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189-083
XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA n Diskettes, No. [] Other, No/Type OVERSIZED · [] Logs'of various kinds , Other Complete COMMENTS: Scanned by: Bevedy Dianna ~ncent-'~~Lowell TO RE-SCAN is/ Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned Suspended ' 1b. Well Class: 20AAC 25.105 1 2OAAC 25.110 Development 0 Exploratory El GINJ ❑ WINJ El WAG El WDSPL ❑ No. of Completion 7 .1'.11 Service ❑ Stratigraphic Test El 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: April 14, 2011 189 - 083 / 311 - 064 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 August 24, 1989 50 - 103 - 20111 - 00 - • 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 121' FSL, 94' FEL, Sec. 2, T1ON, R8E, UM August 31, 1989 2K - 08 Top of Productive Horizon: 8. KB (ft above MSL): 154' RKB 15, Field /Pool(s): 1099' FSL, 765' FEL, Sec. 3, T1 ON, R8E, UM GL (ft above MSL): 40' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1214' FSL, 1122' FEL, Sec. 3, T1ON, R8E, UM 7667' MD / 5372' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 498310 y- 5938425 Zone- 4 9445' MD / 6424' TVD ADL 25589 vim TPI: x - 492360 y - 5939406 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 492003 y - 5939522 Zone 4 SSSV @ 1820' MD / 1712' TVD 2675 18. Directional Survey: Yes ❑ No Q 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1464' MD / 1424' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 115' Surf. 115' 24" 179 sx ASII 9.625" 36# J -55 Surf. 3771' Surf. 2906' 12.25" 1100 sx ASIII, 520 sx Class G 7" 26# J -55 Surf. 9423' Surf. 6379' 8.5" 200 sx Class G 24. Open to production or injection? Yes ❑ No Q If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) all perfs isolated 3.5" 8944' 8873' MD / 6097' TVD 9012' - 9044' MD 6171' - 6189' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9100' - 9140' MD 6220' - 6240' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED bridge plug @ 7800' and R .4 ; it : :, `j (G bridge plug @ 8905' and 13.5 bbls 15.8 ppg cement 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25. 71. _ NONE ?'`' r: . ; i�l t�± iry.i)ittll:iiSSIOfl 1 .y .. . y $ ' t. rry 1 Form 10 -407 Revised 12/20RB MS JUL 21 Liii CONTINUED ON REVERSE Submit original only 4 1?'z1 w G ,28. GEOLOGIC MARKERS (List all formations and markers entered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1464' 1424' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce © 265 - 6471 Printed Name, Gober Title: Wells Engineering Supervisor Signature GLl Phone 263 - 4220 Date �v{ 1 1 C Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 • KUP • 2K-08 Conocops .y �ih 1 x g Well Attributes 9 b Max Angle & MD TD "'r 47( W Ilbore APUUWI Feld Name Well Status Inc! r) MD (ftKB) Act Btm (ftKB) 44,4b r 7 4 501032011100 I KUPARUK RIVER UNIT PROD 61.47 I 9,300.00 9,445.0 ' Comment H2S (ppm) Date Annotation End Date KB (89 Rig Rebase Date "' - p«+6 SSSV: NIPPLE 0 1/13/2009 Last WO: 40.19 9/2/1989 ,_2K_oE 7�2Y !11'41...7 1 +1....,.., _._ Shcerpn&: 1ii�re1 "" D epth (ftKB) End _ Date Annotation )L Mod ... End Date Last Tag- SLM 8,205.0 4/13/2011 Rev Reason: Add Original Tbg & Cement IL ninam 7/12/2011 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15 062 35 0 115.0 115.0 62.50 H Casing Description String 0... String ID __. Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.765 35 0 3,770.5 2 905.6 36.00 J - 55 BTC �." Casin Descnpt String 0... Str n9 ID T p (ftKB) Set D Pth (t . Set D pth (ND) . Sin g Wt Str g Stri g T p Thrd P ROD U CTION 7 6 276 26 8 9 423 2 6 378 6 26 00 J 55 Tubing Strings _ CONDUCTOR, r. Tubing Des ription String 0. String ID .. Top (ftKB) Set Depth (f .. Set Depth (TVD) . Str g Wt... Str g .. Stri g T p Thrd 35 - 115 TUBING Original 31/2 I 2.992 I 7,667.0 I 8,944.3 6,135.7 930 J - 55 EUE - 8rd NIPPLE, 505 s3.1 ✓Completion Details Top Depth (TVD) Top Intl Nomi... GAS LIFT, _ Top (ftKB) () (°) Item Description _.- Comment ID (in) 3098 __- _.. 5,859.2 6,089.1 56.82 PBR BAKER PBR 2.892 8,872.9 6,096.6 56.68 PACKER BAKER HB PACKER 2.892 L 8909.9 6,116.9 56 95 NIPPLE 2.813' OTIS XN NIPPLE w2.75" ID 2.750 8943.5 6 135 3. 56 57 SOS BAKER SHEAR OUT 2.992 SURFACE.._ _.. 35 -3,771 : Qthet In Hole reline retrievable plugs, valves, pumps, fish, etc/ t Top Dep GAS LIFT, (TVD) Top Inc! 4,733 Tp (Po(B) (ftKB) (1 Description Comment Run Date ID (in) MD 7,800 5,451.6 53 60 Br dge Plug CAST IRON BRIDGE PLUG 4/15/2011 0.000 ME 8,905 6,114.2 56 95 Bridge Plug CIBP SET 4' ABOVE XN NIPPLE 3/17/2011 0.000 GAS LIFT, 5.630 m u Perforations & Slots : _ -_ ._.._. _.