-1/2" long. Rigged down wireline. 14:30 - 17:00 2.50 RUNCOI~' COMP Rig up to run completion. Hang wireline shiva in derrick. Rig up tongs and computer equipment for Chrome tubing. 17:00 ~ 00:00 7.00 RUNCOI~ COMP Run 3 1/2" 9.2# 13cr80 VAM-ACE tubing completion. PU overshot, XN nipple X nipple, Baker 9 5/8" x 3 1/2" model S-3 Packer, X nipple and tubing. Drift packer and BHA. Drift tubing every 30 joints w/Halliburton. At joint #65 w/ the first 2 GLM's picked up. (2215') 4/28/2001 00:00 ~ 14:30 14.50 RUNCOItP COMP Continue to run 3 1/2" completion. Total 6 GLM's and at the SSSV. Jt # 317 of 363 total to run. Halliburton running drift every 30 joints. 14:30 ~ 15:30 1.00 RUNCOI~P COMP PJSM RU Camco and hook up control lines and test to 5000 ~si for 10 minutes. 15:30 ~ 20:00 4.50 RUNCO~ P COMP Continue to run 3 1/2" completion. Drift every 30 joints. Circulate to verify overshot swallowing tubing stump and tag up at 11,785.22'. PU 160k SO 140k. Used 55 bands to hold control lines. Prepare to space out. 20:00 ~ 22:00 2.00 RUNCOI~ SFAL COMP Falling object incident:Hung pump in sub on safety line of compensator. Pump in sub parted and fell to floor stricking roughneck on back. Shut down, call for ambulance and safety investigation. 22:00 - 23:00 1.00 RUNCOr~ COMP Safety meeting and PJSM for next operation. Discussed accident, what happened and talked about how it could have been done differently. All personnel in good mental state to restart operations. Printed: 5/24/2001 2:43:28 PM Legal Well Name: 3-15 Common Well Name: 3-15/K-33 Spud Date: 9/25/1987 Event Name: WORKOVER Start: 4/22/2001 End: Contractor Name: DOYON Rig Release: Rig Name: DOYON 15 Rig Number: · ~[e ~ 1 ~b ~60rs ~i~i~ ~Od~ N~ phase Description of Operations 4/28/2001 23:00 - 00:00 1.00 RUNCOkF) COMP Space out completion. Lay down 4 joints of tubing. Pick up space out joints. 4/29/2001 00:00 - 01:00 1.00 RUNCOr P COMP Space out completion. PU 3 pups. 2.22', 10.23' and 10.26'. PU jt #363. PU landing jt and tubing hanger. RD compensator. 01:00 - 02:00 1.00 RUNCO~/P COMP Make up control lines in hanger and test to 5000 psi 10 minutes each. 02:00 - 06:30 4.50 RUNCO~ COMP Reverse circulate in completion fluid. Inhibitor in 9.2 ppg filtered brine. 06:30 - 07:30 1.00 RUNCO~ COMP Circulate at 3 bpm 200 psi to varify overshot swallowing the stub. Land tubing hanger in wellhead. Screw in lock down screws and test seal. 07:30 - 09:00 1.50 RUNCOI~ COMP Change head pins on landing joint. Rig down Camco control line running equipment. RU Halliburton wireline. 09:00 - 15:00 6.00 RUNCOI~' COMP 1st wireline run: driftw/2.875 to 700'. 2nd run: retrieve SSSV dummy sleeve at 1524'. 3rd run: RIH w/2.625 drift to 12,000'. POOH. 4th run: RIH set XXN plug in XN nipple at 11,774'. POOH. 15:00 - 15:30 0.50 RUNCOItl:) COMP RU and test XXN plug to 500 psi f/10 minutes. 15:30 - 17:00 1.50 RUNCOItF' COMP RU Halliburton and first run failed to reset SSS¥ dummy. Second run sucessful to set at 1524'. 17:00 - 19:00 2.00 RUNCO~ F) COMP RU and pressure tubing to 2500 psi to set slips. Pressure to 3500 to set element. Surface pressure leak occured delaying to test Tubing. Repair leaks. 19:00 - 20:30 1.50 RUNCOI~ COMP Pressure to test tubing. Pressure leaking to another surface leak. Correct surface leak. Repressure to 3500 psi for 30 minutes. 20:30 - 21:00 0.50 RUNCOI~' COMP Install TWC and test to 1000 psi f/10 minutes. Lay down landing joint. 21:00 - 00:00 3.00 BOPSUF P COMP Nipple down BOPE. Change top rams to 4 1/2 x 7" varible. Coordinate with conrtol room for SIMOPS procedure. 4/30/2001 00:00 - 04:00 4.00 BOPSUF; 3 COMP Nipple down BOPE. Change rams in top to 4 1/2 x 7" varible. Set back BOP's after production finishes SlMOPS requirements for heavy lift over adjacent wells. 04:00 - 06:00 2.00 WHSUR 3 COMP Set adaptor flange and tree on well and nipple up. FMC tested well head. 06:00 - 07:30 1.50 WHSUR ~ P COMP Rig up Drill Site Maintenance and retrieve TWC. RD lubricator. 07:30 - 08:30 1.00 RUNCOr F' COMP Rig Up lines for testing annulus and freeze protection. 08:30 - 11:30 3.00 RUNCO~/P COMP Pressure test annulus to 2500 psi for 30 minutes. Tubing 2000 ~si. Bleed tubing pressure and shear RP valve. RU and freeze ~rotect annulus and tubing to 500'. 35 bbl diesel circulated into annulus. 11:30 - 13:30 2.00 RUNCOI~ COMP Let diesel U tube to tubing until static. 13:30 - 14:00 0.50 WHSUR 3 COMP FMC set BPV in profile. 14:00 - 15:00 1.00 WHSUR 3 COMP Secure tree and clean up SDI 3-15 well house 15:00 - 18:00 3.00 RIGD ~ COMP Prepare rig for rig move to MPI 2-06 workover. Release rig at 18:00 4-30-2001 Printed: 512412001 2:43:28 PM THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ,ON OR BEFORE OCTO.BER 24, 2000 P M L ATE R IA~L THIS MA Ill E E E W UNDER R K E R STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate Repair well O t h e r 2. Name of Operator 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 144' FNL, 94' FEL, SEC 11,T10N, R8E, UM At top of productive interval 1581' FSL, 1222' FEL, SEC 11, T10N, R8E, UM At effective depth 1380' FSL, 1288' FEL, SEC 11, T10N, R8E, UM At total depth 1362' FSL, 1294' FEL, SEC 11, T10N, R8E, UM 12. Present well condition summary Total Depth: measured 7915 feet true vertical 6545 feet Effective depth: measured 7802 feet true vertical 6 4 5 4 feet 6. Datum elevation (DF or KB) RKB 154 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-16 9. Permit number 89-94 10. APl number 50-1 03-201 15-00 11. Field/Pool Kuparuk River Field/Oil Pool measured 7534'-7547', true vertical 6240'-6251 ', Tubing (size, grade, and measured depth) 3-1/2", 9.3#. J-55 @ 7455' Packers and SSSV (type and measured depth) Plugs (measured) None Junk (measured) None Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 1 6" 170 SX ASII 1 1 5' 1 1 5' Surface 3200' 9-5/8" 1100 SX ASIII 3235' 2926' Intermediate 450 SX CLASS G Production 7 8 4 8' 7" 250 SX CLASS G 7 8 8 4' 6 51 9' Liner Perforation depth: ORIGINAL 7634'-7674' 6320'-6352' Packer: Baker HB @ 7375'; SSSV: Camco TRDP-1A-SSA @ 1803' 13. Stimulation or cement squeeze summary Fracture stimulate 'A' sand on 2/19/97. ~J .} I~ I ir~ll~lA!~ I!'1~t~'~' ]'~ L Intervals treated (measured) ' : 7634'-7674' !i.~_... ! ..... ~ ~i ~ Treatment description including volumes used and final pressure Pumped 260.6 Mlbs of 20/40, 12/18, and 10/14 ceramic proppant into form., fl:) = 7200 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 21 8 2 01 6 960 276 Subsequent to operation 6 9 3 3 3 1 182 983 277 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~~~~- ¢,o( '~'~'¢)i~ Title Wells Superintendent Form 10-4~z~ Date drl? :~' SUBMIT IN DUPLICATE · Alaska, Inc. KUPARUK RIVER UNIT ---- WELL SERVICE REPORT ~ K1(2K-16(W4-6)) WELL JOB SCOPE JOB NUMBER 2K-16 FRAC, FRAC SUPPORT 0215971416.2 DATE DAILY WORK UNIT NUMBER 02/19/97 A SAND REFRACTURE DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I i~ Yes ~,) NoI O Yes (~) No DS-GALLEGOS JORDAN FIELD AFC_,ff CC# DAILY COST ACCUM COST Signed ESTIMATE KD1609 230DS28KL $1 69,91 6 $169,916 Initial Tb.q Press Final Tbct Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 200 PSI 7200 PSI 1500 PSI 3450 PSII 500 PSII 850 PSI DAILY SUMMARY PUMPED A SAND REFRAC. 260633 LB PROPPANT IN FORMATION. 10912 LB PROPPANT IN TUBING. TIME 07:00 09:00 10:00 10:20 11:46 13:00 15:00 17:00 LOG ENTRY MIRU DOWELL FRAC UNIT. TGSM- 15 ON LOCATION. SET TREE SAVER AND TEST. PT TO 9700 PSI. SB TO REPAIR LEAK. PT SFC LINES TO 9100 PSI OK. PUMP BREAKDOWN PUMP DATAFRAC PUMP FRAC STAGES THROUGH 10 PPA IN FORMATION. BEGIN FLUSH. SCREENED OUT WITH 20 BBL FLUSH IN TUBING. 260633 LB PROPPANT IN FORMATION. 10912 LB PROPPANT LEFT IN TUBING. RD DOWELL. TREE CAP PRESS GAUGE MAXED OUT AT 1500 PSI. LEFT HEATER ON TREE AND NOTIFIED OPERATOR OF WELL CONDITION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $2,500.00 $2,500.00 DOWELL $164,616.00 $164,616.00 LITTLE RED $2,800.00 $2,800.00 TOTAL FIELD ESTIMATE $1 69,91 6.00 $1 69,91 6.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate Plugging Perforate X Repair well O t h e r 2. Name of Operator 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 144' FNL, 94' FEL, SEC 11,T10N, R8E, UM At top of productive interval 1581' FSL, 1222' FEL, SEC 11, T10N, R8E, UM At effective depth 1380' FSL, 1288' FEL, SEC 11, T10N, R8E, UM At total depth 1362' FSL, 1294' FEL, SEC 11, T10N, R8E, UM 12. Present well condition summary Total Depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 7915 true vertical 6 5 4 5 measured 7 8 0 2 true vertical 6 4 5 4 Length Size 80' 16" 3200' 9-5/8" 13. 14. feet feet feet feet 6. Datum elevation (DF or KB) RKB 154 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-16 9. Permit number 89-94 10. APl number 50-1 03-201 15-00 11. Field/Pool Kuparuk River Field/Oil Pool 7848' 7" Plugs (measured) None Junk (measured) None feet Cemented Measured depth True vertical depth 170 SX ASII 1 15' 1 15' 1100 SX ASIII 3235' 2926' 450 SX CLASS G 250 SX CLASS G 7 8 8 4' 6 51 9' measured 7534'-7547', 7602'-7610', 7634'-7674' true vertical 6240' - 6251', 6294'-6301', 6320'-6352' Tubing (size, grade, and measured depth) 3-1/2", 9.3#. J-55 @ 7455' Packers and SSSV (type and measured depth) Packer: Baker HB @ 7375'; SSSV: Camco TRDP-1A-SSA @ 1803' Stimulation or cement squeeze summary Perforate 'A' and 'C' sands on 4/25/97. i0RIGINAL Intervals treated (measured) 7534'-7546', 7602'-7610' ' ~ '~-' i ,.. Treatment description including Volumes used and final pressure Perforate using HSD DP guns @ 6 spf, phased 60°, fp = 560 psi. ORI61NAL Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 2 5 2 8 5 8 983 Tubing Pressure 259 Subsequent to operation 25 2 85 8 983 ' 259 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: X Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ ~0'~..,~./4~,¢I~ Title Wells Superintendent Form 10-4~4~ Re~/ SUBMIT IN DUPLICATE .RCO Alaska, Inc. KUPARUK RIVER UNIT A WELL SERVICE REPORT K1 (2K-1 6(W4-6)) WELL JOB SCOPE JOB NUMBER 2K-16 PERFORATE, PERF SUPPORT 0407970800.4 DATE DAILY WORK UNIT NUMBER 04/25/97 PERFORATE- 2 1/2" HSD, 6 SPF GUNS 8293 DAY OPERATION COMPLETE ] SUCCESSFUL KEY PERSON SUPERVISOR I (~) Yes O NoI (~) Yes (~ No SWS-JOHNSON BL_..A.CK~ ESTIMATE KAWWRK 230DS28KL $10,01 9 $11,029 . Initial Tbq Press Final Tbq Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 450 PSI 560 PSI 900 PSI 900 PSII 350 PSII 350 PSI DAILY SUMMARY I PERFORATED F/7534-7546' ELM & F/7602-7610' ELM W/2.5" HSD DP @ 6 SPF PHASED 60 DEG. PENT=17.3" & EH=.20". TIME 08:00 10:30 13:00 15:00 16:30 LOG ENTRY MIRU SWS UNIT 8293 (JOHNSON & CREW). MU TOOL STRING (2.5" HSD DP GUNS/WT/CCL) TL-20'. WO SURFACE TEST EQUIPMENT. PT BOPE TO 3000 PSI. RIH W/TOOL STRING TO 7610' ELM (CCL DEPTH). TIE IN TO 12/18/89 SWS CET. PERFORATE F/7602-7610' ELM W/ 2.5" HSD DP @ 6SPF & 60 DEG PHASED. POOH. AT SURFACE. ALL GUNS FIRED. MU TOOL STRING #2 (SAME AS BEFORE) TL-25'. PT. RIH W/TOOL STRING #2 & TIE IN. PERFORATE F/7534-7546' ELM W/SAME GUNS AS BEFORE. POOH AT SURFACE. ALL GUNS FIRED. RD. OFF LOCATION & TURN OVER TO PRODUCTION SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $147.00 APC $700.00 $700.00 HALLIBURTON $0.00 $423.00 LIq-FLE RED $0.00 $440.00 SCHLUMBERGER $9,319.00 $9,319.00 TOTAL FIELD ESTIMATE $10,019.00 $11,029.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate Plugging Repair well Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ~X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 144' FNL, 94' FEL, SEC 11,T10N, RSE, UM At top of productive interval 1581' FSL, 1222' FEL, SEC 11, T10N, RSE, UM At effective depth 1380' FSL, 1288' FEL, SEC; 11, T10N, RSE, UM At total depth 1362' FSL, 1294' FEL, SEC 11, T10N, R8E, UM Present well condition summary Total Depth: measured 7 91 5' feet true vertical 6545' feet Effective depth: measured 7802' feet true vertical 6 4 5 4' feet Casing Length Structural Conductor 8 0' Surface 3 2 0 0' Intermediate Production 7 8 4 8' Liner Perforation depth: measured 6. Datum elevation (DF or KB) 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2K-16 9. Permit number 89-94 10. APl number 50-103-20115 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Plugs (measured) Junk (measured) Size Cemented Measured depth True vertical depth 1 6" 170 SX AS II 9-5/8" 1100 SX ASIII 45O SX CLASS G 7" 250 SX CLASS G 115' 115' 3235' 2926' 7884' 6519' 13. 7634' - 7674', 7534' - 7547' true vertical 6320'- 6352', 6240'- 6251' Tubing (size, grade, and measured depth) 3-1/2", 9.3#. J-55 @ 7455' Packers and SSSV (type and measured depth) CAMCO TRDP-1A-SSA @ 1803', BAKER HB PKR @ 7375' Stimulation or cement squeeze summary Perforate C Sand @ 6 SPF 90 deg phasing Intervals treated (measured) 7534'- 7547' Treatment description including volumes used and final pressure RECEIVED SEP 1994 Alaska 0il & Gas Cons. Commission Anchor~e 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 348 299 0 800 psi 345 331 0 800psi Tubing Pressure 233 psi 198 psi 16. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~iog;emd 10-40~ Rev 06/158~8 Title Wells Superintendent Date 2~ O-~y SUBMIT IN DUPLICATE ARCO Alaska, inc. Subsidiary of Atlantic Richfield Company wELL DESCRIPTION OF WORK DATE CONTRACTOR'/KEY PERSON DAY PBTD (RI(S) ILAST TA, G (RKB)- DATE LOG ENTRY F TP- ~? C l) # KUPARUK RIVER UNIT WELL SERVICE REPORT , [FIELD COST EST. IACCUMULATED COST ]SSSV TYPE / STATUS ~ "- E~C ~ q ~ "- 'zoo e/o jT~T~ cxJ £930 /~. d. t~EPRI/~,,e COmPZ£T£b, .... 