__. --____ Shot GAS LIFT, Top (ND) 8tm (TVD) D s 6,598 N Tp (ftKB) Btn (ftKB) (ftKB) (ftKB) Zone Date (h . Type Comment Gas LIFT, -- 7,539 7,549 5 294.2 5,300 3 A4, 2K 424/2011 6.0 IPERF 3 HSD 7,115 NIPPLE, 7,168 LOCATOR, 9 9 6.171.3 6,189.4 C 2K 10/15/1990 6.0 IPERF 2 1/8" Dynastdp, Zero deg Phasing 7'219 9,022 9,032 6,177.0 6,182.7 C-4, 2K -08 1/152002 6.0 RPERF 2.5" HSD PJ Chgs, 60 deg ph SEALA i 7.220 MIRE SHOE, __ niE 9,100 9,140 6,219.7 6,240 3 A -4 2K -OS 10/25/1989 2 0 IPERF 4 5" HSD, 180 deg. Phasing IPERF _ Stimulations & Treatments 7,539 - 7,549 Bolcom TUBWG76 III kr Min Top Max Btm Top Depth Depth GAS LIFT,_ Depth Depth (TVD) (TVO) 7,686 (ftKB) (ftKB) (ftKB) ( t B) Type Date Comment IA Cement Ping 77n Sr 9 ,012.0 9,044.0 6,171 3 6.189 4 FRAC 2/18/2002 C SAND FRAC 46114416/20 PROPPANT, 55 ppa � ekw . I ON PERFS -_- GASLIFT, I '` Cement Squeezes 8.249 1 GAS LIFT, -I Top Depth Bbn Depth' 8, _ o,; (ND) (TVO) PBR, 0,859 816 - T (ftKB) Btm (8 808 men ) (ftK (ftKB) Description Start Date Comt PACKER. 6.873 ' -- ._. _.... TIN Cement 7,722.0 7,800.0 5,405.0 5 451 6 IA Cement Plug 4/7/2011 beep , 8,257.0 8,905.0 5,730.6 6 114 2 TBG Cement 4/6/2011 8,915 Plug ..- NIP , 8,9 sOSos,e,944 u 1 t --`� Notes: General& Safety RPERF, yn End Date 1 - - - - -- Annotaton 9,oz29,032 l 421/2006 NOTE: Tagged Obstruction @ 8253' WLM IPERF, RAC, 9,012-9,044 12 FRAC, 11/12010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 , IPERF 9.100 - 9,140 11/72010 NOTE: TAGGED OBSTRUCTION 8976' SLM PRODUCTION. - - _. 27 - 9,423 4/112011 NOTE: TUBING TOC @ 8254' ELMD; IA TOC @ 7722' ELMD LINER, - - -- - 7,222 -9,444 '1 '59; fi I OW I lit 1 UK Mart eI Detait Tp Depth Top P 1 (TVD) Intl OD Valve Lath Size TRO Run ftKB) " () Make M odel (in) Sern Type Type ( n) (po.) Run Date Can... Stn Top (ftKB) ( 1 3,098.0 751.1 2.87 Camco KBG -2 1 R 1 GAS LIFT DMY BK5 0.000 0.0 6/42011 2 4,732.5 2,636.7 23.94 Camco KBG-2 1R 1 GAS LIFT DMY BK5 0.000 0.0 6/42011 3 5,829.9 3,879.4 38.08 Camco KBG-2 1R 1 GAS LIFT DMY BK5 0,000 0.0 6/42011 4 6,598.1 4,616.2 47.97 Camco KBG-2 1 R 1 GAS LIFT DMY BK5 0.000 0.0 6/42011 5 7,114.5 5,016.8 54.63 Camco KBG-2 1R 1 GAS LIFT SOV BEK 0.000 0.0 6/42011 TD (2K -08), tis 9,445 2K -08 Well Events Summary DATE SUMMARY = 3/23/11 BRUSHED @ GAUGED TBG 2.7 .0 XN @ 8909' RKB. SET 2.81" XN PLAIN 8909' RKB. ATTEMPTED P/T PLUG, FAILED. ATTEMPTED PULL PLUG, UNABLE TO PASS GLM @ 8816' RKB. IN PROGRESS. 3/24/11 PULLED 2.813" XXN @ 8909' RKB; PLUG IN GOOD SHAPE. REDRESS &.RESET PLUG @ 8909' RKB. ATTEMPTED TEST TBG, FAILED. SET HOLEFINDER ABOVE PLUG @ 8909' RKB; TEST TBG 2500 PSI, HELD SOLID. SUSPECT NIPPLE DAMAGED. PULLED XXN PLUG @ 8909' RKB. INJ TEST: PUMPED 10 BBL @ 0.5 BPM, 2450 PSI. IN PROGRESS. 3/26/11 SET WEATHERFORD 3.5" CIBP AT A MIDELEMENT DEPTH OF 8905' (TUBING TALLY RECORD). LOG WAS CORRELATED TO SCHLUMBERGER SBHPS DATED 5/18/2009. A 17' DEPTH DISCREPANCY WAS NOTED BETWEEN TUBING TALLY AND CORRELATION LOG. SETTING DEPTH ON LOG WAS RECORDED AS 8888' (4' ABOVE XN NIPPLE). RIGGED DOWN AND TURNED WELL OVER TO DSO. 3/27/11 TEST CIBP TO 2500 PSI, PASSED. PULLED GLV @ 7686' RKB. ATTEMPTED REPLACE w/ DV. IN PROGRESS. 3/28/11 SET INT LATCH DV @ 7686' RKB. PULLED GLVs @ 6574', 4976' & 2772' RKB. REPLACED WITH DVs. IN PROGRESS. 3/29/11 ATTEMPTED PULL DV @ 8816' RKB. RECOVERED BROKEN 1 -1/2" LATCH. PULLED OV @ 8248' RKB. CIRC TBG & IA TO DSL. READY FOR CTU. 3/31/11 (PRE -RWO) T POT- PASSED; T PPPOT- PASSED; LDS- FUNCTIONAL 4/6/11 PUMPED 13.5 BBL 15.8 PPG CEMENT, PUMPED APPROX 10 BLL TO IA FROM TOP OF PACKER @ 8873 MD TO 8500, LAYED IN APPROX 3.5 BBL IN 3 1/2 TUBING FROM CIBP @ 8905 TO 8500 MD, TUBING & IA FP, IN PROGRESS 4/8/11 TAG TOC @ 8231' SLM, ATTEMPT TO MITT FAILED. AOGCC WITNESS WAS WAVERED, BY CHUCK W/ AOGCC. JOB SUSPENDED. 4/10/11 ATTEMPTED TO RUN RADIAL CEMENT BOND LOG. DELAYED START DUE TO HIGH WINDS AND TOOLSTRING SHORTING DURING PRESSURE TEST. WILL RETURN TOMORROW TO COMPLETE JOB. 4/11/11 PERFORMED RADIAL CEMENT BOND LOG. FOUND TOP OF CEMENT IN IA AT 7722'. TAGGED CEMENT IN TUBING AT 8254'. 4/12/11 MITT(PASSED), MITIA(PASSED) 4/13/11 ATTEMPTED TO SET WEATHERFORD CAST IRON BRIDGE PLUG. BRIDGED OUT AT 3630', MADE MULTIPLE ATTEMPTS TO PASS OBSTRUCTION WITHOUT SUCCESS. RDMO FOR SLICKLINE TO CLEAR SUSPECTED ICE PLUG. 4/13/11 BAILED CEMENT STRINGERS FROM 3628' TO 3660' SLM. RAN 2.72" CENT, 2' STEM & 2.74" GAUGE RING TO TAG @ 8205' SLM. SLOW THRU AREA BUT FALLS ON OWN, NO EXCESSIVE P.U. WGTS. READY FOR E -LINE 4/14/11 SET WEATHERFORD CAST IRON BRIDGE PLUG AT 7800 FT. MITT TO 2500 PSI, PASSED. CUT TUBING WITH JET CUTTER AT 7668 FT. PRESSURE DID NOT EQUALIZE BETWEEN TUBING AND IA AFTER CUT, SUSPECTED ICE PLUG IN IA. 4/16/11 ESTABLISH T X IA COMMUNICATION THROUGH TBG CUT. ATTEMPT TO PUMP DOWN TBG, LOST COMMUNICATION AFTER 14 BBLS, TBG LOCKED UP. SWAP OVER & CIRC OUT DOWN IA, PUMP 5 BBLS MEOH SPEAR FOLLWED BY 100 BBLS OF DIESEL DOWN IA TAKING RETURNS TO ADJACENT FLOWLINE. U- TUBE (T X IA FREEZE PROTECTED TO 3000') COMPLETE 4/20/11 Completed pad preparation. Spotted sub over well. Spotted all rig complexes. Rig accepted @ 17:00 hrs. Rig up to circulate out diesel freeze protect. Pressure tested lines. Pulled BPV. Drill site maintenance notified to pull VR plug. 2K -08 Well Events Summary '4/21/11tPull VR plug, Rig up and circulate diesel freeze protect and inhibited seawa ith clean seawater. Pumped at 3.2 bpm final circulating rate. Final circulating pressure 2,300 psi. Set BPV and test under BPV to 1,000 psi. Nipple down tree, Nipple up BOPE. Test BOPE. Test witnessed by AOGCC rep John Crisp. Rig down from BOPE test. Pull blanking plug and BPV. Make up spear, Spear into hanger. Back out lock downs. Pull hanger free 95K up wt. Release spear and lay down. Break out hanger from string, Make up headpin to tubing string. Circulate bottoms up at 5 bpm - 650 psi. 4/22/11 Circulate bottoms up at 5 bpm - 650 psi. Pull out of hole laying down 3 -1/2" J55 9.3 ppf tubing and related jewelry. All equipment recovered from hole. Rig up to test lower rams. Not enough spacing between test plug and rams to test. Wait on Storm packer. Set storm packer. Nipple down BOP stack. Add 3' spacer spool. Nipple up BOP stack. Test rams with 3 -1/2" and 4" test joints. Rig down from test. Trip in unseat storm packer and pull from hole. Set 6 -3/8" wear bushing. 4/23/11 Make up scraper BHA. Single in 4" drillpipe, trip in from derrick to 7,651' MD. Tag tubing stump with 7k. Circulate 30 bbl hi -vis sweep. Continue circulating until returns clean at 8.3 bpm - 1,300 psi. Trip out to surface. Lay down scraper assembly. Nipple down riser, Install shooting flange. Test flange - Test failed. Nipple down shooting flange inspect, Install new API ring. Test to 1,000 psi (Good test) Rig up lubricator. Make up wireline gyro and run in hole. 4/23/11 MOBILIZE EQUIPMENT TO 2K -08. RU PCE / SHEAVES. STAND BY FOR RIG TO SET UP ADAPTER FLANGE TO HYDRILL 4/23/11 LOG CONTINUOUS GYRODATA SURVEY FROM SURFACE TO 7600'. LOG 40- ARM CALIPER FROM 7650' TO SURFACE, DATA SUBMITTED FOR PROCESSING. PERFORATED SQUEEZE HOLES FROM 7539' -7549' WITH 3.125" MILLENNIUM HMX, 6 SPF, 60 DEG PHASING. SET BOTTOM OF CEMENT RETAINER AT 7531'. 4/24/11 Pull gyro out of hole on wireline, Make up caliper logging tool, Run in hole perform caliper log F/7,650' MD to surface, Rig down caliper logging tool, Make up 10' perforating gun and run in hole. locate casing collar @ 7,535' MD. Perforate casing top shot 7,539' MD Bottom shot 7,549' MD. Pull out perf gun on wireline. Monitor well, Lay down shot perf guns. Drain stack, Close blinds, Rig down shooting flange, Rig up lubricator, Make up Baker 7" K -1 cement retainer, Run retainer in hole on wireline, Set cement retainer @ 7,531' MD. Pull out of hole with wireline, Test cement retainer and casing 3,500 psi (Shear assembly found intact did not shear - reason for pressure test)Rig down wireline, Make up cement retainer stinger and run in hole on 4" drillpipe. Sting into retainer, Est injection rate Final circulating rate 2 BPm - 1,900 psi. Shut in pressure 1,500 psi. 4/25/11 Est injection rate, 2 bpm - 1,900 psi, Unsting from K1 cement retainer, Pump 5 bbl's mudpush, 15 bbl's cement, 5 bbl's water holding 270 psi back pressure with choke, pump 635 strokes (54 bbl's) seawater bringing mudpush to stinger. Shut down pump, close choke, Slack off and sting into K1 cement retainer (15k down) Open choke, bleed off annulus pressure, open annular while squeezing cement at 2 bpm 1,850 psi. Shut down after 235 strokes 5 bbl's mudpush and 15 bbl's cement squeezed. Pull stinger out of K1 cement retainer. Cement in place 02:00. Circulate bottoms up. Shut down break off single, Rig down head pin and cement hose. Install ball wiper (Nerf ball) into drill string. Make single up to topdrive. Circulate surface to surface. Hold PJSM, Displace to 9.8 ppg milling fluid, Shut down, Rig up and test 7" casing and k1 Cement retainer to 3,500 psi. 30 min. (Test charted) Trip out to 939' MD, Pick up storm packer, Trip in with storm packer at 75' below surface attempt to set with out success. Pull out of hole lay down storm packer, Continue trip out lay down cement retainer stinger, Service rig, Run in hole 10 stands, Pick up new storm packer and set • 2K -08 Well Events Summary - 4/26/14 Remove 7' Casing packoff, Spear L'Iling pull to reset in casing slips with 50k to n. ,O£ (Pulled 151k to achieve 50k overpull) Release spear, Rig up to cut excess 7' casing. 