1~5'5 , I v]C~CK xms BLOCK IF SUMMARY IS CONTllNRJED ON BACK Weather Report m ~ ^nch0r~ ITemp. Chm. Factor COMPLETE INCOMPLETE Visibility l Wind Vel. I Signed I.I i i ii STATE OF ALASKA ...... ! ~:''! ~ ALasKA OIL AND GAS CONSERVATION CO~v,,vllSSlON ~i ~: WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED ~ ABANDONED r"! SERVICE r-"l 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 89-94/9-1092 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20115 4 Location of well at surface~"~'IP'~'~'"-*'~--- I 9 Unit or Lease Name 144' FNL, 94' EEL, SEC 11, T10N, R8E ua t I ~ ~ATE ; ~ pii~iii'' ''Y- :;':I:~!: KUPARUK RIVER At Top Producing IntervalJ '-~-' ..~ ~~ ~. ~;.~ii ~! 10 Well Number At Total Depth ~ ~ ~ ~ ~ .......... .... ~ 11 Field and Pool 1362' FSL, 1294' FEL, SEC 11, 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. I 15 Water Depth, if offshore 116 No. of Completions 10/15/89. 10/22/89. 6/4/90.I NA feet MSLI 1 17 Total Depth (MD+'rVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 7915' MD & 6545' TVD 7802' MD & 6454' TVD YES ~'1 NO ~ 1803' feet MD 1400' APPROX 22 Type Electric or Other Logs Run DIL/SFL/GR/SP/FDC/CNL/CAL/CBL/GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP DO'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 170 SX AS II 95/8" 36# J-55 SURF 3235' 12-1/4" 1100 SX AS III, 450 SX CLASS G 7" 26# J-55 SURF 7884' 8-1/2" 250 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 7455' 7375' 7634' - 7674' W/4-1/2" @ 4 SPF MD 6320' - 6352' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED SEE A'I-I'ACHED ADDENDUM 27 PRODUCTION TEST Date First Production IMethod 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 ,,~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ,~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. 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 7532' 6239' NA KUPARUK C BOTTOM 7547' 6251' KUPARUK A TOP 7586' 6282' KUPARUK A BOTTOM 7754' 6416' · · 31. LIST OF ATTACHMENTS GYRO, FRAC 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed __~,_~/__.__/~~'1~ Title AR EADRILLINGENGINEER Date-~//'~/~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Well History - Initial Report- Daily Instructlone: Prepare and submit the "lnillal RII~' on the first Wednesday after a well is spudded or workover operations are started. Daily work prtor to apuddlng should be summarized on the form giving Inclusive dates only. District ARCO AT.~SY,~ [NC. Field ICounty, parish or borough NORTH SLOPE Lease or Unit Title Z~DT': 25588 COMPLETIONS IState AK KUPARUK RIVER ~NIT Auth. or W,O. no. AK3714 ALK.' 2674 IWell no. Operator ~M~CO Spudded or W.O. begun Date and depth as of 8:00 a.m. 04/21/90 (10) TD: 7915 PB: 7802 SUPV:DB IDate JHour 10/15/89 00:00 Complete record for each day reporled NORDIC #1 IARCO W.I. 55.8533 Prior status if a W.O. RIH W/ 3-1/2" COMPLETION 7"@ 7883' MW:10.3 NaC1 MOVE RIG FROM 2K-15, ACCEPT RIG AT 1430 4/20/90, ND DRYHOLE TREE, NU BOPE AND TEST TO 3000 PSI, EU HLS E-LINE, RIH W/ GUN 91, PERF 7654-7674, POH, ASF, RIH W/ GUN %2, PERF 7634-7654, POH, ASF, RU & RIH W/ 3-1/2" SINGLE COMPLETION ASSEMBLY DAILY:S52,963 CUM:$934,576 ETD:S934,576 EFC:$1,308,000 The above is c,e'rl~ect For form preparation/~n~l d-istrib~tion, ~ see Procedures Man~f', Section 10, Drilling, Pages 86 and 87. Date AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well, iPage no. ARCO (., and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after arlowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty 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, ITitle AK3714 J COMPLETIONS IAccounting cost center code State AK IWell no, 2~(-16 Operator A.R.Co. W.I. ARCO Date55, 8533 Spudded or W.O. begun SPUD 10/15/89 Date and depth as of 8:00 a.m. 04/22/90 (11) TD: 7915 PB: 7802 SUPV:DB Complete record for each day reported NORDIC #1 Iotal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prlor status if a W.O. I 00.' O0 RIG RELEASED 7"@ 7883' MW:10.3 NaCl CONT. RIH W/ COMPLETION, ATTACH CONTROL LINE AND TEST, CONT. RIH W/ COMPL., MU TBG HGR, TEST CONTROL LINE, LAND TBG, RILDS, DROP BALL, PRESS TBG TO 2500 PSI TO SET PKR, PRESS ANNULUS TO 1000 PSI, BLEED ANNULUS PRESS, BLEED TBG TO 1700 PSI, PU AND SHEAR PBR, RELAND TBG, RILDS, PRESS ANNULUS/TBG TO 1000 PSI, TEST SSSV, BLEED PRESS, ND BOPE, NU TREE AND TEST TO 5000 PSI, TEST ANNULUS TO 2500 PSI, REVERSE CIRC. 6 BBLS DIESEL INTO ANNULUS, BULLHEAD 2 BBL DIESEL DOWN TBG, RELEASE RIG AT 1330 4/21/90 DAILY:S145,917 CUM:$1,080,493 ETD:$1~080,493 EFC:$1,308,000 Old TD I New TD PB Depth I Released rig I Date Kind of rig I Classifications (oil. gas, etc.) Type completion (single, dual, etc.) Producing method Off cial 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, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective dale corrected The above is c,~ct For form preparation an~d)str~bution, ~ / J see Procedures Manual, ~'Ection 10, Drilling1 Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecuttve{y as they are prepared for each well. iPage no. Olvt~lon of AllsntlcRIchfleldCompany ADDENDUM WELL 2K-16 5122/90 Frac Kuparuk "A" sand perfs 7634'-7674' 180 deg oriented 12 deg ccw in nine stages as follows. Stage 1: Stage 2: Stage 3: Stage 4: Stage 5: Stage 6: Stage 7: Stage 8: Stage 9: Pmp 200 bbls YF240 Gel water prepad @ 25 bpm 5450-4550 psi 60 bbls YF240 Gel water prepad @ 20bpm 4010-4230 psi 45 bbls YF240 Gel water prepad @ 15 bpm 37904020 psi 30 bb]s YF240 Ge] water prepad @ 10 bpm 35104070 psi 72 bbls slick diese! flush @ 25-23 bbm 4660-3840 psi 1300 bbls YF240 GW pad @ 25 bpm 4380-4150 psi 101 bbls YF240 w/2 ppg 16/20 Carbolite @ 25 bpm 4150-3990 psi 102 bbls YF240w/4 ppg 16/20 Carbolite @ 25 bpm 3990-3920 psi 111 bbls YF240 w/6 ppg 16/20 Carbolite @ 25 bpm 3920-3850 psi 118 bbls YF240 w/8 ppg 16/20 Carbolite @ 25 bpm 3850-4090 psi 54 bb]s YF240 w/9 ppg 16/20 Carbolite @ 25 bpm 4090-7400 psi i bbls Slick Diesel flush @ 7400-8200 psi Fluid to recover: 2193 bbls Sand in zone: 95,848 lbs Sand in csg: 19,873 lbs Avg pressure: 4150 psi ~pervisor ..... I I I I I ! I I II III SUB. SURFACE DIRECTIONAl. SURVEY F'~UIDANCE r o. ,.uou MICROFILMED C~OOL oa~__ I O/,;,"/..c~ - Company ARC,O ,,ALAS,KA, INC. Well N~me ,2.K-.1.6 (144' FNL,,94' FleldlLocation KUPARUK NORTH II FE..L, SEC · II I i i ! ii 11,TlON,.R8E,,,UM) Job Reference NO_. 73630 Logaed COX SLOPE ALASKA KOHRING * SCHLUMeERGER , GCT DIRECTIONAL SURVEY CUSTOMER LISTING FgR ARCO ALASKA, INC. 2K-16 KUPARUK NORTH SLOPE, ALASKA SURVEY DATE: !8-DEC-1989 ENGINEER: COX METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH [g DEG 16 MIN WEST COMPUTATION DATE: 5-JAN-g0 PAGE I ARCO ALASKA, INC. 2K-16 KUPARUK NORTH SLOPE, ALASKA DATE DF SURVEY: 18-DEC-198'9 KELLY BUSHING ELEVATION: 154.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN ENGINEER: COX 0.00 0.00 -154.00 0 0 N 0 0 E 100.00 100.00 -54.00 0 5 S 13 57 W 200.00 200.00 46.00 0 5 S 29 28 E 300.00 300.00 146.00 0 6 S 29 28 E 400.00 400.01 246.01 0 9 S 45 51 E 500.00 500.00 346.00 0 12 S 70 20 E 600.00 600.00 446.00 0 12 S 71 g E 'TOO.D0 699.99 545.99 0 47 S 33 8 W 800.00 799.98 645.98 1 10 S 41 38 W go0.o0 899.95 745.95 I 30 S 39 45 W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET ~EET FEET DEG MIN 1000.00 999.90 845.90 2 26 1100.00 1099.79 945.79 3 7 1200.00 1199.43 1045.43 6 19 1300.00 1298.64 1144.64 8 0 1400.00 1397.14 1243.14 12 23 1500.00 1494.10 1340.10 15 27 1600.00 1590.14 1436.14 16 20 1700.00 1686.04 1532.04 17 34 1800.00 1780.12 1626.12 21 28 1900.00 1872.64 1718.64 23 33 0.00 0.00 0.00 N 0.00 E 0.03 0.00 0.03 S 0.01 W 0.13 0.00 0.15 S 0.03 E 0.24 0.00 0.29 S O.lO E 0.35 0.00 0.46 S 0.23 E '0.42 0.00 0.61 S 0.48 E 0.41 0.00 0.72 S 0.82 E 0.84 1.31 1.17 S 0.80 E 2.53 0.3~ 2.55 S 0.36 W 4.74 0.19 4.35 S 1.92 W 2000.00 1963.20 1809.20 25 53 2100.00 2052.62 1898.62 28 3 2200.00 2139.58 1985.58 30 15 2300.00 2225.39 2071.39 32 25 2400.00 2307.40 2153.40 36 45 2500.00 2385.79 2231.79 40 37 2600.00 2459.13 2305.18 44 6 2700.00 2530.86 2376.86 44 10 2800.00 2602.9B 2448.98 43 29 2900.00 2675.96 2521.96 42 48 S 38 49 W 7.94 S 35 28 W 12.51 S 32 I W 20.36 S 32 22 W 32.52 S 33 46 W 49.14 S 33 25 W 72.77 S 32 30 W 99.75 S 33 10 W 127.57 S 31 55 W 160.35 S 29 47 W 197.57 S 25 20 W 23'9.42 S 25 0 W ZB4.00 S 25 15 W 332.93 S 22 9 W 384.27 S 18 15 W 441.24 S 18 2~. W 503.40 S 18 21 W 571.27 S 18 41 W 640.94 S 19 0 W 710.23 S 19 14 W 778.58 3000.00 2749.66 2595.66 42 19 3100.00 2824.09 2670.09 41 32 3200.00 2899.23 2745.23 40 59 3300.00 2974.90 2820.90 40 52 3400.00 3050.10 2896.10 41 39 3500.00 3124.35 2970.35 42 29 3600.00 3197.94 3043.94 42 41 3700.00 3271.46 3117.46 42 31 3800.00 3345.43 3191.43 42 5 3900.00 3419.75 3265.75 41 50 S 19 20 w 846.27 S 19 29 w 912.97 S 19 55 W 978.96 S 19 46 w 1044.29 S 19 26 w 1110.23 S 19 8 W 1177.27 S 18 25 W 1245.01 S 17 44 W 1312.72 S 16 39 W 1379.96 S 16 1 W 1446.75 0.73 6.98 S 1.34 10.83 S 2.17 17.56 S 1.99 28.14 S 5.26 42.48 S 2.32 62.76 S 0.52 86.10 S 3.91 110.13 S 1.71 4.23 0.46 4.41 0.43 5.69 2.28 5.33 0.62 0.4~3 0.91 0 -66 0.91 0.53 0.72 0.71 0.88 0.77 0.41 0.77 0.79 0.54 0.00 N 0 0 E 0.03 S 14 23 w 0.16 S 10 55 E 0.31 S 19 21 E 0.51 S 26 55 E 0.78 S 38 24 E 1.09 S 48 39 E 1.42 S 34 28 E 2.58 S 8 8 W 4.76 S 23 46 W 4.08 W 8.09 S 30 17 W 6.95 W 12.86 S 32 42 W 11.45 W 20.96 S 33 6 W 18.04 W 33.43 S 32 39 W 27.41 W 50.55 S 32 50 W 40.98 W 74.96 S 33 9 W 55.98 W 102.70 S 33 2 W 71.55 W 131.33 S 33 1 W 138.52 S 89.66 W 165.01 S 32 55 W 171.07 S 109.35 W 203.03 S 32 35 W 208.67 S 128.58 W 245.11 S 31 38 W 249.25 S 147.62 W 289.69 S 30 38 W 293.78 S 168.50 W 338.67 S 29 50 W 340.80 S 189.59 W 389.98 S 29 5 W 394.43 S 208.82 W 446.29 S 27 54 W 453.47 S 228.28 W 507.69 S 26 43 W 517.89 S 249.67 W 574.93 S 25 44 W 583.97 S 271.76 W 644.11 S 24 57 W 649.54 S 294.14 W 713.04 S 24 22 W 714.14 S 316.51 W 781.13 S 23 54 W 778.03 S 338.86 W 848.62 S 23 32 W 840.95 S 360.98 W 915.15 S 23 14 W 903.08 S 383.24 W 991.04 S 23 0 W 964.51 S 405.46 W 1046.27 S 22 48 W 1026.64 S 427.56 W 1112.12 S 22 37 W 1089.93 S 449.67 W 1179.05 S 22 25 W 1154.06 S 471.53 W 1246.67 S 22 13 W 1218.44 S 492.52 W 1314.22 S 22 1 W 1282.71 S 512.42 W 1381.28 S 21 47 W 1346.91 S 531.19 W 1447.87 S 21 31 W 'COMPUTATION DATE: S-JAN-gO PAGE 2 ARCO ALASKA, INC. DATE DF SURVEY: 18-DEC-19)9 2K-16 KELLY BUSHING ELEVATION: 154.00 FT. KUPARUK NORTH SLOPE, ALASKA ENGINEER: COX INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN 4000.00 3494.44 3340.44 41 34 4100.00 3569.40 3415.40 41 20 4200.00 ~3644.64 3490.64 41 4 4300.00 3720.19 3566.19 40 52 4400.00 3795.95 3641.95 40 36 4500.00 3872.19 3718.19 40 4 4600.00 3949.02 3795.02 39 26 4700.00 4026.67 3872.67 38 48 4800.00 4104.85 3950.85 38 18 4900.00 4183.62 4029.62 37 45 5000.00 4263.15 4109.15 37 9 5100.00 4342.44 4188.44 37 38 5200.00 4421.75 4267.75 37 41 5300.00 4500.29 4346.29 38 37 5400.00 4578.66 4424.66 38 18 5500.00 4656.33 4502.33 39 42 .5600.00 4733.31 4579.31 39 33 5700.00 4810.71 4656.71 38 58 5800.00 4888.70 4734.70 38 36 5900.00 4967.01 4813.01 38 18 6000.00 5045.23 4891.23 39 9 6100.00 5121.75 4967.75 40 40 6200.00 5197.69 5043.68 40 20 6300.00 5274.38 5120.38 39 37 6400.00 5351.52 5197.52 39 22 6500.00 5429.01 5275.01 39 2 6600.00 5506.86 5352.86 38 53 6700.00 5584.32 5430.32 39 lB 6800.00 5661.93 5507.93 38 50 6900.00 5740.36 5586.36 37 50 7000.00 5819.67 5665.67 37 39 7100.00 5898.31 5744.31 38 41 7200.00 5976.57 5822.57 38 11 7300.00 6055.22 5901.22 38 2 7400.00 6134.12 5980.12 37 49 7500.00 6213.34 6059.34 37 29 7600.00 6292.85 6138.85 37 8 7700.00 6372.81 6218.81 36 50 7800.00 6452.85 6298.85 36 50 7900.00 6532.90 6378.90 36 50 BEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN S 15 10 W 1513.14 S 14 25 W 1579.15 S 13 41 W 1644.73 S 14 57 W 1710.00 S 15 4 W 1775.08 S 14 26 W 1839.61 S 13 43 W 1903.31 S 12 47 W 1965.97 S 12 6 W 2027.82 S 11 47 W 2088.99 S 15 48 W 2149.24 S 17 33 W 2210.13 S 17 17 W 2270.98 S 17 8 W 2332.89 S 16 36 W 2394.91 S 16 45 W 2457.83 S 16 20 W 2521.64 S 15 53 W 2584.84 S 15 21 W 2647.30 S 14 34 W 2709.28 S 1,+ 15 W 2771.33 S 15 1Z W 2835.49 S 14 15 W 2900.37 S 13 26 W 2964.31 S 12 38 W 3027.53 S 12 8 W 3090.30 S 12 9 W 3152.57 S 13 23 W 3215.38 S 12 46 W 3278.08 S 13 6 W 3339.69 S 17 18 W 3400.46 S 19 8 W 3462.21 S 18 21 W 3524.46 S 19 2 W 3586.20 S 18 49 W 3647.63 S 18 41 W 3708.66 S 18 16 W 3769.30 S 18 0 W 3829.48 S 18 0 W 3889.41 S 18 0 W 3949.34 0.55 0.58 0.42 1.26 0.48 0.65 1.06 0.64 0.56 1.OD 3.73 0.46 1.17 0.46 I .14 0.78 0.52 0.74 0.32 0.61 2.42 0.60 1.26 0.59 0.38 0.52 1.50 O.S1 0.94 2.41 I .96 0.81 0.64 0.64 0.15 0.23 0.37 0.00 0.00 0.00 1411.00 S 549.05 W 1514.06 $ 21 16 W 1475.01 S 565.95 W 1579.86 S 20 59 W 1538.91 S 581.89 W 1645.25 $ 20 43 W 1602.48 S 597.84 bi 1710.37 S 20 28 bi 1665.46 S 614.89 W 1775.34 S 20 16 W 1728.06 S 631.37 W 1839.79 S 20 4 W 1790.10 S 646.94 W 1903.41 S 19 52 W 1851.44 S 661.36 W 1966.01 S 19 39 W 1912.28 S 674.76 W 2027.83 S 19 26 W 1972.64 S 687.43 bi 2088.99 S 19 13 W 2031.61 S 701.34 W 2149.26 S 19 3 W 2089.83 S 719.30 W 2210.16 S 19 0 W 2147.94 S 737.48 W 2271.02 S 18 57 W 2207.10 S 755.84 W 2332.93 S 18 54 W 2266.50 S 773.85 W 2394.97 S 18 51 W 2326.86 S 791.87 W 2457.91 S 18 48 W 2388.10 S 810.06 W 2521.75 S 18 4~ W 2448.92 S 827.60 W 2584.98 S 18 40 W 2509.20 S 844.45 W 2647.4~ S 18 36 W 2569.23 S 860.53 W 2709.51 S 18 31 W 2629.59 S 875.90 W 2771.63 S 18 25 W 2691.82 S 8'92.29 W 2835.86 S 18 ZO W 2754.71 S 909.01 W 2900.82 S 18 16 W' 2817.10 S 924.29 W 2964.86 S 18 10 W 2879.07 S 938.62 W 3028.21 S 18 3 W 2940.83 S 952.16 W 3091.13 S 17 56 W 3002.26 S 965.16 W 3153.58 S 17 49 W 3063.81 S 979.41 W 3216.54 S 17 44 W 3125.23 S 993.69 W 3279.41 S 17 38 W 3185.77 S 1007.24 W 3341.20 S 17 33 W 3244.53 S 1023.30 W 3402.08 S 17 30 W 3303.15 S 1042.72 W 3463.82 S 17 31 W 3362.09 S 1062.78 W 3526.07 S 1T 33 W 3420.57 S 1082.59 W 3587.79 S 17 34 W 3478.71 S 1102.43 W 3649.21 S 17 35 W 3536.49 S 1122.09 W 3710.23 S 17 36 W 3594.01 S 1141.30 W 3770.87 S 17 37 W 3651.20 S 1160.05 W 3831.06 S 17 38 W 3708.22 S 1178.56 W 3891.00 S 17 38 W 3765.23 S 1197.07 W 3950.94 S 17 38 W COMPUTATION DATE: 5-JAN-g0 PAGE 3 ARCO ALASKA, INC. ZK-16 KUPARUK NORTH SLOPEr ALASKA DATE OF SURVEY: 18-DEC-1989 KELLY BUSHING ELEVATION: 15~.00 FT ENGINEER: COX INTERPOLATED VALUES FDR EVEN 100 FEET OF MEASURED DEP'TH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST OIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 7915.00 6544.90 6390.90 36 50 S 18 0 W 3958.33 0.00 3773.79 $ 1199.84 W 3959.93 S 17 38 W COMPUTATION DATE: 5-JAN-g0 PAGE 4 ARCO ALASKA, INC. 2K-16 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 18-DEC-1989 KELLY BUSHING ELEVATION: 154.00 FT ENGINEER: COX INTERPOLATED VALUES FOR EVEN 1090 FEET OF MEASURED DEPTH TRUE SUB-S~A COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEO MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -154.00 0 0 1000.00 999.90 845.90 2 26 2000.00 1963.20 1809.20 25 53 3000.00 17&9.66 2595.66 42 19 4000.00 3494.44 3340.44 41 34 5000.00 4263.15 4109.15 37 9 6000.00 5045.23 4891.23 39 9 7000.00 5819.67 5665.67 37 39 7915.00 6544.90 6390.90 36 50 N 0 0 E 0.0.0 S 38 4'9 W 7.94 S 25 20 W 239.42 S 19 20 W ,846.2..7 S 15 10 W 1513.14 S 15 49 W 2149.24 S 14 15 W 2771.33 S 17 18 W 3400.46 S 18 0 W 3958.33 0.0 0 0.73 0.46 0.91 0 3.73 2.42 1.96 0.00 0.00 N 0.00 E 0.00 N 0 0 E 6.98 S 4.08 W 8.09 S 30 17 W 208.67 S 128.58 W 245.11 S 31 38 W 778.03 S 338.86 W 8.48.62 S 23 32 W 1411.00 S 549.05 W 1514.06 S 21 16 W '~ 2031.61 S 701.34 W 2149.26 S 19 3 W 2629.59 S 875.90 W 2771.63 S 18 25 W 3244.53 S 1023.30 W 3402.08 S 1'7 30 W 3773.79 S 1199.84 W 3959.93 S 17 38 W COMPUTATION DATE:' 5-JAN-90 PAGE 5 ARCO ALASKA, INC. ZK-16 KUPARUK NORTH SLOPE, ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN DATE OF SURVEY: 18-DEC-1989 KELLY BUSHING ELEVATION: 154.00 FT ENGINEER: COX INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET , 0.00 0.00 0.00 N 0.00 E 0.09 0.01 0.10 S 0.00 W 0.19 0.00 0.23 S 0.07 E 0.31 0.00 0.38 S 0.16 E 0.¢0 0.00 0.55 S 0.35 E 0.41 0.00 0.67 S 0.66 E 0.45 1.14 0.81 S 0.96 E 1.70 0.00 1.88 S 0.213 E 3.66 0.19 3.47 S 1.17 W 6.26 1.03 5.60 S 2.95 W 0.00 0.00 -154.00 0 0 N 0 0 E 154.00 154.00 0.00 0 5 S 27 33 E 254.00 254.00 100.00 0 6 S 25 57 E '354.00 354.00 200.00 0 7 S 38 19' E 454.00 454.00 300.00 0 11 S 57 37 E 554.00 554.00 400.00 0 12 S 72 g E 654.00 654.00 500.00 0 16 S 13 25 E 754.01 754.00 600.00 I 4 S 40 56 W 854.04 854.00 700.00 I 23 S 40 35 W 954.08 954.00 800.00 2 O S 39 32 W S 36 24 W S 34 B W S 31 43 W S 33 20 W S 33 57 W S 32 2'7 W S 33 11W S 32 14 W S 30 36 W S 25 33 W 10.27 0.58 8.93 S 16.01 4.15 13.81 S 26.72 1.29 23.11 S 40.87 5.29 35.36 S 62.43 2.81 53.87 S 89.43 0.56 77.16 S 118.03 1.78 101.90 S 150.55 3.42 130.01 S 189.77 3.22 235.01 0.99 1054.15 1054.00 900.00 2 47 1154.34 1154.00 1000.00 4 48 1254.96 1254.00 1100.00 7 12 1356.00 1354.00 1200.00 10 0 1458.55 1454.00 1300.00 14 23 1562.33 15 54.00 1400.00 16 22 1666.58 1654.00 1500.00 16 3'7 1772.03 1754.00 1600.00 20 44 1879.74 1854.00 1700.00 22 57 1989.79 1954.00 1800.00 25 48 S Z5 0 W 284.75 S 25 7 w 341.32 S ZO 14 W 403.08 S 18 14 w 477.11 S 18 21 W 566.26 S 18 4B W 663.34 S 19 10 W 758.18 S 19 21 W 850.21 S 19 41 W 939.40 S 19 51 W 1026.26 2101.57 2054.00 1900.00 28 6 2216.64 2154.00 2000.00 30 22 2334.26 2254.00 2100.00 34 9 2458.75 2354.00 2200.00 38 35 2592.78 2454.00 2300.00 4~ 3 2732.18 2554.00 2400.00 44 0 2870.02 2654.00 2500.00 42 59 3005.88 2754.00 2600.00 42 16 3139.90 2854.00 2700.00 41 20 3272.37 2954.00 2800.00 40 44 S 19 26 W 1113.69 S 18 56 W 1204.49 S 17 53 W 1296.67 S 16 33 W 1387.69 S 15 39 W 1477.29 S 14 34 W 1565.64 S 13 38 W 1652.84 S 15 17 W 1739.10 S 14 35 W 1824.33 S 13 39 W 1907.38 3405.22 3054.00 2900.00 41 42 3540.35 3154.00 3000.00 42 40 3676.30 3254.00 3100.00 42 37 3811.55 3354.00 3200.00 42 5 3945.92 3454.00 3300.00 41 42 4079.50 3554.00 3400.00 41 23 4212.39 3654.00 3500.00 41 1 4344.72 3754.00 3600.00 40 44 4476.21 3854.00 3700.00 40 4606.45 3954.00 3800.00 39 22 FEET DES MIN 0.00 N 0 0 E 0.10 S 2 18 W 0.24 S 16 58 E 0.41 S 23 2 E · 0.65 S 32 23 E ) 0.94 S 44 46 E ,' 1.25 S 49 46 E 1.89 S 6 49 E 3.66 S 18 39 W 6.33 S 27 46 W 4.36 0.83 6.09 4.55 0.83 0.73 0.58 0.98 0.58 0.48 0.90 0.51 0.52 0.63 0.81 0.58 0.42 0.57 0.72 1.11 5.58 W 10.53 S 32 0 W 9.02 W 16.49 S 33 10 W 14.89 W 27.49 S 32 47 W 22.69 W 42.02 S 32 41 W 35.06 W 64.28 S 33 3 W 50.28 W 92.10 S 33 5 W 66.16 W 121.50 S 33 0 W 84.32 W 154.96 S 32 58 W 164.21 S 105.33 W 1'95.09 S 32 41 W 204.68 S 126.66 W 240.70 S 31 45 W 249.93 S 147.94 W 290.43 S 30 37 W 301.42 S 172.07 W' 347.08 S 29 43 W 358.36 S 196.37 W 408..63 S 28 43 W 428.51 S 220.02 W 481.69 S 27 11 W 513.13 S 248.10 W 569.96 S 25 ~.8 W ~ 605.19 S 278.95 W 666.39 S 24 45 W . 694.87 S 309.81 W 760.80 S 24 Z W 781.75 S 34.0.17 W 852.55 S 23 31 W 865.86 S 369.84 W 941.53 S 23 8 W 947.56 S 399.34 W 1028.27 S 22 51 W 1029.91 S 428.71 W 1115.57 S 22 36 W 1115.66 S 458.56 W 1206.22 S 22 21 W 1203.16 S 487.61 W 1298.21 S 22 4 W 1290.14 S 514.62 W 1388.99 S 21 45 W 1376.35 S 539.52 W 1478.32 S 21 24 W 1461.89 S 562.57 W 1566.40 S 21 3 W 1546.83 S 583.82 W 1653.34 S 20 41 W 1630.64 S 605.46 W 1739.42 S 20 22 W 1713.22 S 627.53 W 1824.53 S 20 7 W 1794.07 S 647.90 W 1907.48 S 19 51 W COMPUTATI3N D~TE: 5-JAN-90 PA G E 6 ARCO ALASKA, INC. 2K-16 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 18-DEC-19~9 KELLY BUSHING ELEVATION: 154.00 FT ENGINEEr: COX INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DISTo AZIMUTH FEET DEG/ZO0 ~EET FEET FEET DEG MIN 4735.04 .¢054.00 3900.00 38 39 4862.48 4154.00 4000.00 38 1 4988.53 4254.00 4100.00 37 8 5114.60 4354.00 4200.00 37 34 5240.89 4454.00 4300.00 38 14 5368.61 ¢554.00 4400.00 38 17 5496.98 4654.00 4500.00 39 41 5626.82 4754.00 4600.00 39 26 5755.57 4854.00 4700.00 38 41 5883.42 4954.00 4800.00 38 20 S 12 31 W 1987.75 S 11 46 W 2066.13 S 15 6 W 2142.35 S 17 30 W 221'9.05 S 17 18 W 2296.11 S 16 47 W 2375.48 S 16 45 W 2455.90 S 16 11 W 2538.68 S 15 36 W 2619.58 S 14 43 W 2699.03 0.79 0.65 3.83 0.58 1.45 0.59 0.83 0.61 0.50 0.74 1872.83 S 666.16 W 1987.78 S 19 35 W 1950.07 S 682.73 W 2066.13 S 19 18 W 2024.93 S 699.56 W 21,42.36 S 19 4 W Z098.35 S 721.98 W 2219.08 S 18 59 W S 744.95 W 2296.15 S 18 56 W ) 2171.95 2247.87 S 768.28 W 2375.54 S 18 52 W 2325.01 S 791.31 W 2455.98 S 18 48 W 2~04.48 S 81~.8~ W 2538.80 S 18 43 W 2492.42 S 837.0~ W 2619.75 S 18 38 W 2559.28 S 857.93 W 2699.26 S 18 32 W 6011.34 5054.00 4900.00 39 25 S 14 20 W 2778.~+6 6142.51 5154.00 5000.00 40 43 S 15 3 W 2863.14 6273.52 5254.00 5100.00 39 44 S 13 37 W 2947.46 6403.21 5354.00 5200.00 39 21 S 12 37 W 3029.55 6532.12 5454.00 5300.00 38 56 S 11 55 W 3113.31 6660.80 5554.00 5400.00 39 19 S 13 24 W 3190.65 6789.81 5654.00 5500.00 38 55 . S 12 51 W 3271.72 6917.25 5754.00 5600.00 37 37 S 13 47 W 3350.19 7043.43 5854.00 5700.00 38 3 S 18 1'7 W 3427.07 7171.25 5954.00 5800.00 38 23 S 18 36 W 3505.66 2.6I 0.72 0.82 0.36 0.58 0.9'7 0 · 82 3.07 1.52 1.25 2636.53 S 877.66 W 2778.78 S 18 25 W 2718.59 S 899.54 W 2863.55 S 18 19 W 2800.65 S 920.33 W 2947.99 S 18 11 W 2881.05 S 939.07 W 3030.23 S 18 3 W 2960.56 S 956.37 W 3111.20 S 17 54 W 3039.62 S 973.66 W 3191.76 S 17 46 W 3119.00 S 992.27 W 3273.04 S 17 39 W 3196.03 S 1009.69 W 3351.73 S 17 32 W 3269.88 S 1031.41 W 3428.70 S 17 30 W 3345.20 S 1057.14 W 3508.26 S 17 32 W 7298.45 6054.00 5900.00 38 Z 7425.14 6154.00 6000.00 37 42 7551.21 6254.00 6100.00 37 21 7676.53 B-3-S'a-:-~O 6200. O0 36 41 7801.43 6454.00 6300.00 36 50 7915.00 6544.90 6390.90 36 50 S 19 2 W 3585.24 S 18 50 W 3663.05 S 18 29 W 3739.80 S 18 I W 3815.29 S 18 0 W 3890.27 S 18 0 W 3958.33 0.65 0.66 0.53 1.19 0.00 0.00 3419.66 S 1082.28 W 3586.84 S 17 34 W 3493.30 S 1107.40 W 3664.62 S 17 35 W 3566.01 S 1132.00 W 3741.37 S 17 37 W 3637.72 $ 1155.6Z W 3816.86 S 17 37 W 3709.03 $ 1178.82 W 3891.86 S 17 38 W 3773.79 S 1199.84 W 3959.93 S 17 38 W ARCO ALASKAt INC. 2K-16 KUPARUK NORTH SLOPE, ALASKA H~RKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A GCT LAST READING BASE KUPARUK A PBTO T" CASING TO COMPUTATION DATE: 5-JAN-90 PAGE 7 DATE OF SURVE'Y: 18-DEC-19~9 KELLY BUSHING ELEVATION: 154.00 ENGINEER: COX INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFA, CE LOCATION : 144" FNL & 94' FELt SECll TION RBE MEASUREO DE~TH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3235.00 7532.00 7547.00 7586.00 7692.15 7754.00 7802 o00 7883.00 7915.00 2925.68 2771.68 6238.75 6084.75 6250.66 6096.66 6281.67 6127.67 6366.53 6212.53 6416.04 6262.04 6454.46 6300.46 6519.29 6365.29 6544.90 6390.90 924.60 S 3554.94 S 3563.59 S 3585.96 S 3646.73 S 3681.99 S 3709.36 S 3755.54 S 3773.79 S 391.03 W 1128.30 W 1131.20 W 1138.64 W 1158.59 W 1170.04 W 1178.93 W 1193.92 W 1199.84 W COMPUTATION DATE: 5-JAN-90 PAGE 8 ARCO ALASKA, INC. 2K-16 KUPARUK NORTH SLOPE, ALASKA Da'T.E DF SURVEY: 18-0EC-198.9 KELLY ~USHING ELEVATION: 15¢o00 FT ENGINEER: COX ~0~0000~ STR.~T'IGRAPHIC SUMMARY SURFACE LOCATION = 144~ FNL & 94' FEL, SEC11 TION R8E MARKER MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD 7532.00 7547.00 7586.00 7754.00 7802.00 7915.00 6238.75 6084°75 6250.66 6096.66 6281.67 6127.67 6416.04 6262.04 6454.46 6300.46 6544.90~ 6390.90 3554.94 S 3563.59 S 3585.96 S 3681.99 S 3709.36 S 3773.79 S 1128.30 W 1131.20 W 1138.$4 W I170.04 W 1178.93 W 1199.84 W FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED V:ERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7915.00 6544.90 6390.90 3959.93 S 17 38 W SCHLUMBEROER O I REC T I ONAL SURV E Y COMPANY ARCO ALASKA. INC. · WELL 2K- 16 FIELO KUPARUK COUNTRY USA RUN ONE DATE LOOOEO 18 - DEC - 89 REFERENCE '73630 WELL- <( 144' 2~K-~ 16 !RIZONTAL PROJECTION FNL, 94' FEL, SEC l l, TION, R8E, UM) NORTH ~000 ~000 1000 -1000 -~OOO -9000 -4000 ,~3UT H -SO00 HEST REF 79690 SCALE = I/lO00 IN/FT --r.~.*-t,**-t~-.-r--r*-r*-: ...... r*-:*.-t.*-, .... --t**T.T*-*.~ ....... ?-'*~--;'*-: ..... :~-*'*:*-T--t. ....... ?'*'~"*-,,'**T*" "'~"-..'**-~"'? ...... !"-~*"%.."~ ..... ~'*'*r-:~**~ ...... ..' T*~ T' ..' ~: '~ ! ~ ~ "~'*T'*'.~"".,' ...... ~"T'T'-~"'*f'-:'"-S'-/ :" · .~-~ 4- 4--~. ~.-4.--~-i 4~-~ _L i-~ ,; ~ -~*-.L-~..-~....~.:-~:-~...~.-4....~ ........ ~..-b*4..-.~.--.~.,4----b--~--b..l---;.--~,*-~-.-v.:L-b-.*~.-4.-~ ...... ~..4.-b.~ ....... ~..4..4 ........... ~...-~..--~.-4 ........ ~ ........ ~.-..~ ........ ~..4 * 4 4.4.4---.-4--4.-4--4 .... 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H-~.-~...~ ....... f-~..~..+-~.-+..HH+ ....... ~-+-~-~ .... .~ ~.4-- -Z~-~ ~ -~-4-~4Z-4-~-.,..4...[..-~-,..,-4..4..~-,.414 - - t -~ ~-.* ....... ;..4 ....... 4..+-:..4 ....... ~-.,-+..~...~ .-4..--r.?.~ ....... ?.74.---~ ..... t-?.-t.-.~ ..... ~-.?..?-4..~ ...~-~..-~...~-. :, I : : : : · : I : : : : : : : : : : ' I : : ; : : ; ; { : ; } ] ~ : ~ ; ; : : : ~ : : : : : : : : : : ? ~ i , ..4..~..4--4.-.-~-4.-~. ~.-. ,-4 4-~ ~-4 ~ ~---~ ~ ~ ~ 4-4 ; ~, ~ · .~ 4-.? ...... H4-??....~...?.-?,.~ ....... ?"'-r'?----~ ....... r'-'r'-r-?---r.--r'-'r--r-"~ ...... r-r..-,'--.~ ........ ,...?...r.--, ....... r-.?-...r.'?... 'T'"r'T'"~-" -4000 -9000 -2000 -1000 0 1000 2000 9000 4000 44' ~.FNL, 94' FEL, SEC 11, TION, R8E, UM ) RTICAL PROJECTION 19. -2000 - 1000 0 0 !000 2000 3000 4000 SO00 6000 199. PROJECTION ON VERTICAL PLANE 199. - 19. SCALED IN VERTICAL OEPIHS HORIZ SCALE : 1/1000 IN/FT ITl -"1 o o 0 COMPLETION DATE ~/ ! .~;z ; )'o CO. """"""'"""' _ ~ ~ . I~UII~ 1~4,~, I. I , AOGCC GEOLOGICAL I~L~It,~'IERIALs INVENTORY LIST "' , {, ,c, heck off or list data as it is re~ceived ) -40,7 ! ,¢//~ ¢-//~o drilling history ~ surve~¢, '1 vi' well tests I core desripti~n cored intervals,,, core .aha. lysis , , dry dit,ch intervals digital data . ..... LOG TYPE ' RUN INTERVALS SCALE NO. '2] ~ C~ ~r~) / " ~"¢ ~" ...... .......... , , , , , ,, ,,, .... ARCO Alaska, Inc. Date- December 28, 1989 Transmittal #: 7635 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 5 Acoustic Cement Bond Log ~'~'¢¢') 1 2 - 1 8 - 89 61 68 - 81 85 2 K - 1 6 Acoustic Cement Bond Log (..