1 �r Wachs cutter did not function. Wait on new cutter. Use new cutter cut excess 7" casing. Cut piece = 32 ", Install new packoff and tubing spool, Nipple up BOPE and test breaks, Set wear bushing, Retrieve storm packer, Do 15 min 3,500 psi csg test, make up whipstock BHA, trip in hole, Orient whipstock, Set @ 19° LHS, Take SPR's. 4/27/11 Mill window F/7,512' MD to 7,545' MD. TOW = 7,512' MD BOW = 7,525' Mai Circulate sweeps.. Perform LOT T/15.5 ppg EMW. Add 13 ppg spike fluid to increase mud wt F/9.8 ppg - T/ 11.0 ppg. Trip out of hole with mills T/2,885' MD. Level rig over Q( hole (Centering pipe in rotary table better) Trip out to surface. Lay down mills, Upper mill full gauge. Pull wear bushing, Flush stack, Install Wear bushing, Slip and cut drill line, Service topdrive. Make up Bi- Center bit BHA. � ` J 0 2K -08 rrJ Actual Pre -ST P &A fX9 7 /. ( 3.5" J -55 Tubing I 9.625" Surface I I Casing I All GLM's have DV's Est. ST KOP ' MD except GLM at 8249' RKB +1- 7500 Tbg Cut at 7668' RKB TOC in IA at 7722' MD per CBL .n: �� CIBP Set at 7800' MD GLM with Open Pocket TOC in Tbg at 8249' RKB at 8257' SLM Baker PBR Brown HB Packer 8873' RKB �- • CIBP Set at 2.75" Otis XN Nipple 8905' RKB Top of rocks & sand at -9015' RKB ............... ............... C Sand Perfs: 9012 - 9044' RKB A Sand Perfs: 9100 - 9140' RKB 7" Prod Csg (may be split at perfs) • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 27, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record, Plug Setting Record: 2K -08 Run Date: 4/24/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K -08 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20111 -00 1"g PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 / c20q j Office: 907 - 273 -3527 Fax: 907- 273 -3535 klinton.wood@halliburton.com Date: Signed: . • , ::..: S r , WELL LOG TRANSMITTAL PROAcrivE DIAgnosTic SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Anchorage, AK 99518 Adotwai VIAY Fax: (907) 245 -8952 e vi ®63 oxpf 9 ( Li 0., i°i' q -oa9 c:26 996 1) Caliper Report 22-Apr-11 2B -10 1 Report / EDE 50 -029- 2108400 () Caliper Report 24- Apr - -11 2K-08 1 Report / EDE • - o -0• i i Signed : d / . Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 C:\Documents and Settings\Diane Williams \Desktop \CPAI_Transmit.docx ' • • Multi- Finger Caliper Log Results Summary 111 Company: ConocoPhillips Alaska, Inc. Well: 2K -08 Log Date: April 24, 2011 Field: Kuparuk Log No.: ZX70 State: Alaska Run No.: 1 API No.: 50-103-20111-00 Pipe Desc.: 7" 26 Ib. J -55 BTC Top Log Intvl.: Surface Pipe Use: Production Casing Bot. Log Intvl.: 7,645 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: 1 This caliper data is correlated to Halliburton CBL Dated September 27, 1989. This log was run to assess the condition of the 7" casing with respect to corrosive and mechanical damage. The caliper recordings indicate the 7" casing logged appears to be in good condition, with no significant wall penetrations, areas of cross - sectional wall loss or I.D. restrictions recorded. This summary report is an interpretation of data provided by Halliburton Well Services. 1 MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 14 %) are recorded. MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant areas of cross - sectional wall loss (> 4 %) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. 