¢¢~ 1 2 - 1 8 - 89 5838 - 7764 2K-1 6 CET Log 1 2-1 8-89 5838-7764 Receipt Acknowledged: DISTRIBUTION' NSK Drilling State of Alaska(~sepia) RECEIVED --' .... :JAN 1 2 Alaska 01! A Gas Cons. Comm'l Anchorage "~"~ STATE OF ALASKA 0 ~ A~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ 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 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 144' FNL, 94' FEL, Sec. 11, T10N, R8E, UM At top of productive interval 1602' FSL, 1283' FEL, Sec. 12, T10N, R8E, UM (approx) At effective depth 1407' FSL, 1351' FEL, Sec. 12, T10N, R8E, UM (approx) At total depth 1343' FSL, 1374' FEL, Sec. 12,T10N, R8E, UM (approx) 12. Present well condition summary Total Depth: measured (approx) true vertical 791 5' feet 651 5' feet Plugs (measured) None RKB 154' 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-16 feet 9. Permit number 89-94 10. APl number 50-103-20115 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool Effective depth: measured (approx) true vertical 7802' 6425' feet Junk (measured) feet None Casing Length Structural 8 0' Conductor Surface 3 2 0 0' Intermediate Production 7 8 0 5' Liner Perforation depth: measured Size 16" 9 5/8" 7" None Cemented 1100 Sx AS III & 450 Sx Class G 250 Sx Class G true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Attachments Measured depth True vertical depth 115' 115' 3235 2733' (approx) 7883' 6490' (approx) Description summary of proposal _ Detailed operation program BOP sketch_ 14. Estimated date for commencing operation 115. Status of well classification as: February, 1990 I Oil X Gas __ 16. If proposal was verbally approved Name of approver Date approved S e r vi c e 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned ¢ ~' ~,(~5. c~_~_-_? Title Area Drillincj Engineer Date / FOR COMMISSION USE ONLY Suspended Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form require 10-/-/"-) ~ IApproval No. Approved by the order of the Commission Form 10-403 Rev 06/15/88 URIGtNAL SIGNED Commissioner Date /'~ "* ~7 'O~'~' SUBMIT IN TRIPLICATE 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. KU?ARUK RIVER UNIT County, parish or borough NORTH SLOPE Lease or Unit ADL: 25588 ALK: 2674 Title DRILLING State 2K-16 Well no. Field Auth. or W.O. no. AK3714 Operator ARCO Spudded or W.O. begun IDate Hour 10/15/89 00330 IARCO W i, 55.8533 Prior status if a W,O. SPUD Date and depth as of 8:00 a,m. 10/16/89 (1) TD: 311'( 311 SUPV:TM 10/17/89 (2) TD: 2911'( 2600 SUPV:TM 10/18/89 (3) TD: 3295'( 384 SUPV:TM 10/19/89 (4) TD: 3962'( 667 SUPV:CD 10/20/89 ( 5) TD: 6304'( 2342 SUPV:CD 10/21/89 (6) TD: 7770'( 1466 SUPV:CD 10/22/89 (7) TD: 7850'( 80 SUPV:CD 10/23/89 ( 8) TD: 7915'( 65 SUPV:CD Complete record for each day reposed DOYON 14 DRLG SURF HOLE MW: 8.8 VIS: 78 RIG ACCEPTED AT 2300HRS ON 10/15/89, NU DIVERTER AND FLOW LINES,PU BHA, TEST DIVERTER, OK, SPUD WELL 0330 HRS. 10/16/89, DRILLING AHEAD DAILY:S34,220 CUM:$34,220 ETD:S34,220 EFC:$1,308,000 DRLG 12.25" HOLE MW: 9.3 VIS: 68 DRLG F/311 T/2911, KICK OFF @ 1100', DROP THRU PERMAFROST @ 1552, COAL SEAM @ 1761' DAILY:S52,741 CUM:$86,961 ETD:S86,961 EFC:$1,308,000 N.U. BOPE 9-5/8"@ 3235' MW: 9.5 VIS: 56 DRILLED F/ 2911 T/ 3295, CIRC. HOLE CLEAN, POOH W/ TIGHT SPOTS @ 2430 & 2000, RIH, NO PROBLEMS, CIRC., POOH LD BHA, RUN 82 JTS. 9 5/8" CSG, TAGGED UP AND HAD TO LAY DOWN 1 JT.,CMTD W/ll00 SX ASIII & 450 SX CL 'G', LOST RETURNS, DID TOP JOB, ND DIVERTER, NU BOPE. DAILY:S232,353 CUM:$319,314 ETD:S319,314 EFC:$1,308,000 DRLG F/3962 9-5/8"@ 3235' MW: 8.7 VIS: 34 MU BRADEN HEAD, NU BOPE,TEST BOPE, OK, TIH, TEST CSG, OK, DRLG FLOAT EQUIP, TEST FORMATION T/ 12.5 EMW, OK, DRLG F/3310 T/3551, BIT TRIP FOR #3, CUT DRLG LINE, DRLG F/ 3551 T/ 3962. DAILY:S90,765 CUM:$410,079 ETD:S410,079 EFC:$1,308,000 DRLG F/ 6304 9-5/8"@ 3235'~ MW: 9.2 VIS: 34 DRLG F/ 3962 T/4690, TRIP F/ MWD, DRLG F/ 4690 T/ 6304. DAILY:S50,715 CUM:$460,794 ETD:S460,794 EFC:$1,308,000 DRLG F/ 7770 9-5/8"@ 3235' MW:10.1 VIS: 39 DRLG F/ 6304 T/ 7284, CIRC AND POOH, LEAK OFF TEST TO EMW=10.6,RIH, DRLG F/ 7284 T/ 7770 DAILY:S58,190 CUM:$518,984 ETD:S518,984 EFC:$1,308,000 POOH F/ LOGS 9-5/8"@ 3235' MW:10.2 VIS: 38 DRLG F/ 7770 TO 7850, CIRC, SHORT TRIP, SPOT DIESEL, POOH, RU LOGGERS, LOGS WOULD NOT GO, PU BHA, RIH, REAM F/ 4850 T/ 4944, RIH TO TD, NO FILL, POOH TO LOG DAILY:S60,448 CUM:$579,432 ETD:S579,432 EFC:$1,308,000 RUNNING 7" CSG 9-5/8"@ 3235' MW:10.2 VIS: 39 POOH, RUN LOGS, RIH, REAM TIGHT SPOT 7790-7850,DRLG F/7850 T/7915, CIRC. POOH, LDDP, RUN 7"CSG. DAILY:S140,963 CUM:$720,395 ETD:S720,395 EFC:$1,308,000 The above is correct Drilling, Pages 86 and 87. AR3B-459-1-D umber all daily well hlsto~ forms consecutively ~they are prepared for each well. iPage no. ARCO O~l and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted aisc when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting lhe entire operation if space is available. I Aocounting cost center code District County or Pariah ~te ARCO ALASKA INC. NORTH SLOPE Field Lease or Unit no. KU?ARUK RIVER UNIT ADL: 25588 ALK:2674 2K-16 we~ Auth. or W,O. no. Title AK3714 DRILLING Operator I A.R.Co. W.I. ARCO 55.8533 Spudded or W.O. begun Date SPUD 10/15/89 Date and depth as of 8:00 a.m. 10/24/89 ( 9) TD: 7802'( 0) SUPV:CD Complete record for each day reported DOYON 14 Iotal number of wells (active or inactive) on this oat center prior to plugging and bandonment of this well our IPrior status if a W.O. I 00330 RIG RELEASED @ 2100 10/23/89 7"@ 7883' MW:10.3 VIS: 0 CONTINUE RUNNING CASING, 7" 26# J55 BTC, 201 JTS SET @ 7884', CIRC, CMT W/ 250 SKS CLASS G, ND BOPE, INSTALL PACKOFF, CHANGE OUT SPOOLS, TEST PACKOFF T/ 3000, OK, RIG RELEASED @ 2100 HRS 10/23/89. DAILY:S161,218 CUM:$881,613 ETD:S881,613 EFC:$1,308,000 Old TD New TD PB Depth Released rig Date Kind o r g 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 gasTeat time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct sig~ ~ Date sFe°; ~;o~ e%ruerPe~'~i~)nnu aaln, ds de '¢~ ti r~ nb Ul 0,~' Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each well. Page no. Olvl~on of AtlanflcRIchfleldCompany ARCO Alaska, Inc. Date: November 2, 1989 Transmittal #: 7598 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Engineering 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 6 OH Edit Tape and Listing 1 1 - 1 - 8 9 # 7 3 5 2 6 Receipt Acknowledged: DISTRIBUTION: Lynn Goettinger ............................. Dat~.' State of/Alaska ARCO Alaska, Inc. Date: October 31, 1989 Transmittal #: 7593 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Engineers 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 6 5" Dual Induction-SFL 1 0 - 2 2 - 8 9 1 0 0 0 - 779 6 2K-1 6 FDC-POROSITY I 0-22-89 7295-7770 2K-16 Cyberlook 1 0-22-89 7300-7750 2 K - 1 6 2" Dual Induction- SFL 1 0 - 2 2 - 8 9 1 0 0 0- 7796 2K-16 Raw Data-FDC I 0-22-89 7295-7770 Receipt Acknowledged: ............................. Date: .......... DISTRIBUTION: D&M Drilling Franzen NSK State of Alaska(+Sepia) Vendor Package(Johnson) iii & Gas Cons. 'Anchorage September 6, 1989 Telecopy~ (907)276-7542 J. B. Kewin Regional Dz'iiling Engineer ARCO Alaska, Inc. P. O. Box 100360 ~chorage, Alaska 99510-0360 Re: Kuparuk Ever Unit 2K- 16 ' ~CO AlasP~,' InC. Permit No. 89-94 Sur. Loc. 144'FNL, 94'FEL, Sec. 11, T10N, RSE, UM. Btmhole Loc. 1221'FSL, 1463'FEL, Sec. 11, T10N, RSE, Dear Mr. K~in: Enclosed is the approved application for permit to drill the above referenced well. The pemit to drill does nog exempt you from obtaining additional permits required by law' from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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 sur'face casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hOurs prior to co~encing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COI.~'IiSSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA A~,..,r(A OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X ~edrill ~ I lb. Type of Well Exploratory __ Stratigraphic Test ~ Development Oil .~. Re-Entry m Deepen --I Service _ Development Gas __ Single Zone ~ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc, RKI~ 154. P~,~l 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 ~'.' Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 144' FNL, 94' FEL, Sec. 11, T10N, R8E, UM I~uDaruk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1400' FSL, 1400' FEL, Sec. 11, T10N, R8E, UM 2K-16 #U630610 At total depth 9. Approximate spud date Amount 1221' FSL, 1463' FEL, Sec 11, T10N, R8E, UM 9-6-89 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2K-15 7983' MD 1221' @ TD feet 25' at SURFACE' feet 2560 6463' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 11 00'feet Maximum hole angle 42 o Maximum surface 1 663 psll~ At total depth (TVD) 3362 psig 'lB. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casin~l Weight Grade Couplin~l Len~lth IVD TVD IVD TVD (include sta~le dataI 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 CF 12.25 9.625 36.0# J-55 BTC 3211 35' 35' 3246 2934' 1000 Sx AS III & HF-ER~ 450 Sx Class G ~".5 7" 26.0# J-55 BTC 7949 34' 34' 7983 6463' 200 Sx Class G HF-ERWl 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 Lenglh Size Cemented Measured depth True Vertical depth Structural R EC E IV E D Inlermediate Production Liner AUG 2 8 989 Perforation depth: measured true vertical Naska 0ii & Gas Cons, C0mmiss~011 .... Anchorage ' 20. Attachmenls Filing fee ~ Property plat __ BOP Sketch ~X Diverter Sketch X Drilling program ~ Drilling fluid program ~ Time vs depth plot T Refraction analysis _ Seabed report ...20 AAC 25,050 requirements certi tha the foregoing is true a correct to the best of my knowledge Signed Title Regional Orillin~ Engineer Date // ~ ~ // ./ ,/' Commission Use Only / Per~t,Num~e~_ I^~'50-/'onumber.~ - I Approval date 00~ / 0~) ~(~N otherSee coVerrecjuiromentsletter for Conditions of 'approval Samples required __Y e s .~ N o Mud log required __ Y e s o Hydrogen sulfide measures __ Y e s ~" N o Directional survey required ~ Yes__ N o Required working pressur~ BOPE_ ~2~ .~ 3M; __ SM' __ 10M' __ 15 M Other: y/~y~/~ ..... by order of Approved by ~,_ - ,,,_.~/'. ~,, q ar~.~~//~.,,~ Commissioner the commission Date Form 10-401 Rev.~/~-2~8'~ / / , triplicate ARCO ALASKA. Inc Pad 2K, Well No' 16 Revised Proposal Kuparuk Field, North Slope, Alaska RKB ELEVATION t 2000_ m 3000_ m c~.. 4000_ . 5000_ 6000 _ 7000 KOP'" TVD'I 1 O0 TMD~ 11 O0 DEP,,O 3 BUILD 3 DEG PER 100 FT $ B/ PERMAFROST TVD=1424 TMD-1426 DEP-28 T/ UGNU SNDS TVD"1544 TMD-1548 DEP-52 3,3 'T/' w SAK SNDS TVD-2162 TMD-2226 DEP=323 ,39 EOC TVD-2374 TMD-2494 DEP-487 B/ ~/ SAK SNDS TVD-2734 TMD-29?8 DEP-809 9 5/8" CSG PT TVD=2934 TMD=3246 DEP-988 K-lO TVD-3184 TMD":3582 DEP-1212 K-5 TVD=4490 TMD-53:35 DEP-2:381 AVERAGE ANGLE 41 DEO 50 MIN ZONE C TVD-6154 TMD=7568 DEP=:3871 T~ ZONE A · TVD-6187 TMD=?612 DEP-:3900-, ~ ', TARGET CNTR ?VD=6251 TMD-?698 DEP-,:395B KUP SNDS TVD=6:31 4 TMD-??8:3 DEP-4014 TD (LOG PT) TVD=646:3 TMD-?98:3 DEP-4147 RECEIVED AUG 2 81989 Alaska Oil & Gas Cons. comm]SS~.il Anchorage I I I I 0 1 000 2000 :3000 4000 VERTICAL SECT[ON I 5000 HOR~ZONT^L PROdECT I ON ~-- ~SCALE 1 IN. = lO00 FEET ARCO ALASKA, I no · Pad 2K. Well No, 16 Revised Proposal ' :' Kuparuk Field. North Slope. Alaska · 1000 0 _ z 1000 _ I ~- 2000 _ 3000 _ · ": ::;?:i::: 7:' T~GET ~NTER '"::'~' '" : TVD"~2$1 THDm'?~98 4000 DEP-ae,8 WEST-EAST 3000 2000 1000 0 I I I SOUTH 3736 WEST 1306 1000 I SURFACE TARGET LOCAT I ON, 1400' FSL. 1404)' FEL SEC. 11. T 1 ON. RSE TD LOCATION ~ 1221' FSL. 1463' FEL SEC. 11. TION. ROE SURFACE LOCAT I ON, 144' FNL. 94' FEL SEC. 11. T 1 ON. RSE S 19 DEQ 16 MIN W J958' (TO TARGET) 100 50 _ O ~ 300 250 200 150 100 50 0 50 .... I , I I I I I I I 1 000 I I I I I I lO0 50 _ J 100 _ I I 150 _~ ~ I 200 _ ,,, m 300 / / I I I I I 250 200 1 50 1 O0 50 I I I I I 100 _ 100 _ 50 _0 _ 50 _ 100 _ 150 _ 200 DRILLING FLUID PROGRAM (2K-16) Spud to 9-5/8" Drill out to Weight up surface casing weight U.D to TD Density 8.8-9.0 8.7-9.2 10.0 PV 15-30 5-1 5 1 1-1 6 YP 20-40 8-12 8-12 Viscosity 70-80 35-40 35-50 Initial Gel 5-15 2-4 3-5 10 Minute Gel 1 5- 3 0 4 - 8 5-1 2 APl Filtrate 1 0 - 1 5 1 0 -2 0 6 pH 9-1 0 9.5-10.5 9.0-10.5 % Solids 10 +/- 4-7 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 13.0 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-16 is 2K-15. This well is 25' 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 1) MIRU, 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) 'Drill 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casing. Pressure test to 3500 psig. 11) Downsqueeze Arctic pack' and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 1S) 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 insta)l Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. OEGASSER MUD CLEANER SHALE SHAKERS STI STIR STIR TYPICAL MUD SYSTEM SCHEMATIC -7 A(~CLMLATCR CAPACITY I'~T I. OEO< N~) FILL AO3,MiATOR REiE;NOIR TO PE]:F.R LEVEL WITI.I ~IC FLUID. ASSURE THAT ACQ.M. iA'rCR ~ I~ ~ PSI WITH 1500 PSI ~TI~ el' TI.~ REGLLATOR. 3. CBSERVE TIKE. TI,,EN CLOBE ALL UNZ"r~ $IM/,.TN~EQ. ISLY AN) RECI3~) ]~ TII~ AN3 ~ RLrMMNIN$ AFTER 4. RECORD ON NN3C RE]N]RTo ~ ~ABLE LO~ER LIMIT I$ 45 SE~ CLOSIN~ TII~ N~) 1200 PSI Rlg~IMING 2 1:5-5/8' BI~ STACK TEST I. FILL BCP STACK AN3 CH~ MIINIFCI. D WITH ARCTIC DI£~ 2. Q. ECK THAT N.L LOCK ~ ~ IN I~EL.