1 1 1 1 I Field Engineer: Biery /Cheysobhon A nalyst: HY. Yang Witness: B. Boehme PraActive Diagnostic Services, In / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDSilimemorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 —o1s3 c9O9/ I • • faS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk 1 Well : 2K -08 Date : April 24, 2011 Description : Detail of Caliper Recordings Across Vicinity of Whipstock Placement I Comments Depth Maximum I.D. 3 -D Log Image Map M i 1ft:320Ft 6 inches 7 0° 0° 90° 180° 270° 0° I Minimum I.D. 6 inches 7 1 Nominal I.D. i 6 inches 7 ...1Lrit / .1.1V _ Joint 191 I 7460 » IC mi Joint 192 t 7480 -.a I 7 . -no - I 7500 — _ . i Joint 193 I 7520 1 • mos I 7540 — z. - , – z 1 Joint 194 1 ^_+" i 7560 - _ . if 7. f 7580 _ €- - Joint 195 = I 7600 7620 - - k I Joint 196 w_ • 7640 ' i _ I I • • Correlation of Recorded Damage to Borehole Profile I II Pipe 1 7. in (43.3' - 7613.0') Well: 2K -08 Field: Kuparuk I Company: Country: ConocoPhillips Alaska, Inc. USA Survey Date: April 24, 2011 I II Approx. Tool Deviation ■ Approx. Borehole Profile 1 43 -i a I 25 1 971 1 I 50 / 1938 I 75 2913 a I 45 E c z 100 a 3886 y o p I 125 4856 150 = 5828 1 I 175 6795 I 196 7613 I 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) I Bottom of Survey = 196 I I • • I PDS Report Overview ti s ,,. Body Region Analysis I Well: 2K -08 Survey Date: April 24, 2011 Field: Kuparuk Tool Type: UW MFC 40 No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 7 ins 26 ppf J -55 BTC Analyst: HY. Yang Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 7 ins 26 ppf J -55 BTC 6.276 ins 7 ins 6.0 ins 6.0 ins Penetration(% wall) Damage Profile (% wall) 200 Penetration body Metal loss body 0 50 100 1 150 100 a 50 1 0 I 51 O to 20 to 40 to over 20% 40% 85% 85% g Number of joints analysed (total = 196) g I 196 0 0 0 1 a I Damage Configuration ( body) 101 10 iiir 5 I 151 A 0 I solated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole 4 I Number of joints damaged (total = 6) 6 0 0 0 0 Bottom of Survey = 196 I I I 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7 in 26 ppf J -55 BTC Well: 2K -08 Body Wall: 0.362 in Field: Kuparuk Upset Wall: 0.362 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 6.276 in Country: USA Survey Date: April 24, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 1 2 43 0 0.03 9 2 6.24 75 0 0.02 6 2 6.26 3 114 0 0.02 6 1 6.25 4 153 0 0.03 9 1 6.22 5 191 0 0.04 10 3 6.22 I 6 230 0 0.02 5 1 6.24 7 269 0 0.03 7 2 6.24 8 308 0 0.03 9 2 6.26 9 347 0 0.03 9 2 6.24 1 I 10 11 386 0 0.04 10 3 6.23 425 0 0.02 6 1 6.25 12 465 0 0.02 6 2 6.23 13 504 0 0.04 10 2 6.24 I 14 15 542 0 0.02 7 2 6.24 581 0 0.02 4 1 6.25 16 620 0 0.04 10 3 6.24 17 659 0 0.03 8 3 6.23 18 699 0 0.03 7 2 6.25 I 19 738 0 0.05 13 2 6.21 Shallow Pitting. 20 776 0 0.03 9 2 6.25 21 816 0 0.03 8 2 6.22 22 855 0 , 0.03 7 1 6.23 I 23 893 0 0.02 6 I 6.23 24 933 0 0.03 8 2 6.21 25 971 0 0.02 6 1 6.24 26 1011 0 0.03 9 2 6.25 I 27 1048 28 1088 0 0.03 9 2 6.21 0 0.03 7 2 6.26 29 1127 0 0.03 8 3 6.24 30 1166 0 0.03 7 1 6.22 I 31 1205 0 0.02 6 1 6.23 32 1243 0 0.03 8 2 6.24 33 1282 0 0.03 8 1 6.22 34 1321 0 0.03 9 2 6.23 35 1360 0 0.03 7 2 6.23 I 36 1398 0 0.02 6 2 6.24 37 1436 0 0.03 8 2 6.24 38 1475 0 0.03 9 3 6.25 39 1515 0 0.04 10 2 6.20 I 40 1554 0 0.02 6 1 6.22 41 1592 0 0.03 9 2 6.22 42 1631 0 0.03 9 2 6.22 43 1668 0 0.03 9 2 6.20 I 44 1705 45 1744 0 0.03 9 2 6.24 0 0.03 9 2 6.22 46 1783 0 0.02 6 1 6.26 47 1821 0 0.03 8 2 6.21 48 1859 0 0.03 8 2 6.23 I 49 1899 0 0.03 7 2 6.23 50 1938 0 0.03 9 2 6.24 I Penetration Body I Metal Loss Body Page 1 I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7 in 26 ppf J -55 BTC Well: 2K-08 Body Wall: 0.362 in Field: Kuparuk I Upset Wall: 0.362 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.276 in USA Survey Date: April 24, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/0 wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 51 1976 () 0.03 8 1 6.23 52 2015 t) 0.03 8 2 6.22 53 2053 0 0.02 7 2 6.24 54 2093 0 0.03 8 2 6.25 55 2132 0 0.02 6 2 6.24 I 56 2170 0 0.03 8 2 6.24 57 2209 0 0.03 8 3 6.22 58 2247 0 0.02 7 2 6.24 59 2287 0 0.03 7 2 6.23 I 60 2326 0 0.04 10 3 6.24 61 2366 0 0.03 9 2 6.23 62 2404 0 0.02 6 2 6.24 63 2442 0 0.04 10 2 6.23 I 64 2482 65 2521 0 0.03 9 2 6.24 0 0.03 7 2 6.25 66 2560 0 0.04 10 2 6.24 67 2599 0 0.03 9 3 6.25 68 2638 0 0.04 10 2 6.23 I 69 2678 0 0.04 10 2 6.22 70 2717 0 0.03 7 1 6.25 71 2757 0 0.03 8 2 6.25 72 2795 0 0.03 8 2 6.22 I 73 2834 0 0.02 7 1 6.25 74 2873 0 0.03 7 1 6.25 75 2913 0 0.03 9 2 6.22 76 2952 0 0.03 7 2 6.23 I 77 2992 0 0.03 9 1 6.26 78 3031 0 0.02 6 2 6.20 79 3070 0 0.03 8 2 6.23 80 3109 0 0.02 6 1 6.25 I 81 3149 0 0.03 8 2 6.23 82 3187 0 0.04 10 2 6.22 83 3225 0 0.04 12 3 6.26 84 3265 0 0.03 9 2 6.25 85 3304 0 0.02 6 1 6.23 I 86 3343 0 0.03 7 2 6.22 87 3382 0 0.03 9 3 6.27 88 3421 0 0.03 7 2 6.22 89 3458 0 0.04 10 2 6.20 I 90 3496 0 0.03 9 2 6.24 91 3534 0 0.03 7 2 6.24 92 3573 0 0.03 