~ ARE FLLLY RETRACTEIX SEAT TEST PLUG IN I~ELU. EN3 WITH ~ING JT 4. PI;ESSU;E UP TO 250 ~ MD 143LD F'OR I0 MIN, II~ C~EA~ F:REg~I. RE TO ~ PSI AI~ HI3LD FI~ IO MIN, BLEED PI~gSI.I~ TO 0 I~l. L:Zl~: V,o4..VE:S. CLO~ Ta=' PIPE ~ MD ~ VALV~_S CN Kill 6. TESTTO25OPSl N~)~EI3OPSI ASINSTEP4. ?. CQ~TI~ TES'I'II~G ALL VALVES, LIliES, MD CH3(E$ WITHA ZSO PSI LOW N~) ~XX) PSl HI~I'I. 1EST AS 8. C;:EN TC~ PIPE ~ MD CLC~E BOTTOM PIPE ~ TEST BOTTCM PIPE; ~ TO 250 PSl MD 3000 PSI. ~. CPEN BOTTC~4 PIPE ~ BAa( ou'r ~ JT AND IO. CLOSE BLII~D RAk~ MD TE~T TO ~O PSI MD 30CO PSI. I~AIIFCLD ~ LII;~ ~ FLI. L OF MiN.-FRiEZIh~ FLUID, SET AIL VALVES IN [~RILLIN~ P0~ITICN. 12. TEST Sg'N~PlPE VALVES, ~my, KELLY 03(]<S, DRILL PIPE SAFETY VALVE., AN3 II~BII~ ~ TO 250 PSI ~ ~ PSl. FORM, SIGN, ~ ~ TO CRILLIN~ SU=ERVISOR. VEEKLY THEREAFTB~ FLNCTICNN.LY Q=ERATE I)CPE ~ I~.,. 510064001 KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC _! L DESCRIPTION 1. 16' CONDUCTOR 2. FMC SLIP~:~I WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16' 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL WI10" OUTLETS 5. 10' HCR BALL VALVES W/10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTEP. VALVES CAN BE REMOTELY CONTR(~/Fn TO ACHIEVE DOWNWIND DIVERSION. 6. 20' 2000 PSI ANNULAR PREVENTER ARCO ALASK~ INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC2S.035(b) MAINTE~NANCE & OPERATION 3 I ! , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 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 ARCO Alaska, Inc. Post Office Box Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 12, 1988 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Conductor As-Built Location Plat- 2K Pad /~ (Wells 1 - 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 DEC 1 1988 Alaska 0il & Gas Cons. C0rmnissim~ Anchorage GRU13/010 ARCO AlaskR, Inc. is a Subsidiary of Alh3nticRichfieldC~rupany N.TS. et SECTION IECTION I I · WELLS 1-12 ARE LOCATED IN G SECTION 2, T ~ON., R. 8 E., r~ss UMIAT MERIDIAN. WELLS 13-24 ARE LOCATED IN SECTION II,T. ION., R. 8 E., UMIAT MERIDIAN. SECTION I PROTRACTED SECTION CORNER Notes: I. COORDINATES ARE ASP. ZONE 4. VICINITY MAP Tilth~1 T ION ~ SECTION 12 RECEIVED DEC; 1 ~ 1~88 ?. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATtONS ARE B.P.M.S.L. 4. O.G. ELEVATIONS FROM CED- RIXX-3311, re~4. 5. HORIZONTAL POSITION BASED ON 2-K CONTROL MONUMENTS PER LOUNSBURY 8, AS:~OClATES. 6. REFERENCE FIELD BOOK; L88-40, pgs. 55,56, 58,59, 65 8, 66. ,,~p ¥. Well ASP's Alasl a Ui! & ~-,.:~ CH,,.,.:,. L;0r,;m;3:;:'::: Dist. Dist. O.G. Pod No. 'Y' 'X' L/~t;t~dlD~ LONGITUDE F.S.L. EE.L. Elev. Elev. I 5,938,600.18 498,310.17 70°14'36.519 " 150°00'49.133" I 296' 94' !14.0 118.5 2 5,938,575.14 498,310.28 70° 14' 36.273" 150°00'49.130'' 271' 113.9 3 5,938,550.:50 498,310.35 70° 14.' 36.029" 150°00'49.128" 246' 113.8 4 5,938,525.46 498,310.06 70o14' 35.784" 150°00'49.136" 22:2' 113.8 5 5,938,500.19 49 8,310.17 70°!4' 35.536" ~50o 00'49.134'' 196' 113.8 6 5,958,475.14 498,310.33 70014' 35.289" 150°00'49.128'' 171' 113.8 7 5,938,450.36 498,310.36 70°14'35.046" 150°00'49.127'' 146' 113.8 4' ii 8 5,938,425.30 498,310.18 70°14,34.799 150°00'49.132'' 121' 113.8 9 5,938,400.30 498,309.98 70°1 34.55;5" 150°00'49.137'' 96' 113.8 I0 5,938,375.19 498,510.14 70014'34.'506'' 150°00'49.135" 71' 113.9 I I 5,938,350.'22 498,310.14 70°14'3,4.061 " 150°00'49.133" 46' 113.9 12 5,958,$25.20 498,310.17 70°14' $$.815'' 150 °00'49. 131'' 21' 94' 113.9 118.5 FN.L. 13 5,938,2'55.31 498,310.37 70° 14' $2.930" 150°00'49.125'' 69' 94' 113.7 118.5 14 5,9.58,210.14 498,310.16 70014'32:.683'' 150o00'49.131" 94' 113.7 15 5,958,185.12 498,.510.16 70 ° I 4' 37_.4.57'' 150°00'49. 131'' 119' !13.8 16 5,938, 160.11 . 498,310.20 70°14' .52. 191'' 150° 00' 49. 130" 144' 113.8 17 5,938,135.21 498 310.18 70o14' 31 946" 150°00'49.130'' 169' 115.9 18 5,958, 110.19 i 498,'510.29 70° 14' 31.700" 150°00'49.127'' 194' 114.0 19 5,938,085.?~0 498,'510.27 70014' 31.454" 150o00'49.12:7'' 219' 114.0 20 5,938,060.14 498,:510.22 70°14' 31.207'' 150° 00'49. 128" 244' 114.1 21 5,9 38,035.16 498,510.16 70° 14' 30.962'' 150°00'49.150" 269' ~r !14.0 22 5,938,010.40 498,3~0.19 70°14' 30.718" 150° 00'49. 129" 294' 94' 114.0 23 5,937,985.37 498,310.13 70014' .50.47t" 150° 00'49. 130" 319' 95' 114.0 24 5 ~957,960.29 498,310.08 70o14'30.225'' 150°00'49.132" :544' 95' I 113.9 118.5 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS 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 zO, 19e8. AR :0 Alaska, Inc. DRILL SITE 2.K CONDUCTOR AS-BUILTS CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE L°c (2 thru (8) (3) Admin ~PZ ~Z//~ 9. ('9 thru 15)-' ' 10. (10 and 13) 12. 13. (4) Casg ~~.~, ~-~'-j~q (14 thru 22) (23 thru 28) Company/~c~O Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. 3. Is we~] located proper distance from property line .................. 4. Is w~i!ocated proper distance from other wells ................ ' ... 5. Is suz~'iCient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ............ ... 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ............... ~ . .... Lease & Well No. YES NO R~MARKS ' 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 ......................... i4. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........ ? ................................ Will surface casing protect all zones reasonably expected to serve as an .underground source of drinking water ..................... Is enough cement used to circulate on conductor 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 30~P~ psig .. ~ Does the choke manifold comply w/AMI RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER £z',,-. ' (2~ thr~ 3i) Fo r 29. 30. 31. (6) Add: ~-~.,.'~..~.~( ~'~ Geology: Engineering: DWJ BEW 32. rev: 01/30/89 6.011 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 GE0. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 0 ~0 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. RECEIV'E1) NOV - ~ ~ & Gas ~o~..C;_o. mmissi.oJ) COMPANY NAME : ARCO ALASKA~ ~IELL NAME : 2K-I6 F]:E:LD NAME : KUPARUK ~OROUGH : NORTH SLOPE STATE : ALASKA AP! NUMBER : REFERENCE NO : 73526 .IS TAPE VERIFICATION LISTING iCMLUMBERGER ALASKA COMPUTING CENTER 1-NOV-1989 lO:gO *~*~ REEL SERVICE N,AME : EDIT D.aTE ORIGIN : FLIC REEL NAME : 73526 CONTINUATION ~ : PREVIOUS REEL : COMMENT : ARCO ALA:SKA, INC~,,KUPARUK,,ZK-16,,50-I03-20115 **~ TAPE HEADER SERVICE Nd'ME : EDIT DATE : 89/11/ ORIGIN : FLiC TAPE NAME : 73526 CONTINUATION ~ : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA~ · ~ FILE HEADER FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001A02 DATE : 89/11/ 1 M;AX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: SCHLUMBERGER WELL SERVICES COMPANY NAME: ARCO ALASKA~ INC. WELL: 2K-16 FIELD: KUPARUK BOROUGH: NORTH SLOPE STATE: ~LASKa AP1 NUMBER: 50-103-20115 LOCATION: 144' FNL & 94' FEL SECTION: 11 TOWNSHIP: 1ON RANGE: 8E PERMANENT DATUM: MSL ELEVATION: 0 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 1-NDV-tg$9 10:00 LOG MEASURED FROM RKB 154 ABOVE PERMANENT DATUM ELEVA'TIONS KB:' 154 DF:: 153 GL: 113 DATE LOGGED: RUN NUMBER: TO DRI~LLER: TO LOGGER: 22-OCT-1989 ONE 7850 7804 CASING: 9 5/8" 47 LB @ DEILLER DEPTH OF 3235 AND LOGGER DEPTH OF 3235 BIT SIZE: 8 1t2" TYPE FLUID IN HOLE: WEIGH'TED POLYMER DENSITY: 10.2 VISCOSITY: 38 PH: g.$ FLUID LOSS: 4 MUD RESISTIVITY:: 3.27 FILTRATE 'RESISTIVITY: 3.22 MUD CAKE RESISTIVITY: : 3.4 @ 66 @ 66 B 66 TIME CIRCULATION ENOEO: 03:00 ]22-0CT TIME LOGGER DN BOTTOM: 09:00 22-0CT MAXIMUM TEMP RECORDED: 138 'LOGGING OISTRIC'T: LOGGING: ENGINEER: WITNE SS: :P'RUDHOE BAY WARNER LOWEN/DIXON TOOL NUMB:ERS: DIS-EC 1131 PGS-HB 508 CNC-a 1.238 IEM-BD 1290 D'IC-DA 41'? PgC-J A 1041 SGC--JC 2626 NLM-BC 1312 FIELD REMARKS: I 1/2" STANDOFFS .AND A. 2'~ HOLE FINDER USED ON THE OIL. MATRIX DENSITY : 2.65 G/CC., FLUID DENSITY = 1.0 G/CC. NEUTRON MATRIX = SAND, HOLE CORRECTION : CALIPER. SP SHIFT AT 6750' ON MAIN PASS. PAGE: DATE JOB STARTED: 01-NOV-B9 JOB REFERENCE NO: 735Z6 LDP/ANA: J. KOHRING FILE - EDIT.O01 ARCO ALASKA, INC. KUPARUK 2K-16 IS TAPE 'VER'IFIC~*TION LISTING CHLUMBERGER aLASK~ COMPUTING CENTER 1-N0¥-1989 10:00 50-10~-20115 MAIN PASS LOG DA'TA DATA SAMPLEO EVERY -.5000 FEET DATA IN~CLUDED - TOOL EXTENSION TOOL TYPE USED NAME D IT-D .. OIL FDC - FDC CNT-A/D/H .CNL G~ . CSG DUAL INOUCTION SFL FORMATION DENSITY COMPENSATED NEUTRON GAMMA R AY 7795' TO 3235' 7770" TO 7297* '775.5' TO 7297' 3227~ TO 996': PAGE: TABLE TYPE : CONS TUNI VA:LU CN ARCO ALASKA, INC. FN KUPARUK WN 2, K-16 APIN 50-103-20115 FL 1~4' FNL & 94' FEL SECT 11 TOWN RANG 8E COUN NORTH SLOPE STAT ALASKA NATI USA WITN LOWEN/OIXON SON 548741 PDAT MSL EPD FT O. LMF RKB APO FT EKB FT 15~. EOF FT 153. EGL PT 113. TOO FT 7850. BLI FT 7795. TLI FT 1000. TCS 03:00 22-0CT TLAB 09:00 22-OCT STEM OEGF -4. DEFI COMPANY NAME FIELD NAME WELL NAME AP1 SERIAL NUMBER FIELD LOCATION SECTION TOWNSHIP RANGE COUNTY STATE OR PROVINCE NATION WITNESS'S N.AME SERVICE ORDER NUMBER PERMANENT DATUM LOG ME,~SURED FROM BOTTOM LOG INTERVAL TOP 'LOG INTERVAL TIME CIRCULATION STOPPED TIME LOGGER AT BOTTOM IS TAPE VERIFICATION LISTING CMLUMBERGER ALASKA COMPUTING CENTER 1-NO]V:-i989 10:00 TABLE 'TYP:. : CURV OEPT I LO ILM SFLU SP GR TENS DPHI RHO~ DRHD FFOC NFOC CALI GR TENS N PiH I T NPH DEFI DEPTH CHANNEL NAME [L-,~ EEP RESISTIVITY IL-MEDI~UM RESISTIVITY SFL UNAVERAGED SPONTANEOUS POTENTIAL TENSION OENSITY :POROSITY BULK DENSITY DELTA RHD i FAR FDC COUNT RATE NEAR FOC COUNT RATE CALIPER GAMMA RAY TE NS ID N NEUTRON POROSITY THERMAL NEUTRON POROSITY TNRA CALIBRATED THERMAL NEUTRON RATIO. NPOR RCNT RCFT C NT C CFTC GR C ALii T E:N S GR TENS m NEUTRON POROSITY OUTPUT FROM AN APPLICATION PROGRAM RAW CORRECT'O NE~R 'THERMAL COUNTS RAW CORRECTED FAR THERMAL COUNTS CORRECTEO NEAR THERMAL COUNTS CORRECTED FAR THERMAL COUNTS GAMMA RAY CALIPER TENSION GAMMA RAY TENSION PAGE: DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 6~EB ** TYPE REPR CODE V~LUE ! 66 0 2 66 0 3 73 11Z ~ 66 1 6 73 7 65 B 58 0.5 9 65 FT 11 66 9 12 6B 13 66 0 IS TAPE VERIFICATION LISTING CHLUMB~RGER ~LASKA COMPUTING CENTER 1-N'DV-1989 10:00 TYPE REPR CODE :VALUE I4 65 ~T 16 '66 0 .66 ~ SET TYPE - CHAN ~ NAME SERV UNIT SERVICE ~PI API aPI API FILE NUMB NUMB SZZE REPR PROCESS ID O.ROE~ ~ LOG TYPE CLa. SS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 568741 O0 000 O0 0 I I I 4 68 0000000000 ILO Oil OHMM 548741 07 120 4,6 0 I I I 4 68 O0000000OO ILM OIL OHMM 548741 07 120 44 0 1 1 1 4 68 0000000000 SFLU OIL OHMM 5'48741 07 220 01 0 I I 1 4 68 0000000000 S P OIL M V 54 8741 07 010 01 0 1 I I ,~ 68 00 O00000 O0 GR OIL GAPI 548741 07 310 01 0 I 1 1 4 68 0000000000 TENS OIL L~ 548741 07 635 21 0 I i i 4 68 0000000000 DPHI FDC PU 548741 07 890 O1 0 1 1 1 4 68 0000000.00.0 RHOB FDC G/C3 548741 07 350 02 0 I I I 4 68 0000000000 DRHO FOC G/C3 548761 07 356 O1 0 I 1 1 4 68 0000000000 FFDC FOC 'CPS 548741 07 356 OZ 0 I I 1 ,~ 68 0000000000 NFOC FOC CPS 548741 07 354 01 0 I 1 t 4 68 000'00000'00 CALI FDC IN 5487~1 07 280 O1 0 ! 1 1 4 68 0000000000 GR ~OC GAPI 548741 07 310 01 0 1 1 I 4 68 0000000000 TENS FDC LB 548741 07 635 21 0 I I I ~ 68 0000000000 NPHI CNL PU 548741 07 890 O0 0 I I I 4 68 0000000000 TNPH CNL PU 548741 07 890 O0 0 I 1 1 4 68 0000000000 TNRA CNL 548741 07 420 0'1 0 ! I I ~ 68 0000000000 NPOR CNL PU 54874t 07 890 O0 0 I 1 1 4 68 0000000000 RCNT CNL CPS 548741 07 620 O1 0 1 1 1 4 68 0000000000 RCFT C'NL CPS 54874'1 07 420 01 0 I I I 4 68 0000000000 CNTC CNL CPS 548741 07 620 01 0 I I 1 4 68 00000'00000 C~:TC CNL CPS 548741 07 420 01 0 I I I 4 6B O000OO0000 GR CNL GAPI 54~741 07 310 01 0 I I I 4 68 0000000000 CALI CNL IN 548741 07 280 01 0 I 1 I ~ 68 0000000000 TENS CNL 'LB 5¢8741 07 635 21 0 I I 1 6 68 0000000000 GR CSG GAPI 548741 07 310 01 0 I I i 4 68 0000000000 TENS CSG LB 548761 07 635 21 0 I I 1 4 68 0000000000 · ~ OATA ~ DEPT. 7818.500 ILO.OIL 3.025 ILM.OIL 3.231 SFLU.DIL SP. DIL 1.750 GR.DIL 84.063 TENS.OIL 2210.000 DPHI.FDC RHDB. FDC 2.482 Dt~HD. FDC 0.105 I::FOC. FDC 549.000 NFDC.FDC CALI.FDC 8.555 GR.FDC 84.063 TENS.FDC 2210.000 NPHI.CNL TNPH..CNL 43.612 TNRA.CNL 3.622 NPOR.CNL 43.612 RCNT.CNL RCFT.CNL 4.34.300 CNTC.CNL 1752.577 CF'TC.CNL 492.982 GR.CNL CALI.CNL 8.555 TENS.CNL 2210.000 GR.CSG -999.250 TENS.CSG 4.053 10.170 681.500 45.361 1717.217 84.06~ -999.250 ,IS TAPE VERIFIC:~.TION LISTING CHLUMBERGER ALASKA COMPUTING CENTER DEP'T. SP.OIL R H 0 B. F D C C AiLI. FDC TNPH. CNL RC FT. CNL C AL I. CNL ' OEPT- S P- OIL RHDa. FDC C AL I. FDC TNPHoCNL R:C FT. CNL CALl. CNL DEPT. SP.OIL RHOS.FOC CALI.FOC T NPH. CNL RCFT.CNL C AL I. C N L DE PT.; SP. OIL R HO B.. F D C CALI.FDC TNPH. CNL RCFT.CNL CALI.CNL DEPT. SP.DIL RHOB.FDC CALI.FDC TNPH. CNL R CFT. CNL CALIoCNL DEPT. SP.DIL RHOS.FDC CALI.FDC TNPH.CNL RCFT.CNL CAL!.CNL DEPT. Sm. DIL RHOB.FDC C AL I..,1FDC TNPH.CNL RCFT.CNL 7800. 000 ILO.OIL -24. 500 GE.OIL 2.482 DRHD.FDC 8. 555 GR. FDC 43.612 TNRA.CNL 43 ~. 300 C N T C, C N L 8. 555 TENS.CNL 7700.000 ~ ILO'DtL -39.000 GE.OIL 2.459 ORHO.FDC 9.039 GR.FOC 32.417 TNRA.CNL 722, 55~ CNTC.CNL 9.039 TENS.CNL 7600.000 tLD.DIL -81.438 GE.OIL 2.439 ORHOoFOC 8. 820 GR. FDC 32.5:20 TNRA.CNL 7¢0,283 CNTC.CNL 8. 820 TENS.CNL 7500.000 ILO.OIL -TZ. 500 GE.OIL 2.420 ORHO.FDC 9.602 GR.FDC 37,087 TNRA.CNL 455.756 CNTC.CNL 9.602 TENS.CNL T400.O00 ILO,.DIL -65.250 GE.OIL 2,425 DRHO.FOC 9.141 GR.FDC 45.585 TNRA.CNL 410,605 CNTC.CNL 9.141 TENS.CNL 7300.000 ILO.OIL -48.500 GR.DIL 2.411 DRHO.FDC 9.180 GR.FDC 39.785 TNRA.CNL 498.567 CNTC.CNL 9.150 TENS.CNL 7200.000 ILO. OIL -61.469 GE.OIL -999.250 ORHO.FDC -999.250 GR.FDC -999.250 TNRA.CNL -999.250 CNTC.CNL 1-NOV-1989 10:00 3-02,6 ILM.DI'L 8¢.063 TENS.D~L 0.105 FFDC.FDC 84.063 TENSoF~C 3.622 NPDR.CNL 1752.577 CFTC'CNL 4148.000 GR.CSG 4°605 ILM.DIL 9 Z. 500 T E N S. O I L O. 044 FFDC.FDC 92.500 TENS.FOC 2.923 NPOR.CNL 2307. 534 CFTC.CNL 4 ! 24.000 G R. C S G 4.744 ILM.DIL 94.188 TENS.OIL -O.OOZ FFOC'FDC 94.158 TENS.:FDC 2.939 NPOR.CNL 2408.191 CFTC.CNL 4084.000 GR.CSG 1.855 ILM.OIL 117.063 TENS.OIL OD 080 FFDC.FDC 1117. 063 TENS.FOC 3..485 NPOR.CNL [ 7 '9 ?. 890 C F T C. C N L 4168. 000 GR.CSG 1. 961 ILM.DIL 108.375 TENS.OIL 0.058 FFDC.FOC 108.375 TENS.FOC ~. 627 NPOR.CNL 1759.058 CFTC.CNL 3934.000 GR.CSG 3.929 ILM.DIL 219.750 TENS.OIL 0.015 FFDC.FOC 219.750 TENS.FDC 3.347 NPOR.CNL 1_931.374 CFTC.CNL 440~.000 GR.CSG 3.045 ILM.OIL 525.000 TENS.OIL -999.250 :FDC.FDC -999.250 TENS.FOC -999.250 NPOR.CNL -999.250 CFTC.CNL 3- 233 SFLU.OIL 4148.000 DmHI.FOC 54go 000 NFDC.FDC 4148o000 NPMI.CNL 43- 612 R C N T. C N L ~92.983 GR.CNL -999.250 TENS.CS5 4.740 SFLU.OIL 4124.000 DPHI.FDC 500.500 NFDC.FOC 4124.000 NPHI.CNL 3 2.557 R C N T. C N L 803.T64 GR.CNL -999.250 TE:NS.CSG 5.509 SFLU. DIL 408~.000 DPHI.FOC 46 go 500 NFlJC. FDC 4084.000 N P H I. C N L 31.6,55 RC'NT.CNL 839.845 GR.CNL -ogg.250 TENS.CSG 1.957 SFLU.OIL ~16.8,.000 DPHI.FDC 600.500 NFOC.FDC ~168..000 NPHI.CNL 36.872 RCNT.CNL 562.817 GR.CNL -ggg. Z50 TENS.CSG 2,028 SCLU.DIL 3934.000 DPHI.FOC 561,500 NFOC.FDC 3934.000 NPHi.CNL 46.155 R'CNT.CNL 475.Z3.! GR.CNL -999.Z50 TENS.CSG 4.344 SFLU.DIL ~404.000 DPHI.FDC 523.000 NFDC.FDC 4404.000 NPHI.CNL 38.372 RCNT.CNL 577.430 GR.CNL -999.250 TENS.CSG 3.,085 SFLU.DIL 3970.000 DPHI.FDC -999.250 NFOC.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 GR.CNL PAGE: ~.064 ' 10.170 6 $1.500 45.361 1717.217' 84.063 -999.250 t.658 11. 585 616. :0 O0 32,088 2253a070 92.500 -999. 250 6.495 12. 809 557,500 32,603 2411.917 94.188 -999.250 2.283 13.939 679.500 41.287 1770'333 117.063 -999:.250 2.181 13.629 648.500 44.577 1704.343 108.375 -999.250 5.901 14.483 596.000 39.392 1952.478 219.750 -999.250 4.439 -999.250 -999.250 -999.250 -999.250 -9'99.250 IS TAPE VERIFICATION LISTING CHLUMBERGER ~LASK.~, COMPUTING CENTER CALI.CNL -999.250 TENS.CNL DEPT. 7100. 000 ILO.OIL $ P. g I L - 4 9 ° 2 ! 9 G R. O I L RHOB. FDC -999. 250 DRHO. FDC CALI.FOC -999. 250 GRo FOE TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999. 250 CNTC.CNL CALI.CNL -999° 250 TENS.CNL DEPT. 7000. 000 SP. OIL ,-4,4.6 88 RHOBo FDC -999. 250 CALI'FOC -99'9.250 TNPH.CNL -999.250 RCFT. CNL -999. 250 C ALI.CNL -999.250 ILO. OIL g R. g I L g R H D. F O C GR. FOC T N R A. C NL C N TC. C NL TENS.CNL DEPT. 6900.000 SP-DIL -50.344 RHOB.FDC -999.250 CALI'FDC -999.250 TN:PH.CNL -999.25:0 RCFT. CNL -999.250 CALI.CNL -999.250 ILO.OIL GR.DIL DRHO.FDC GR.FOC TNRA.CNL CNTC.CNL TENS.CNL DEPT. 6800. 000 SP.OIL -72.438 RHOB.FDC -999.250 CALI.FDC -999.250 T N P H. C N L -999.2 50 RCFT.CNL -999.250 CALI.CNL -999.250 ILO. OIL GR. OIL ORHO.'FOC GR.FDC TN RA .C N!L CNTC.CNL T E N S. C N L DEPT. 6700.000 SP.OIL -14.2150 RHOB.FDC -999.250 CALI.FDC -999.250 TNPH.CNL -999.250 RCFT. CNL -999.250 CALI.CNL -999.250 ILO.OIL SR .OIL DRHO.FOC GR.FDC TNRa~.CNL CNTC.CNL TENS .CNL DEPT. 6600.000 SP.DIL -8.000 RHOB.FDC -999.250 CALI.FDC -999.250 TNPH.CNL -999.250 RCFT.CNL -999.250 CALI.CNL -999.250 ILO.OIL GR.DIL DRHO.FDC GR .FOC TNRA.CNL CNTC.CNL TENS.CNL DEPT. 6500.000 SP.DIL -24.359 RHOB. FDC -999.250 CALI.FDC -999.250 TNPH.CNL -999.250 !LO.OIL GR.DIL DRHO.FDC GR.FDC TNRA.CNL I-NOV-lOS9 10:00 -999. 250 GR.CSG 3.'741 ILM'DIL 99.000 TENS.OIL -999. 250 FFOC'FOC -999 250 TENS.FDC -999. 250 NPOR.CNL -999,. 250 CFTC.CNL -999. 250 GR.~CSG -999.250 3.776 3934. 000 -999.250 -999.2:50 -999o250 -999'250 -999.250 3.256 ILM.DIL 3.348 122.375 TENS.OIL 3890.000 -'gg9.250 FFOC.FDC -999.250 -999.250 TENS.FDC -999.2'50 -99'9.250 NPOR.CNL -999.250 '--999r' 250 CFTC.CNL -999.250 -999. 250 GR.CSG -'999.250 4. 579 ILM.OIL 9~.188 TENS.OIL -ggg. 250 ~FDC.FDC - g g 9..Z 50 T E N S - F O C -999.250 NPOR.CNL -999. 250 CFTC.CNL -999. Z50 GR.CSG 2.51~ ILM.DIL 1112.000 TENS.OIL -999. 250 FFOC. FOC ,-999. 250 TENS. FOC -999.Z50 NPOR.CNL -999.,250 CFTCoCNL -good 250 GR.CSG 3.695 ILM. OIL 123.500 TENS.OIL -ggg. zso FFDC.FDC -999..250 TENS.FOC -999.250 NPOR.CNL -999.250 CFTC.CNL -999. 250 GR.C SG 3.109 ILM. DIL 102.125 TENS.OIL -999.250 ~FOC..FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG 3.105 ILM.DIL 104.938 TENS.OIL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL 4-687 374~4.000 -999.250 -999.250 -999.250 -999-250 -999..250 Z.613 3'754.000 -999.250 -999.250 --999.250 -999.250 -9'99.250 3.799 368 O. O00 -999.250 -999.250 -999.250 -999.250 -999.250 3.217 3654.000 -999.250 -999.250 -999.250 -999.250 -99'9.250 3.145 367~o000 -999.250 -999.250 -999.250 TENS.CSG SFLU.D[L DPHI-FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENSoCSG SFLU.DtL DPHI.FDC NFDC.FDC :NP'HI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.OIL DPHI.FDC NFDC.FOC NPHI.CNL RCNT..CNL GR.CNL TENS..CSG S FLU. OIL DPHI.FOC NFOC.FDC NPH'I.CNL RCNT.CNL G R. C N L TENS .CSG 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 TENSoCSG SFLU.DIL DPHI.FOC NFOC.FDC NPHI.CNL RCNT. CNL PA~E. -999.250 4. g 96 -999.2 50 -999.25!0 -999.250 -999-250 -999.250 -999'2S0 4. 510 -999. 250 -g 99.250 '-999.250 -999' 250 - g go. 250 -999. 250 5.B¢3 -999.250 -999.25'0 -999.250 -999.250 -999.250 -999.250 3.858 -999.250 -999.250 -999.250 -999.2~0 -999.250 -999'250 4.230 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.066 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.212 -999.250 -999.250 -999.250 -999.250 IS TAPE 'V'ERIFICATION L:.T. STING CHLUMBERGER ALASKA COMPUTING CENTER RCFToCNL -999. 250 CNTCoCNL CALI.CNL -999.250 TENS.CNL DEPT. SP.DIL R HOB. FDC CALI.~DC T NPH. CNL ~ RCFT' CNL C AL I. C N L 6400-000 ILO.DIL -20.563 GE.OIL -999.250 DRHD.FDC -999.250 GR.FDC -99:9 - 250 'T N R A o .C NL -999. 250 CNTCoCNL -999.2:50 TENS.CNL DEPT. S P. D I L RHO~. FDC CALI.FDC TNPH.CNL RCFT. CNL C A L I' C N ~L 6300.000 ILO.OIL -40.563 GR. OIL -999. 250 DRHO.FOC -999. 250 GR.FOC -999.250 TNRA.CNL -99'9.250 CNTC.CNL -999.25,0 TENS.CNL D EPTo S P. D ! L R H 08. F D C CALI.FOC TNPH.CNL RCFToCNL C ,6LI. CNL 6200 - 000 I :L O. D I ~L -29.813 GR.OIL -999° 250 ~RHO. FOC -999. 250 GR. FDC -999.250 TNRA.CNL -999.250 CNTC.:CNL -999. 250 TENSoCNL DEPT. SP.DIL RHOB.FDC C ALI. FDC T NPH. CNL RCFT.CNL CALI.CNL 6100.000 ILO.OIL -.27.0¢7 GR.DIL -999.250 DEHO.FDC -999.250 GR. FDC -999.250 TNRA.CNL -999.250 CNTC.CNL -999.2150 TENS.CNL DEPT.. SP.DIL RHOB.FOC CALI. P.DC TNPH.CNL RCFT.CNL CALI.CNL 6000.000 ILD. DZL -34.531 GR.DIL -999.250 DRHO.FDC -999.250 GR.FDC -999.250 TNRA.CN'L -999.250 CNTC.CNL -999.250 TENS.CNL DEPT. SP.DIL RHOB.FDC CALI.FDC TNPH.CNL RCFT.CNL CALI.CNL 5900.000 ILO.OIL -62.656 GR.DIL -999.250 ORHO.FDC -999.250 GR.FDC -999.250 TNRA.CNL -999.250 CNTC.CNL -999.250 TENS.CNL DEPT. SP.DIL RHO$.FDC CALI.FDC 5800.000 ILD.DIL -47.906 GR.DIL -999.250 DRHO.mDC -999.250 GR.FDC 1-NOV-lO89 lO:O0 '- 999.250 C F T 'C. C N L -999. ~250 G R. C S G 2.369 ILM. OIL 125. 313 TENS.OIL -999.25.0 FFDC.FDC -999.250 TENS.FDC - g 99.2:50 N P O R, C N L -999.250 CFTC.CNL -999.250 GR.CSG 3. 129 ILM. DIL 1[1.250 TENS.OIL -ggg. 250 FFOC.FDC -999o 250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 ' GR.CSG -999'250 -999. 250 .2.397 3 ~.g O. 000 -999.250 -999.250 - 999.250 - 9'9 g. :Z 50 -999.250 3. ,235 3464. 000 -999.250 -999.250 - ~ 99. :Z 50 - 99 '9.250 -999.2.50 3.820 ILM-DIL 3.908 1[5.500 TENS.OIL 3394.000 '-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 -999.250 3.370 I'LM.OIL 91.62S TENS.OIL -999.250 FFD~C-FDC -999.250 TENS.FDC -999.250 NPDR.CNL -999.250 CFTC.CNL -999.250 GR.CSG 3.616 ILM.DIL 114.438 TENS.OIL -999.250 FFOC.FDC -ggg. 250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CN.L -999.250 GR.CSG 3.699 ILM.DIL 136.625 TENS.OIL -999.250 FFOC. FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999o 250 GR. CSG 3.518 ILM.DIL 127.B75 TENS.OIL -999.250 FFDC.FDC -~99.250 TENS.FDC 3.~16 3464°000 -999.250 -999.250 -999.250 -999.250 -999.250 3.645 315¢.000 -999.250 -999.250 -999°250 -999.250 -999.250 3.657 3214.000 -999.Z50 -999.250 -999.250 -999.250 -999.250 3.563 3264.000 -999.250 -999.250 GR. CN:L T E N S. C S G S FLU. OIL D PM I. FO C NFDC.FDC NPHI.CNL R C N T. C N L G R. CNL TENS.CSG SFLU.DIL DPHI. ~mOC NFOC. FDC NPHI.CNL RCNT .CNL GR .CNL TENS.CSG SFLU.OIL DPHI.FDC NFDC. FDC NPflI.CNL RCNT. CNL GR .CNL TENS.CSG SFLU.DIL DPHI. FDC NFDC. FDC NPHI.CNL RCNT.CNL GR. CNL TENS.CSG SFLU.OIL OPHi. FOC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU. DIL DPMI.FDC N~DC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.~DC NPHI.CNL PAGE -999.250. -999,250 2.336 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 3.219 -999. 250 -999- 250 -999.250 -999.250 -999.250 -999.250 3. 972 -999'250 -999-250 -999.250 -999.250 -999. 250 -999.250 4.053 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.753 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.873 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.667 -999.250 -999.250 -999.250 IS TAPE VERIFICATION LISTING CHLUM'BERGER aLASKA COMPUTING CENTER TNPH.CNL -999.250 'TNR~.CNL RCFT-CNL -999.250 CNTC'CNL CALI.CNL -999.250 TENS.CNL D EP'T. $700.000 ILO.OIL SP,.O!L -56.750 GR.DIL RHOB.. FDC -999.250 DRHO.FOC CALI. FDC -999.250 GR.FOC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.2!50 CNTCoCNL C AL[.CNL -9919. 250 TENS.CNL DEPT. SP. DIE RHOB. FOC CALI.FOC TNPH.CNL RCFT. CNL CALI.CNL DEPT. SP. OII R H O B. F O C C AL I,. FO C T NPH. CNL RCFT.CNL C ALI. CNL DEPT. SP.OIL RHOB.FDC CALI.FDC TNPM. CNL RCFT.CNL CALI.CNL DEPT. SP.DIL RHOB.FDC CALI. FDC TNPM. CNL RCFT.CNL CALI.CNL DEPT. SP.DIL RHOB.FDC CALI.FDC TNPHoCNL RCFT.CNL CALI.CNL 5600.000 ILO.OIL -43.000 GR.DIL -999.250 ORHO.FOC -999. 250 G'R.FOC -999.250 TNRA.CNL - g 99.2 S 0 C N T C. C N L -999. 250 TENS'CNL 5500.000 ILO. OIL -~9.000 GR.DIL -999.250 ORHO.FOC -999.250 GR.FOC -999.250 TNRA.CNL -999.250 CNTCoCNL -999.250 TENS.CNL 540'0. 000 ILD.DIL -ZO.O00 GR.DIL -999.250 DRHO.FDC -999.250 GR.FDC -999.250 TNRA.CNL -999.250 CNTC.CNL -999.250 TENS.CNL 5300.000 ILO.OIL -5.750 GR.DIL -999.250 DRHO.FOC -999.250 GR.FDC -999.250 TNRA.CNL -999.250 CNTC.CNL -999.250 TENS.CNL 5200.000 ILO.OIL -29.234 GR.OIL -999.250 DRHO.FDC -999.250 GR.FDC -999.250 TNRA.CNL -999.250 CNTC.CNL -999.250 TENS.CNL 1-NOV-1989 10:00 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL --999.250 -9'99. 250 GR. CSG -999. 250 2 - 350 I L M. D I L 2.461 161,.125 TENS.OIL 3264.000 -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 -999. 250 1. 733 ILM'DIL 126.250 TENS.OIL -999.2.50 FFDC.FDC -999. 250 TENS. FOC -999.250 NPOR.CNL -999. 250 CFTC.CNL -999. 250 GR.CSG 1. 820 ILM. DIL 10.2.750 T E N S - D I L - 999.250 F F O C. F O C -999.250 TENS.FOC -999. 250 NPOR.CNL -99'9.250 CFTC.CNL -999. 250 GR.CSG 4.219 ILM'DIL 146.625 TENS.DI~L -999.250 FFDC.FOC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG 1.799 3134.000 -999.250 -999.250 -999.250 -99 g o 250 - 9 g 9.250 1.815 3260.000 -999.,250 -999.250 -999.250 -999.250 -999.250 4.222 3220. 000 -999. 250 -999.250 -999.250 -999. 250 -999.250 3.361 ILM.OIL 3.26~ Bl.000 TENS.OIL 3190.000 -999.250 FFOC. FDC -999.250 -999.250 TENS.FDC -999.Z50 -999.250 NPOR.CNL -99'9.Z50 -999.250 CFTC.CNL -999o250 -999.250 GR.CSG -999.250 3.166 ILM.DIL 3.120 92.125 TENS.OIL 3100.000 -999.250 FFOC. FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPDR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG -999.250 R C NT. C NL GR. CNL TENS.CSG SFLU.DIL DPHI.FOC NFOC.FDC NPHI..C'NL RCNT.CNL GR'CNL TENS.CSG SFLU.DIL DO~HI.FDC NFOC..FDC NPHi.CNL R'CNT. C~NL GR.CNL TENS.CSG SFLU'OIL OPHI.FOC NFDC.FDC N, PHI.CNL RCNT.CNL ~ GRoCNL TENS.CSG SFLU. DIL DPHI'FOC NFOC.FDC NPHI.CNL ECNT.CNL GR'CNL TENS.CSG SFLU. DIL DPHI.FDC NFOC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFOC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG -999. -999.250 -999.250 ,-999.250 -999.250 -999. 250 -999. 250 -999. 250 -'999. 250 2.265 - 999.250 -999.250 -999. 250 -999-250 -999.250 -999'250 2.0~7 -999 . 250 -999.250 -999.250 -999.250 -999.250 -999.250 4.285 -999.250 -999. 250 -999.250 -999.250 -999'250 -999.250 2.893 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.492 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 IS TAPE VERIFICATION LISTING ,CHLUMBERGER ALASK,~ COMPUTING CENTER D E P T. 510 O- 000 I t D. D I L SP'DIL -40. 250 GR,DIL RHDB. FDC -999.250 DRHO.FDC CALt. FDC -999. 250 GR.FDC TNPH. CNL -999.o 250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C AL ! o CN L - 999.250 T E NS. C NL D E P T. 5000.00 O I L O. O I L S~.DIL -45-750 GR.DIL RHOB.FDC -999. 250 DRHO.,FOC CALI.FOC -999.250 GR. FOC T NPH,. CNL -999.2 50 'TN:RA. C NiL RCFT.CNL -999.250 CNTCoCNL CALI.CNL -999.250 TEN$oCNL DEPT. 4900'000 ILO.OIL SP.DIL -29.250 GR'DIL RHO~'FDC -9'99.250 DRHO.FDC C AL I.o FD'C - 999' 250 GR. FOC TN:PHoCNL -999.250 TNRA.CNL RCFT,CNL -999.2S0 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 4800..000 ILO.OIL SP'OI1 -27. Z$O GE.OIL. RHOB.FDC -999,250 DRHO.FDC C ALI,.FDC -999.2 50 GR.FOC TNPfl. CNL -999.250 TNRA.CNL 'RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999'250 TENS.CNL DEPT. ~,700.000 ILO.OIL SP.D[L -35.03! OR.OIL RHOB.FOC -999.250 DRHO.FDC CALI.FDC -999.2 50 GR. FOC TNPH. CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 4600.000 ILO.OIL SP.DIL -31.984 OR.OIL RHOB.FDC -999.250 DRHD.