8 1 6.22 93 3613 0 0.03 9 2 6.24 I 94 3652 0 0.02 7 1 6.24 95 3691 0 0.04 10 2 6.21 96 3730 0 0.03 8 2 6.25 97 3769 0 0.03 8 2 6.23 98 3808 0 0.02 7 2 6.22 I 99 3847 0 0.04 10 3 6.25 100 3886 0 0.04 11 .3 6.23 rat I Metal Loss ion Body I Page 2 Penet I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7 in 26 ppf J -55 BTC Well: 2K -08 Body Wall: 0.362 in Field: Kuparuk I Upset Wall: 0.362 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.276 in USA Survey Date: April 24, 2011 I Joint Jt. Depth Peen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 101 3925 0 0.03 9 2 6.24 102 3963 0 0.03 7 1 6.25 103 4001 0 0.04 11 1 6.22 104 4039 0 0.03 8 2 6.26 105 4077 0 0.03 7 2 6.23 106 4117 0 0.03 8 3 6.22 107 4155 0 0.04 10 2 6.24 108 4194 0 0.04 10 2 6.25 109 4233 0 0.03 7 2 6.25 110 4273 0 0.03 8 1 6.23 111 4312 0 0.02 7 1 6.23 112 4352 0 0.03 9 2 6.25 113 4391 0 0.03 7 3 6.26 114 4430 0 0.04 10 2 6.20 115 4466 0 0.03 7 1 6.26 116 4504 0 0.03 7 2 6.22 117 4544 0 0.03 9 2 6.26 118 4583 0 0.03 9 2 6.23 119 4622 0 0.03 9 3 6.25 120 4662 0.04 0.05 14 2 6.22 Shallow Line of Pits. 121 4700 0 0.03 8 2 6.23 122 4738 0 0.02 7 1 6.24 123 4778 0 0.04 10 2 6.24 124 4817 0 0.03 8 2 6.25 125 4856 0 0.03 8 2 6.24 126 4896 0 0.03 9 2 6.21 I 127 4934 0 0.03 7 2 6.26 128 4973 0 0.04 11 2 6.22 129 5013 0 0.05 14 2 6.25 Shallow Pitting. 130 5053 0 0.04 12 3 6.23 Shallow Pitting. I 131 5091 132 5131 0 0.03 9 3 6.24 0 0.03 9 2 6.23 133 5170 0 0.03 8 2 6.25 134 5210 0 0.03 8 2 6.26 135 5249 0 0.04 10 3 6.24 136 5288 0 0.04 10 2 6.23 137 5328 0 0.04 10 3 6.25 138 5367 0 0.03 8 2 6.23 139 5406 0 0.02 7 1 6.22 1 140 5445 0 0.03 8 2 6.25 141 5485 0 0.03 7 2 6.25 142 5522 0 0.04 10 2 6.26 143 5560 0 0.04 11 2 6.24 ;1 1 144 5599 0 0.04 10 2 6.25 145 5637 0 0.03 8 2 6.26 146 5676 0 0.03 8 2 6.26 147 5715 0 0.04 10 2 6.26 148 5749 0 0.03 9 3 6.24 I 149 5789 0 , 0.03 7 2 6.26 150 5828 0 0.03 9 2 6.25 Penetration Body I Metal Loss Body Page 3 I I ! • PDS REPORT JOINT TABULATION SHEET I Pie: 7 in 26 f J-55 BTC Well: Pipe: Pp 2K-08 1 I 2 Body Wall: 0.362 in Field: Kuparuk I Upset Wall: 0.362 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.276 in USA Survey Date: April 24, 2011 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % l oss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I ' 151 5867 0 0.04 11 2 6.24 152 5906 () 0.03 7 2 6.25 153 5945 0 0.04 10 2 6.26 154 5984 0 0.03 7 2 6.25 155 6024 0 0.05 14 6.27 Shallow Line of Pits. I 156 6063 0 0.03 8 2 6.23 157 6102 0 0.04 10 2 6.24 158 6142 0 0.04 11 2 6.24 159 6180 0 0.04 12 2 6.24 I 160 6218 0 0.03 8 2 6.26 161 6258 0 0.03 9 2 6.24 162 6296 0 0.02 6 1 6.22 163 6335 0 0.03 8 2 6.22 I 164 6373 165 6411 0 0.03 9 2 6.22 0 0.03 8 2 6.25 166 6450 0 0.03 9 2 6.24 167 6489 (1 0.04 11 3 6.24 I 168 6528 0 0.03 9 2 6.22 169 6566 0 0.03 8 2 6.26 170 6605 0 0.04 10 2 6.23 171 6644 3) 0.04 10 2 6.26 172 6684 0 0.04 12 2 6.23 Shallow Pitting. I 173 6724 0 0.04 10 2 6.23 174 6762 0 0.04 10 2 6.25 175 6795 0 0.04 11 2 6.25 176 6835 0 0.02 5 1 6.25 I 177 6874 0 0.04 10 2 6.27 178 6914 0 0.03 7 2 6.23 179 6953 0 0.03 8 2 6.18 180 6992 0 0.02 6 2 6.24 I 181 7031 0 0.04 10 3 6.26 182 7069 0 0.03 9 2 6.22 183 7107 0 0.02 6 1 6.26 184 7146 0 0.03 8 2 6.27 185 7186 0 0.02 7 2 6.25 I 186 7223 0 0.03 7 2 6.28 187 7263 0 0.03 7 2 6.27 188 7302 0 0.03 8 2 6.23 189 , 7340 0 0.03 9 2 6.26 I 190 7379 0 0.04 10 2 6.24 191 7418 0 0.04 10 1 6.26 192 7457 0 0.02 6 2 6.23 193 7496 0 0.04 12 :3 6.26 I 194 7534 0 0.03 9 2 6.24 195 7573 0 0.04 11 6.23 196 7613 0 0.04 12 4 6.24 I Pration Bo Metal Loss Body I Page 4 I t KUP • •• t ConocoPhillips Well Attributes Max Angle S MD TD J Welton) al lPIIIWI Red ma .6.0]..o. �'1 ,'L II ( 'a'' n...:. CanacaPlSa f 501032011100 KUPARUK RIVER UNIT 'PROD 1 010511 I -, • r 6 _ H •[I .47 8,300) .00" IEU)/ �t 8,445.If Edit ■ °- Dammam d .t nls lppmI Date Edit anna0tan am EMS -,itr Po. n(h) 019 RCIS.I Edlt 2,11{��51IViiYDYn„F.t1a0.7P)nJ SSS 1 0 017 0 1/13 Lest WO' 40.19 9127198 vv_nnvic 0009 an DPpin(� a) eu1 , amore... Lae Moe _. em. Adis Last Tap:ELMD 9,015.0 5798 11• Rev Reason: PUMP CEMENT PLUGS IrrosLor 4/7'. Casing S r rigs • aging LOIS14i0n Vona O0.. 0015 ID... op (ttKE) aei win (t_ set DIM (NO)... String 082_ stung._ tiring Top 111,. 111 K•NGEP 31 1 ■ CONDUCTOR 16 15.0962 35.0 115.0 115.0 6250 H-40 tY dm Deaglun thing O0.. Siring ID_. {1tKE) Set Depti(t_ Sat Depth iTVD)... Sting Wt_ Stkg._ Shim Top TIf;. SURFACE 9 518 8.765 35.0 3,770.5 2,905.6 36.08 755 BTC Lit (f i1 C0 9g 0,0411 ion smog 00.. String ID... op (ttKB) lei DIpi1 (9_ Set Depth (MV'D)... Sting N/Y_ M00 .. 