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 DEPT. 4500. 000 ILO. OIL SP.DIL -31.250 GR.OIL RHOB. FOC -999.250 DRHO.FDC C ALI. FDC -999.2 50 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT, CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL i-NDV-!989 10:00 2,889 ILM. DIL 95.688 TENSoDIL -999.250 FFOC.FOC -999.250 TENS.,FDC -999.25{) NPOR.CNL -999. 250 CFTC.CNL -99'9.2.5'0 GRoCSG 3.37! ILM.DIL 92,.625 TENS.OIL -999°250 FFDC.FOC -999.250 TENS.FDC -999,250 NPOR.CNL -999.2:50 CFTC.CNL -999. 250 GR.CSG 2.904 ILM.OI~L 105.438 TENS,OIL -999.250 FFDC. FOC -999.250 TENS.FD'C -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GRoCSG ' 3.171 ILM.DIL 100-250 TENS.OIL -999.250 FFDC.FDC -999..250 TENS.FOC -999..,250 NPORoCNL -999°250 CFTC.CNL -999.250 GR.CSG 2.855 3004.000 ,-999.250 -999,250 -999,250 -999.250 -999.2.50 3.334 2964'000 '-999.250 -999.250 -999.250 - 999.2 S 0 -999.250 2.87 :! 282 O. 0~00 -999.250 -999.250 -999,250 --999.250 -999.25,0 3.033 2964. 000 -999. 250 -999.250 -999.250 -999°250 -999.250 3.257 ILM.DIL 3.215 76.$63 TENS.DIL 2870.000 --999.250 FFDC. FOC -999°250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999. 250 CFTC.CNL -999. 250 -999. 250 GR.CSG -999.250 3.375 ILM.OIL 3.270 99.688 TENS.OIL 2670.000 -999.250 FFDC.FDC -999.250 -999.250 TENS. FDC -999.250 -999.250 NPDR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999. 250 GR.CSG -999. 250 3.840 ILM.DIL 122.68B TENS.OIL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -'999.250 GR.CSG 3°790 2684.000 -999.250 -999.250 -999.250 -999.250 -999.250 SFtU.OIL DPHI. FOC N FDC. FDC NPH I. CNL R CNT.. CNL GR.CNL TENS. C SG SFLU.DIL D P H FI . FO C NFOC.FDC NPHI.CNL R C N T - C N L 'G R. CNL T'ENS .C.SG SFLU. OIL DPHI. FDC NFDC.FDC N P H I . C NL RCNT, CNL GR. CNL TENS.CSG SFLU.OIL D PM I .. FOC NFDC.FDC NPHI. CNL RCNT.CNL GR. CNL TENS.CSG SFLU.OIL DPHI.FDC NFOC-FDC NPHI.CNL RCNT.CNL GR .CNL TENS.CSG SFLU.DIL DPHI.FDC NFOC. FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG PAGE: 10 2.808 -999.250 -999.250 -999.250 -999. 250 .-999.250 - 999 . 250 3.480 -999.250 -999.250 -999.250 -999.250 -999.2,50 -999.250 3.i036 -999'250 -999.250 -999.250 -999.250 -999.250 -999.250 2.624 -999.250 -999,250 -999.250 -999.250 -999.250 -999.2!50 3.343 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.330 - 999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.80! -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER DEPT. 4400.000 ILOoDIL SP.DIL -35.500 GR..OI:L RHOB'FDC -999.250 DRHO.FDC CALI.FDC -999.25:0 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 4300. 000 ILO. OIL SP. OIL -47.21'9 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. 4200.000 ILD. D!L SP. OIL -44. 000 GR. OIL R H 0 B. F D C - 999.25. 0 0 R H 0. F D 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 DEPT. 4100. 000 ILDoOIL SPoOIL -55. 500 GR.DIL RHOB.FDC -999.250 DRHO.FDC CALI.FOC -999.250 GR.FDC TNPM.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 4000. 000 ILO. OIL SP. OIL -62.625 GR.DIL RHOB.FDC -999.250 ORHO.FDC CALI.FOC -999. 250 GR. FDC TNPH. CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CAL!.CNL -999.250 TENS.C'NL DEPT. 3900.000 ILD. DIL SP.DIL -60.375 GR.DIL RHOB.FDC -999.250 DRHO.FDC CALI. r:OC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 3800. 000 ILD. OIL SP.DIL -68.750 GR.DIL RHOBoFDC -999.250 DRHO. FDC CALI. FDC -999. 250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -9'99.250 CNTC.CNL 1-NOV-1989 10:00 99. -999. - 999. -999. -'999. - 9'99. 99. - 999. -999. -999. -999. - 9:99. . 96. -999. -999. -999. - 999. -99 9. 99. -999. -999. -999. - 999. -999. 3~ 100. -999. -999. -999. -999. -999. . 90. -999. -999. -999. -999. -999. 85. -999. -999. -999. -999. 16¢ 188 250 250 250 250 250 695 ! 88 250 250 25.0 250 250 401 1:88 25O 250 Z SO 250 Z50 86.5 125 25.0 250 250 250 069 063 250 25O 250 250 25O 061 625 250 250 25O 990 625 250 250 Z50 250 I LM. :D IL T E N S- O ! :L F F O C' F D C TENS. FDC NPOR. C NL C F'T C. C N L GR.CSG ILM.DIL 'T E NS. O IL FF DC. F DC TENS. FDC NPOR.CNL C F T C . C NL GR. C :SG ILM.DIL TENS.OIL FFDC.FDC 'TE NS. F OC NPOR'CNL CFTC.CNL G .R. C S G ILM.DIL TENS.OIL FFOC.FOC TENS.FOC NPOR. CNL C F T C. C N L GR.CSG ILM.OIL TENS.OIL FFDC.FOC TENS. FDC NPOR.CNL CFTC.CNL GR.CSG ILM. DIL TENS.OIL FFDC.FDC TENS.FDC NPOR.CNL CFTC.CNL GR.CSG ILM.DIL TENS.OIL FFOC.FDC TENS.FDC NPOR.CNL CFTC.CNL 3.000 .2694o000 -999.250 -999.250 -999.250 -999.250 -999..250 3.67I 2484.000 -99:9.250 -999.250 -999.250 -999.2S0 -999.2510 3-263 2:504.000 -999.250 -999.250 -999.250 -999.250 - 999.25 0 2.749 247¢.000 -999.250 -999. 250 -999. 250 -999.250 -999.250 2.913 2354.000 -999.250 -999.250 -999.250 -999.250 -999.250 4.685 2554.000 -999.250 -999.250 -999.250 -999.250 -999.250 2.684 2290.000 -999.250 -999.250 -999.250 -999.250 SFLU.DIL DPHI.FDC NFOC.FDC NPHIoCNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL D P H I. F O C NFDC. FDC NPHI. CNL RCNT.CNL G R - C NL TENS,. CSG SFLU.DIL DPHIoFDC NFOC. FOC NPHI. CNL RCNT.CNL GR. CNL T=~NS.CSG SFLU.DIL OPHI .FDC N F D C. F O C NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.. FDC NFOC. 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 NPHI.CNL RCNT.CNL GR .CNL PAGE: tl 2.835 -999.250 -999.250 -999.250 -999'250 -999.250 -999.250 3.609. '-999.250 -999.250 -999.250 -999.25'0 -999.250 -999.250 3.269 -999.2 .50 -999.250 -999.250 -:999.250 -999.250 -999°250 2.752 -999.25~0 -999'250 -999'250 -999.250 -999.250 -999.250 2.947 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 4.813 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.014 -999.250 -999.250 -999.250 -999.250 -999.250 ,IS TAPE VER ;C H L U M B E R G E R CALI.CNL DEPT. SP.DIL RHOB:. FDC C ALI. Foe T NPH. CNL R CFT. CNL C ALI o CNL DEPT, SP.OIL RHOB.FOC CALI,FDC TNPH.CNL RCFT.CNL C~LI. CNL DEPT. SP. OIL RHOB.FDC C ALI, FDC TNPH.CNL RCFT.CNL CALIoCNL DEPT,. SP. DI'L RHOB. FDC C~L[oFDC TNPH.CNL R C F T. C N L CALZ.CNL DEPT. SP, DIL RHOS.FDC C~LI.FDC TNPH, CNL RCFT.CNL CAL!.CNL DEPT. SP.DIL RHOB.FDC C :al I. FDC TNPH.CNL RCFT.CNL CAL':. CNL DEPT. SP. OIL RHOB.FDC CALI.FDC TNPH,CNL :FICA, TIDN LISTING A~LASKA COMPUTING CENTER -999. 250 · TENS.CNL 3700. 000 ILO.OIL -63. 594 GR.DIL -999.250 DRHO.FOC -999.2 50 GRo FDC -999.250 TNRA.CNL -999.250 CNTC'CNL -999.250 TENS.CNL 3600.000 ILO.OIL -76. 313 GR.DIL -999.250 DRHO.FDC -999. 250 GRoFDC -999. 250 TNRA.CNL -ggg. 250 CNTC. CNL -999-250 TENS-CNL 35 00.000 I L D. D I :L -67.688 GR.OiL -999.250 DRHO.FOC -999.250 GR.FOC -999.250 TNRA.CNL -999.250 CNTC.CNL -999.250 TENS.CNL 34.00.~000 ILO. OIL -75.063 GR.OIL -999.250 DRHD.FOC -999.250 GR.FDC -999,250 TNRA,CNL -999.250 CNTC.CNL -999.250 TENS.CNL 3300.000 ILO. [}IL -88.813 GR.DIL -999.Z50 DRHO.FDC -999.250 GR.FDC -999.25.0 TNRA.CNL -999.250 CNTC.CNL -999.250 TENS.CNL -999- 94. - 999. -999. -999. -999. - g 99. 1-NOV-:IgB9 10=00 . 116. -999. -999. -999. - 99 g. - 999. G R. C S G 223 ILM.DIL 625 TENS.OIL 25;0 FF:OC,.FDC ZSO TENS. FDC 250 NPOR.CNL 250 CFTC.CNL 250 G R o C $ G 398 ILM. DIL 375 TENS. DIL 250 FFDC,FDC 25:0 TENS.FOC 250 NPO:R.CNL Z50 CFTC.CNL 250 GR.CSG 5.69~ -999. 250 -999. 250 -999. 250 -ggg. 250 -999.Z50 101. -999o -999. -999. -999. - 999. B2. -ggg. -999. -999. -999. -999. 3200.000 ILD.DIL -999. -999.250 GR.DIL -999. -999.250 DRHO.FDC -999. -999.250 GR.FDC -999. -999.250 TNRA.CNL -999. -999.250 CNTC.CNL -999o -999.250 TENS.CNL -999. 3100.000 ILD.DIL -999. -999.250 GR.DIL -999. -999.250 DRHO.FDC -999. -999.250 GR.FDC -999. -999.250 TN~A.CNL -999. 329 B75 250 250 250 250 250 716 188 Z50 250 25.0 250 250 250 2.50 250 250 25O 2.50 2.5O 250 250 2.50 250 250 ILM.DIL TENS. D I l F F DC. F g C TENS.FDC NPOR.CNL C F T C. C N L SR.CSG ILM. DIL TENS.OIL FFDC.FOC TENS.FDC N P 0 R. C N L CFTC.CNL GR.CSG ILM.OIL TENS.OIL ~FOC.FDC TENS.FDC NPDR.CNL CFTC.CNL GR.CSG ILM.DIL TENS.DIL FFOC.FDC TENS.FOC NPOR.CNL CFTC.CNL GR.CSG ILM.DIL TENS.OIL FFDC.FDC TENS. FDC NPOR.CNL -999. 2234. -999° -999. ,-999. -999. -999. 3. 2164. -999. -999. -999. -ggg. -999, 2170. -999. -999. -gO9. -999. -999. 2134. -999. -999., -999. -999. -999. 2124.. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. 250 02. 3 000 250 250 250 2. 50 2:50 000 250 250 Z50 250 250 369 000 2.50 250 .250 Z50 250 053 000 250 250 2. 50 250 ;?50 414 000 ;?50 25O 2.50 250 250 250 Z50 250 250 2.50 250 563 ;?50 250 2. 50 250 250 TENS'CSG SFLU,DIL DPHI.FOC NFDC. FO C NPHI.C:NL R C N T. C N L G R. CNL TENS.CSG SFLU. OIL DPHI.FOC NFOC.FOC NPHI-CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL D PH I. ~:D C NFDC.FDC N PH I. CNL R C N T. CNL GR. CNL TENS.CSG SFLU.OIL OPHI.FDC NFDC' FDC NPHI.CNL RCNT.CNL GR-CNL TENS.CSG SFLU.DIL DPHI.FDC NFOC.FDC 'NPHIoCNL RCNT.CNL GR.CNL TENS.CSG SFLU.OIL DPHI.FDC NFOC.FDC NPHI .CNL RCNT.CNL GR.CNL TENS.CSG SFLUoDIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL PAGE: 12 -999.250 3.583 -999.250 -999.2S0 -999. 250 -999.250 -999' 250 -999'250 3.152 -999. 250 -999.2.50 -999.250 -999.250 -999,250 -999.250 5.319 -999.250 -999.250 -999.250 -g 99. 250 -999.250 -999.250 3.87B - 999 -250 -999.250 -999.250 - 999.250 -ggg.250 -999.250 4.651 -999.250 -999. 250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 -999.250 2080.000 -999.250 -999.250 -999.250 -999.250 -999.250 IS TAPE VERIFICATION LISTING CHLUMBE'RGER ALASKt COMPUTING CENTER RCFT.CNL -999.250 CNTC.CNL CALIoCNL -999.250 TENS.CNL DEPT. 3090. 000 ILO. OIL SP.OIL -999. ~:50 GR. OIL RHOB. FDC -:999.250 DRHO.FOC C AL I. F O C - 9 g g. 2 50 G R o F O C TNPH.CNL -999.250 TNRi~.CNL R C F T. C N L - g 99.250 C iN TC. C NL CALI.'CNL -999.250 'TENS.CNL DEPT. 2900,.000 ILO-OIl SPoOIL -999..250 GR.OIL RHOB.FDC -999.250 DRHO.FDC CALI. FOC -999. 250 GR.FOC TNPH.CNL -999. 250 'TNRA.CNL RCFT.CNL -999. 250 C:NTC. CNL CALI.CNL -999.250 TEN:S.CNL OEPT. 2800. 000 ILO. OIL SP. OIL -ggg-250 GR.OIL RHOB.FDC -999.250 ORHO.FOC CALI.FDC -9:99. 250 GR.FDC TNPM.CN'L -999.250 TNRA.CNL RCFT.CNL -999.2 50 CNTC.CNL CA'LI.CNL -9'9'9.250 TENS.CNL DEPTo 2700.000 ILO-OIL SP.DIL -999.250 GR.'OIL RHOB. FDC -999.2~0 DRHOoFDC CALI.FDC -999.250 GR.FOC TNPH.CNL -999.250 TNRA.~CNL RCFT. CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. Z600.O00 ILO.OIL SP.DIL -999.250 GR.DIL RHOB.FDC -999.250 DRHO.FDC CALI.FOC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 2500.000 ILO.OIL SP. DIL -999.250 GR.DIL RHOB.FDC -999.250 DRHO.FDC CALI.FOC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 2400.000 ILO.OIL SP. DIL -999.250 GR.DIL RHOB.FOC -999.250 DRHO.FDC CALI.FDC -999.250 GR.FOC 1-NGV-1989 10:00 -999. 250 CFTC.CNL -999.250 -999.250 GR.CSG 42.094 - 999.25 0 I L M. D ! L -'999. 250 TENS.OIL -999.2!50 FFOC.FOC -999.250 TENS.FOC -999. 250 NPORoCNL - 999 o 250 C F'T C . C N L -999.250 GR.CSG -999. 250 -999. 250 -999.250 -999.25:0 -999'250 -999. 250 3 6.125 -999. 250 ILM' OIL -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. '-999.:250 CFTC.CNL -999.'250 -999.250 GR..CSG 67.500 -999.250 ILM. DIL -999.250 TENS.OIL -999.2'50 FFOC.FOC -999.250 TENS.FDC -999,.,250 , NPOR"CNL -999.250 CFTC.CNL -ggg. 250 GR.CSG -999. 250 -ggg.zsO -99 9. 250 - 999.250 -:999.250 -999.25,0 51o 4.38 -999.250 ILM. DI~L -999.250 -999.250 TENS'OIL -999.o 250 -999.250 FFD.C.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999. Z50 GR.CSG 43.344 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 FFDC.FOC -999.Z50 -999.250 TENS.FDC -999.250 -999. 250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 50.000 -999.250 ILMoDIL -999.250 -999.250 TENS.OIL -999.250 -999. 250 FFDC. FDC -999. 250 -ggg. 250 TENS. FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999. Z50 GRoCSG 49.531 -999.Z50 ILM. DIL -999.250 -999.250 TENS.OIL -999.250 -999.Z50 FFDCoFDC -ggg.zso -:999.250 TENS.FDC -999.250 GR.CNL TENS'CSG S FLU. OIL DPHI.FOC NFDC. FDC NP HI . CNL R C N T. C N L GR.CNL TENS.'CSG SFLU. OIL OPH !. FDC ~ N FDC. F DC : NPHI.CNL R CNT. CNL GR.CNL TENS.CSG SFLU. DIL OPHI.FDC NFDC.FDC NPHIoCNL RCNToCNL GR-CNL TENS.CSG SFLU. DIL DPHI.FOC NFOC.FDC NPHI.CNL RCNT.CNL G~.CNL TENS.CSG SFLU.OIL DPHI.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.OIL DPHI.FDC NFDC.mOC NPHI.CNL PAGE,: I3 -999.250, 1930.000 -9'99..250 -999-250 -999'.250, -999.250 -999.250 -999.250 1870,000 -999.250 -9 g 9.250 -999.25:0 -999.250 -999'250 -999' 250 1BB5.O00 -999.250 -999.25,0 -999'25'0 -999.250 -999.250 -999.250 1750.000 -99:9.250 -999.250 -999.250 -999.250 -999.250 -999.250 1730.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1775.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1760.000 -999.250 -999.250 -999.250 -999.250 · IS 'TAPE VERIFICATION LISTING ;CHLUMBERGE!~ ALASKA COMPUTING CENTER TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTCoCNL CALI.CNL -999.2:50 TENS.CNL DEPT. 2300.000 ILO'OIL SP.OIL -999. 250 GR.DIL RHOO.FDC -999.2...50 ORHO.FOC CALI.FDC -999. 250 GR.FDC TNPH.CNL -999.250 TNRA'CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TEN:S.CNL DEPT. 2200.000 'ILO. DIL SP.DIL -9 99.250 GR.OIL RHOB.FDC -999.250 DRHO.FOC 'C ALI. FDC -999.250 GR. FDiC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL '-999.250 CNTC.CNL CALI.CNL -999.2~,0 TENS.CNL D E P T. 2100.000 I L D. D I L SP.DIL -999.250 GR.OIL RH:DB. FDC -999.2'50 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. 2000. 000 ILO.OIL SP.OIL -999.250 GR.OIL RHOB.FDC -999.250 DRHO.FOC CALI.FDC -999.250 GR.FOC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 1900.000 ILD.DIL SP. DIL -999.250 GR.DIL RHOB.FDC -999.250 DRHO.FOC 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. 1BO0.O00 ILD.DIL SP. OIL -999. 250 GR. OIL RHDBoFDC -999.250 DRHO.FDC C AL I. FDC -999.250 GR.,~DC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL 1-NOV-lO89 10:00 -999.250 NPOR.CNL -999.250 -999. :250 CFTC.CNL '-999. 250 -999.25.0 GR.CSG 57.781 -999.250 ILM. D'IL -999.250 -999. 250 TENS. DIL -999. 250 -999' 2.50 FFO'C. FDC -99'9.250 -999.250 TENS. FOC -999.250 -999. 250 NPOR.C. NL -999. 250 -999.250 CFTCoCNL -999. 250 -999.250 GR.CSG 42. 500 -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 GRoCSG -999.250 -999.250 -999.250 -999. 250 -999. -999' 250 /+ B. 6 B B -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 4!.094 -999'250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 FFOC.FDC -999.250 -999°250 TENSoFDC -999.250 -999.250 NPOR.CNL -'999.250 -999.250 CFTC.CNL -999.25.0 -999. 250 GR. C SG 24. 516 -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 27.531 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 ~FDC.FOC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 57.125 RCNT.CNL GR.CNL TENSoCSG SFLU. OIL OPHI. FDC NFDC. FDC NPHI .CNL R C N T. C N L G R. C NL TENS.CSG S FLU'. DI L DPHI. FDC NFDC. FDC NPHI.CNL RCNT.CNL G R. C NL TENS.CSG SFLU.OIL DPHI.FDC NFDCoFDC NPHI.C'NL RC~T.CNL GR"CNL TENS.CSG S FLU. OIL 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 SFLU.DIL DPHI.FDC NFDC.FOC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG PAGE: -999.250 -999.250 t655.000 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 1720.000 -999-250 -999.250 -999-250 -999.250 -999.250 -999.2:5,'0 1605.000 -999.250 -999.250 -999.25:0 -999.250 -999.250 -999.250 1695.000: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1605.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1575'000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 15~5.000 !S TAPE YERIFICATION LISTING CHLUNBEtGER ~LASKA COMPUTING CENTER D E PT. 1 ? 00. ,000 I L D' D I L S P. DI'L -99'9.250 GR. D IL R H'O B. F O C - 999. Z 50 0 R H'O .. F O C C AL I. F O C - g 9 g. 250 G R. F O C TNPH.CNL -999.25.0 'TNRAoC. NL RCFT.CNL -999.250 :CNTC.CNL CALI.CNL -999'. 250 TENS.CNL DEPT. SP.OIL RHOBoFDC C A'L I. FOC TNPH' CNL RCFT.CNL C AL I. C NL O EPTo SP.OIL RHOB.FDC C AL I' FO C TNPH. CNL RCFT.CNL C ,~L I. C'N L DEPT.. SP. OIL RHOB.FDC C~LI.FDC TNPH. CNL RCFT.CNL CALI.CNL DEPT.. SP.DIL RHOB. FDC CALI.FOC TNPH.CNL RCFT.CNL C,~LI.CNL DEPT. SP.DIL RHOB.FDC CALI.r:OC TNPH.CNL RCFT.CNL CALt. CNL D~PT. SP.DIL RHO~.FDC CALI.FDC TNPH.CNL RCFT.CNL CAL! .CNL -999. -999o -999. -999. - 999. - 999. -999. ! 60 O- 000 I L O. D Z L - 999. - 9 g 9 ' 2 50 G R. O I L - 99 9. -999.250 DRHO.'FDC -999. -999.250 GR.FOC -999. -999.250 T:NRA.CNL '-999. -999-250 CNT'C.CNL -999. -g 99.250 'T f N $. C NL - 99 g. 1500. 0 '00 I L O. D IL - 99 g:. -999.250 GR.OIL -999. -999.250 DRHO. FDC -999. -999- 250 GR. FOC - 999. -gg9.25'0 T'NRA. ICNL -999. -999-250 CNTC'CNL -9gg. -999-250 TENS.CNL -999. 1400.000 ILD'DIL -999. -999.2 50 GR. O IL -999I. -999.,250 ORHO.FOC -999.. -999.250 GR.FDC -999. -999.250 TNRA.CNL -999. -999. 250 CNTC.CNL -999. -999.250 TENS.CNL -999. !300.000 ILO. OIL -999. -999.250 GR.DIL -999. -999.250 ORHO.FDC -999. -999. 250 GR.FOC -999. -999. 250 TNRA.CNL -999. -999.250 CNTC.CNL -999. -999.250 TENS.CNL -999. 1200.000 ILO.OIL -999. -999.250 GR.DIL -999. -999.250 ORHD.FDC -999. -999.250 GR.FDC -999o -999. 250 TNRA.CNL -999. -999.250 CNTC.CNL -999. -999.250 TENS.CNL -999. t-NOV-t989 10:00 1100.000 ILO.OIL -999. -999.250 GR.DIL -999. -999.250 DRHO.FDC -999. -999.250 GR.FOC -999. -999.250 TNRA.CNL -999. -999.250 CNTC.CNL -999. -999.250 TENS.CNL -999. 250 ILM.OIL -999.250 250 TENS.OiL --999.250 250 FFDC.FOC -999.250 250 TENS.FDC -999.250 250 NPOR.CNL -999..250 250 CF'TC.CNL -999. 250 250 GR.CSG 47.531 250 250 250 250 250 250 250 250 250 250 250 250 250 Z 50 250 250 2.50 2:50 25O 25O ;?5O gEO 250 ;250 ;?50 250 250 250 Z50 250 250 250 250 250 250 250 250 ILM.OIL T E NS. D IL FFDC.FDC TENS- FOC NPOR-CNL C F T:C. C NL GR. C SG ILM. OIL TENS.OIL F F DC. FDC TENS.FDC N P 0 R. C N L CFTC. CNL GR.CSG ILM.OIL TENS.OIL FFOC. FDC TENS. F DC NPOR.CNL C F T C. C NL GR.CSG ILM.DIL TENS.OIL FFDC.FDC TENS.FDC NPOR.CNL CFTC.CNL GR.CSG ILM.DIL TENS.OIL FFDC.FDC TENS.FOC NPOR.CNL CFTC.CNL GR.CSG ILM.DIL TENS.OIL r:FDC. FDC TENS.FOC NPOR.CNL CFTC.CNL GR.CSG -999.2,50 -99.9.250 -99 9.250 -g 99..250 -999.25.0 -999:. 2:50 32. ~69 -ggg. 250 -999.250 -99 9.250 -999.250 -999. 250 -999°250 28.609 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 44.125 -999.250 -999.250 -999. Z50 -999.250 -999.250 -999.250 29.1¢! -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 36.469 -999.250 -999.250 -999.250 -999oZ50 -999.250 -gog. Z50 2B.4ZZ SFLUo git DPHI.FDC NFOC. FDC NPHI. CNL RCNT.'CNL G R. CNL TENS.CSG SFLU.OIL DPHI. FDC NFOC.FDC NPH I. C NL RCNT.CNL G R. C NL TENS.CSG SF:LU. OIL DPHI.FOC NFDC.FDC N PH I. CNL RCNT.C:NL GR.CNL TENS.CSG SFLU.DIL DPHI. FDC NFDC.FOC N P H I. C'N L RCNT. CNL GR.CNL T'ENS.CSG SFLU.DIL DPHI.FOC NFOC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.OIL DPHI.FDC NFOC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU. OIL D~HI. FDC NFDC.FOC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG PAGE:: 15 -999.250 -999.250 -999.25:0 -999.250 -999'25,0 -999°250 I510.000 -999.250 ':-999.250 -999°250 -999.250 -999.250 -999.250 1485.000 -999.250 -999.250 -999. 250 -999. 250 -999. 250 -999.250 1410.000 -999.250 -999-250 -999.250 -999.250 -999.250 -999.250 1335.000 -999.250 -999'250 -999.250 -999.250 -999.250 -999.250 1280.000 -999.250 -999.250 -999.Z5:0 -999.250 -999.250 -999.250 1250.000 -999.250 -999.250 -999.250 -999.250 -999.250 -ggg.zEO 1;?00.000 IS TAPE VERIFICATION LISTING CHLUMBERGER aLASKA COMPUTING CENTER 1-NOV-1989 I0:00 · PAGE: 16 DEPT. 1000.:000 I~LD.DIL SP.D~L -999.25~0 GR.DIL RHD~.FDC -999.250 DRHO.FOC CALI,.FDC -999.250 GR.FDC TNPM. CN'L -999.2!50 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALIoCNL -299.2,50 TENS.CNL D E P T. 995.500 I L 0. D I L SP.DIL -9'99.250 GR. OIL RHDB.FDC -999.250 DRHO.FDC CALl. 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 - 999.2.50 I L M' D I L -999. ID0 TENS.OIL - 99'9.250 F F DC. F D C -999.= 250 TENS. FDC -999.250 NPOR,'CNL -999.250 CFTC.CNL · -999. 250 GR.CSG - 999- 250 -999.250 -99 9.250 - 99 9.2 50 -999.250 -999.25,0 '~ 7.906 -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.Z50 NPOR.CNL -999.250 -999.250 CF'TC..CNL -999.250 · -999. 250 GR.CSG 39.031, FLU. O I L P H'I. F O C · NFDC. FDC NPH I. CNL RCN'ToCNL G R. C NL TENS.CSG SFLU.DIL DPMI.FDC NFDC. F.DC NPHI.CNL RCNT.CNL GRoCNL TENS.CSG -999.250 -999.250 ,-999'250 -999.250 -999.250 -999.250 11.75.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999°250 1215-000 ***~ FILE TRAILER FILE NaME : EDIT .0OI SERVICE : FLIC VERSION : O01AOZ DATE : 89/[[/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01AO2 DATE : 89/11/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE - EDZT.OO2 ARCg ALASKA, KUPARUK 2K-16 50-103-20115 INC. IS TAPE VERIFICATION LISTING CHLUMBERGER ALAS'KA COMPUTING CENTER ~l-NOV-1989 10=00 PAGE: 17 MAIN PASS LOG DA'TA @1.2" SAMPLE RATE DATA SAMPLED EVERY-,.1000 FEET DATA [iNCLUDED- TOOL EXTENSION TYPE USED FOC CNT-A/O/H .CNH TOOL NAME FORMATION DENSITY iCOMPENSATED 'NEUTRON TABLE TYPE : CONS TUN[ VALU DEFI CN ARCO ALASKA, INC. FN KUPARiUK WN 2K-16 APIN 50-103-20115 FL 144,' FNL & 94~ FEL SECT 11 TOWN ION RANG BE CO,UN NORTH SLOPE S'TAT ALASKA NATI USA WITN LOWEN/DIXON SON 548741 POAT MSL EPO FT O. LMF RKB APO FT 154. EKB FT 154. EOF FT 1:53. EGL FT 113. TOD FT 7850. STEM OEOF -4. COMPANY NAME FIELD NAME WELL NAME API SERIAL NUMBER FIELD LOCATION SECTION TOWNSHIP RANGE COUNTY STATE OR PROVINCE NATION WITNESS'S NAME SERVICE ORDER NUMBER PERMANENT DATUM LOG MEASURED FROM TABLE TYPE : CURV DEFI DEPT DEPTH CHANNEL NAME DPHI DENSITY POROSITY RH08 ~ULK DENSITY DRHO DELTA RHD FFDC FAR FDC COUNT RATE IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 1-NOV-1989 10:00 DEFI NFDC NEAR FDC COUNT R~TE CALI CALIPER GR GAMMA RAY TENS TENSION NPH! NEUTRON POROSITY TNPH THERMAL NEUTRON POROSITY TNRA CALIBRATED THERMAL NEUTRON RATIO NPOR NEUTRON POROSITY OUTPUT FROM ~N APPLICATION PROGRAM RCNT RAW CORRECTE~ NEAR THERMAL COUNTS RCFT RAW CO~RECTED FA~ THERMAL COUNTS CNTC CORRECTED NEAR THERMAL COUNTS CFTC CORRECTED 'FAR THERMAL COUNTS GR GAMMA RAY CALI CALIPER TENS TENSION PAGE: 18: ~ OATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ~ TYPE REPR COOE VALUE I 66 O 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.099 9 65 FT 11 66 12 12 68 13 66 0 1~ 65 FT 15 66 68 16 66 0 66 i ~ SET TYPE - CHAN ~ NAME SERV UNIT SERVICE API AP~ API API FILE NUMB NUMB SIZE REPR ID ORDER e LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS CHEX) DEPT FT 548741 GO DOHI FDH PU 548741 07 RHOB :DH G/C3 548741 07 DRHO FDH G/C3 548741 07 000 O0 0 2 i I ~ 68 890 01 0 2 i I 4 68 350 02 0 2 I 1 4 69 356 01 0 2 ' I ~ 68 O000OO0000 0000000000 00000~0000 O0000000OO IS TA. PE VERIFICATION LISTING 1-NOV-1989 10:00 CHLUMBERGER ALASKA COMPUTING CENTER PAGE:, 19 NAME SERV UNIT SERVICE API API API API FILE NUMB ID DROER ~ LOG TYPE CLASS MOO NUMB SAMP FFDC FOH CPS 545741 07 354 NFDC FDH CPS 548741, 07 354 CALI FOH IN 54874! 07 280 GR FOH GAP! 548741 07 310 TEN S F 0 H L ~NPHZ CNN PU 548741 07 TNPH CNH PU 5487~ 07 890 TNRA CNH NPOR CNH PU RCNT CNM CPS 5~8741 07 ~20 RCFT C'NM CPS 548741 07 ~20 CNTC CNM CPS CFtC CNH CPS 54874~ 07 420. GR CNH G~PI 54874~ 07 3~0 CALI CNH TENS CNH NUMB SIZE REPR 'PROCESS ELEM COgE (HEX) 1 ~ 68 000:0000000 4 65 0000000000 4 68 00000000010 4 68 0000000000 4 63 0000000000 ~ 68 0000000000 ~ 68 0000000000 ¢ 68 0000000:000 ¢ 68 O000OO0000 4 68 000'0000000' 4 68 0000000000 ,4 68 0000000'000 4 68 O00000000O 4 65 00000,00000 4 68 0'000000000 4 68 0000000000 DATA DEPT. 7817.100 DPMI.FOH 26.15Z RHOB.FDH FFDC. FDH 1'159.000 NFDC.FOH 884.500 CALI.FOH TENSoFOH 14g0.000 NPHI.CNH 54,711 TNPHoCNH NPOR... C~NH 50.710 RCNT. CNH 1750.215 RCFT.CNH CFTC.CNH 455.681 GR.CNH 119.125 CALI.CNH DEPT. 7800.000 OPHI.FDH Z6.15Z RHOB.FDH FFDC.FDH 1159.000 NFOC.FDH '884.500 CALI.FDH TENS.FDH 4352.000 NPHI.CNH 54.711 TNPH. CNH NPOR.CNH 50.710 RCNT.CNH 1780.215 RCFT.CNH CFTC.CNH 455.681 GR.CNH 119,125 CALI.CNH DEPT. 7700.000 DPHI.FDH 13.847 RHOB.FDH FFOC.FDH 509.000 NFDC.FDH 590.000 CAL[.FOH TENS. FDH 4268.000 NPHI.CNH 35.407 TNPH.CNH NPOR.CNH ~5.772 RCNT.CNH 2101.715 RCFT.CNH CFTC.CNH 735.768 GR.CNH 97.313 CALI.CNH DEPT. 7600.000 OPHI.FDH 7.415 RHOB.FDM FFOC.FOH 417.250 NFDC.FDH 579.500 CALI.FDH TENS.FDH 4~08.000 NPHI.CNH 35.$71 TNPH. CNH NPOR.CNH 36.280 RCNT.CNH 1932.607 RCFT.CNH CFTC.CNH 739,507 GR.CNH 92,563 CALI.CNH DEPT. 7500.000 DPHI.FDH 13.193 RHOB.FDH FFOC.FDH 561.500 NFDC.FDH 654.000 CALI.FDH TENS.FDH 415~.000 NPHI.CNH 43.131 TNPH.CNH NPOR.CNH 44.393 RCNT.CNH 1633.610 RCFT.CNH CFTC.CNH 510.723 GR.CNH [18.375 CALI.CNH 2-218 DRHO. FDH 7.594 GR.FDM 50.T1'0 TNRA.CNH 401.440 CNTC°CNH 7.594 TE:NS.CNH 2.218 DRHO.FDH 7.594 GR.FDH 50.710 TNRA.CNH ¢01.440 CNTC.CNH 7.594 TENS.CNH Z.,422 DRHO. FDH 8.984 GR.FOH 35.158 TNRA.CNH 636.597 CNTC.CNH 8.984 TENS.CNH 2.528 DRHO.FDH 8.766 GR.FDH 33.912 TNRA.CNH 671.080 CNTC.CNH $.766 TENS.CNH 2.43Z ORHO.FDH 9.602 GR.FDH 42.561 TNR~.CNH 450.~44 CNTC.CNH 9.602 TENS.CNH 0.145 I19.125 18t6.872 1~90.000 0.145 119.125 4.058 1816.872 ~+352.000 0.014 97.313 3.114 2239.632 4268.000 0.039 92.563 3.121 2184.554 4108.000 0.065 218.375 3.596 1805.709 4152.000 ,IS TAPE VERIFICATION LISTING iCHLUMBERGER ALASK4 COMPUTING CENTER 1-NOV-1989 10:00 PAGE: 2:0 DEPT. '7400.000 OPHI.FDH FFDC.FDH 599.000 NFOC.FDH TENS.FDH 4200.000 NPHI.CNH NPOR.C'NH 4Z. 800 RCNT. CNH CFTC.CNH 499.25! GR.CNH DEPT. 7300.000 DPHI.FDH FFDC'FDH 554.500 NFDC.FDH TENS.FDH 3954. 000 NPHI.CNH NPOR.CNH 41.799 RCNT.CNH CFTC.'CNH 57!'470 GR.CNH DEPT. 72 96.800 DPHI.FOH FFDC.FDH 551.000 NFDC.FDM TENS-FDH 3960.000 NPHI.CNH NPDR.CNH 4[. 850 RCNT. CNH CFTCoCNH 543. 342 GR.CNH 14.278 RHOB.FDH 5?4.000 CALI.FOH 46.898 TNPH.CNH 1654.907 RCFT.CNH 126:.~38 CALI.CNH 15. 6213 RHOB.FDH 611,.000 CALI.FDH 41. 949 TNPH. C. NH 8,9 !. 3 ! 2 R C F T. C N H 174.500 CA:LI.CNH 11.287 RHOB.FOH 669.500 ~CALI.FOH 43.014 TNPH'CNH 1823.390 RC~T.CNH 1249.250 CAiLI.CNH 2.414 9.031 42,310 439.260 9.0'31 2.392 4o.65a 471'445 2.464 9.023 41. 284 0.844 9. O23 DRHO.FDH GR.FOH 'TNRA.CNH CNTCoCNH TENS,:CNH ORHO.FDM GR.FDH TNRA.CNM CNTC'CNH TENS.CNH DRHO.FDH GR.FOH TNRA.CNH CNTC.CNM TENSoCNM 0.073 126.438 3.745 17~4,.985 ~200.000 O. 019 174. 500 3.480 1940.356 3964.000 0.089 249L25,0 3.532 1864.285 396'0.000 END OF **** FILE 'TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001A02 DATE : 89/[[/ ! MAX REC SIZE : [024 FILE TYPE : LO L RST FILE : **** TAPE TRAILER **** SERVICE NAME : EOIT DATE : 89/11/ 1 TAPE NAME : 73526 CONTINUATION ~ : 1 PREVIOUS T~E : COMMENT : ARCO AL4SK~ INC., KUPARUK,ZK-16,50-103-20115 **** REEL TRAILER ~*** SERVICE NAME : EDIT DATE : 89/11/ 1 ORIGIN : FLIC REEL NAME : 73526 CONTINUATION ~ : P~EVIOUS REEL : COMMENT : ARCO ~LASKA~ INC., KUPA RUK, 2K-16, 50-103-20115