11101970p lull_ l It PRODUCTION 7 6.151 27.0 9,4232 8,378.6 28.00 J55 BTC • ooeouS.111 Tubing Strings I Tl Viva Deenptbn Dril m . 9_ _ op ODY 101 ra it_ et (TInrg'WT tong .. !Wiv P st TUBING I S 312 OQ. l 2992 00 ID 31.1 ifl 8, 944 . pt) 3 ( S,35.7 DI _ I S 9.30 _ prim] I E UE-9 Completion Details IF1tit :l /ETYVLV, 'Top Copt) 1 •e'o' Top TIDY Top h<l 19111._ 100 /:11/ IRr: am Do enptlon •-_ mment ID(In1 I 31.1 31.1 -1.83 HANGER RAC GENIVTUBINOHANGER 3.508 18195 1,712.3 4050 SAFEN VW CAMCO TROP-1A 955V 2812 G.4^, r 8,859.2 8,089.1 56.82 P518 BAKER PRB 2.892 _, 8,872.8 6,086.6 56.68 PACKER BAKER HB PACKER 2.882 8,909.9 6,116.9 5635 NIPPLE 2.013•' OTISXN NIPPLE 02.75 "ID 2.750 I 8,843.5 6,135.3 56.57 SOS BAKER SHEAR OUT 2.882 Other In Hole °Mrelina retrievable plugs, valves, pumps, fish, etc.) Hill Tap /spin 31DIeLE, Top LFODl Top reel 3S�]tl ttr:ba tit! El. I ', 00,00/109 Comm ant Run Der IDilnl 8,905.0 6,1142 55.95 PLUG CIBP SET 4 ABOVEXN NIPPLE 3/172011 0.000 I rw T9rF u lr. F/lil Perforations $Slots snot 9069 Top 17/01 151M ITJDO 0011 a�s T..IRKCI MKEI ftttOr (711 env Dal 1 1104 Comment ml 9,012.0 9,044.0 6,171 6,109.4 C4, 2K-00 1011511990 6.0 IPERF 21/8 "Dynaslrip, Zero deg. Phasing I 00 9,022.0 9,032.0 9,177162.7 C4,2K -08 V15l2 BA RPERF 2.5 "HSD PJChgs•60degph 0Ll1T, ,0 8, 9,130.0 9,140.0 6,219.7 6240.3 A-4, 2K-08 1012511089 2A IPERF 4.5 SD, IChgs .Rrasing fiT1 Stimulations 8 Treatn1811ts hold tinhorn Min Top Pal BIn Tap Olptl 13 0n 1 c......"..1 Dg111 (ND) (ND) i CPI: 151 MK!) (6IKBI ,.T0,1:11 T" 'orim1nt ill 9,012.0 9,844.0 6,771.9 6,109.4 FRAC 2/102082 C -SAND FRAC, 461,11620PROPPANT, 5.5ppa UN 0,01.11T. P ER F S '0` Celttert Squeezes ILdit mop elm min , ohn , Tiny, ( ' TOD II5K61 1111 E) MK el 411:131 01101104/00 Start Dam Coumalt LI 8,500.0 0,905.0 5,879.4 6,1142 Cement Rug 4/6/2011 LIrT 0,5903 9,9725 5,878.401 8.056.6 Comore Rug 47612111 s w Notes: General & Safety it Eta mm 31950105 10/19/1993 NOTE, CAM CU MANDRELS 7 t 80URST@ 5000 PSI, COLLAPSE@ 3400 PSI 42112006 NOTE Tagged 06sa oclion @ 8253'191M 11/12010 NOTE' VIEW SCHEMATIC w1Alaska S4hematio9.0 T 11772410 NOTE: TAOOED OBSTRUCTION @ 8976' SLM c.- ..LIFT, ;+ 8E10 y it mti Crnml4m '�4 4 NI PALL:P. a • clm<m ■. rtuy DSra 117. I 1000E0.911 0001,09M I MS ■ 10E11. 9p:2 13 031]0(1, IPNG,9Al2 Mandrel Details IF1li1 i Top dp09! I Port Top iP.D, Top O D 1151 as TRO Run Ito ittl•E] JAI., B'1 ,Intl °1 Hai. I wool (In) tary 49100 Twa TV* On) (pre') Run Dab Con_ ,_,,. ' 1 2,771,7 2,320.5 54.29 MERLA 11 1 GAS LIFT GLV BK 0.000 DA 3262011 I 2 4,978 4 1,6022 50.0:3 MERLA TM PD I GAS LIFT OW BK 0.000 OA 328/2011 9,nmii _ 3 6,051.5 4,3482 49.61 MERLA IMP() 1 GAS LIFT DMY BK 0.000 OA 7/18/1997 4 6,574.4 4,686.3 48.51 MERLA TM PD 1 GASLIFT DMY BK 0.000 0 .03/29/2011 ■ 5 7,132.5 5,041.3 50.09 MERLA TMPD 1 GAS LIFT DMY 0K DA00 OA 7/18/1997 6 7,886.3 5,383.4 52.90 MERLA TMPD 1 GAS LIFT DMY BK 9.000 OA 3292011 7 8,248.8 5,725.4 51.37 CAM... MMU.2 1 12 GAS LIFT OPEN 0.000 03 3/292011 5 8,810 4 0,005.4 56.07 CAM.. MMG2 1 12 GAS LIFT DMY BK 0300 03 10/19/1983 ■ P POI n�� 70.90.1.5 1. ■ • • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, April 13, 2011 8:30 AM To: 'Gober, Howard' Subject: RE: 2K -08 (PTD 189 -083) Pre -Rig P &A Operations Howard, agree ... a tubing test alone will be fine. *MAO APR 1 3 in F Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Gober, Howard [mailto:Howard.Gober @conocophillips.com] Sent: Wednesday, April 13, 2011 8:29 AM To: Schwartz, Guy L (DOA) Subject: RE: 2K -08 (PTD 189 -083) Pre -Rig P&A Operations Guy, Along with the MIT of the tubing yesterday, we were able to MIT the IA as well. The pressures were initial 2520 psi, 15 min 2464 psi, and 30 min 2442 psi. With this passing MITIA, I do not think we need to do a CMIT after the cut. We can pressure test the CIBP once it is set, but a CMIT will not be necessary since the IA and CIBP will have been pressure tested separately. Please let me know if you concur. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907 - 263 -4220 Office 907 - 240 -5515 Cell Howard.Gober@conocophillips.com From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, April 13, 2011 8:21 AM To: Gober, Howard Cc: Peirce, John W; Cecchetti, Elmo B; Boehme, Brandon H; CPA Wells Supt; Cawvey, Von Subject: RE: 2K -08 (PTD 189 -083) Pre -Rig P&A Operations Howard, I agree with your proposed plan as you outline it below. The CBL confirms cement above the open mandrel pocket so placing anther CIBP within that area will insure an adequate barrier. Pressure tesing to 1800 psi still 4/13/2011 Page 2 of 2 1 • meets regulation requirements (TVD X .25 psi) also received a request from Elmo to move the 7" casing window uphole to about 7500'md that was approved (originally was at 7966' md) Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Gober, Howard [mailto:Howard.Gober @conocophillips.com] Sent: Tuesday, April 12, 2011 5:16 PM To: Schwartz, Guy L (DOA) Cc: Peirce, John W; Cecchetti, Elmo B; Boehme, Brandon H; CPA Wells Supt; Cawvey, Von Subject: 2K -08 (PTD 189 -083) Pre -Rig P&A Operations Guy, Thank you for taking the time to discuss the 2K -08 Pre -Rig P &A Operations today. I would like to recap our conversation. The work on 2K -08 is in preparation for a upcoming rotary sidetrack by Doyon 141. The reservoir was isolated with a CIBP set at 8905' RKB below the packer. The plan was to pull the bottom gas lift valve and lay in -373' of cement above the packer in both the tubing and the IA. Due to some miscommunication the job did not go as planned. Slickline attempted to pull the bottom gas lift valve at 8816', but a broken latch prevented the valve from being pulled. They pulled the valve in the next mandrel up at 8248' RKB and turned the well over to coiled tubing for the cement job. The coil crews did not realize the valve had not been pulled from the bottom mandrel and they completed the cement job as if the well was setup as previously planned. By doing so, we have cement in the tubing from 8905' RKB to 8257' RKB (slickline tag) and cement in the IA from 8248' RKB to -7722' RKB. The top of cement in the IA is according to a bond log we ran through the tubing. I have attached a field copy of the log for your reference. The tubing passed a MIT to 2500 psi today. The results of the MIT on the tubing were sent to you by Brent Rogers earlier today via email. Since we do not have cement above the open gas lift mandrel at 8248' RKB, we will set a CIBP at -7800' RKB in the tubing. This is within the best cement on the bond log. We will pressure test the CIBP to 2500 psi after the plug is set. The tubing will be cut at -7668' RKB. After the cut we will CMIT the tubing and IA to 1800 psi. We are limiting this to 1800 psi because the 7" casing packoffs have historically leaked. We do not want to exceed 1800 psi on the surface casing if the packoffs leak as expected. I think this adequately captures the conversation we had and our plan forward. Please let me know if you agree. Our plan is to start this work 4/13 or 4/14. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907 - 263 -4220 Office 907 - 240 -5515 Cell Howard.Gober@conocophillips.com 4/13/2011 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 12, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: 2K -08 Run Date: 4/11/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K -08 Data in LAS format, Digital Log Image files 1 CD Rom 50 -103- 20111 -00 Cement Bond Log 1 Color Log 50 -103- 20111 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 tr9 klinton.wood @halliburton.com (305 03 3 1, 4 _a ea Date: Signed: 0' �;. ��� ,, • • Page 1 of 1 Regg, James B (DOA) 16q- ® V_, From: NSK Problem Well Supv [n1617 @conocophillips.com] 4 I Sent: Tuesday, April 12, 2011 3:56 PM � To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: Gober, Howard Subject: 2K -08 (PTD 1890830) MITT data post cement plug Attachments: MIT KRU 2K -08 04- 12- 11.xls; MIT KRU 2K -08 04- 08- 11.xls Tom, Jim, Guy Attached are the MIT forms for 2K -08 for the MITT performed post cement for a CTD sidetrack. The first sheet shows the attempts that failed and the second sheet has the data from the passing diagnostic MITT that was performed today. Please let me know if you have any questions. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 : ,:4e' 4 2 01 ` Pager (907) 659 -7000 pgr. 909 4/14/2011 • i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.react alaska.gov, doa.aoacc.orudhoe.bay alaska.gov; phoebe.brooks(ctalaska.gov: tom.maunder(a).alaska.gov OPERATOR: ConocoPhillips Alaska, Inc FIELD / UNIT / PAD: Kuparuk / KRU / 2K DATE: 04/12/11 OPERATOR REP: Colee / Westlake - AES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K -08 ' Type Inj. N TVD 6,09T Tubing 250 2,505 2,400 2,357 ' Interval 0 P.T.D. 1890830 Type test P Test psi 1524.25 Casing 10 10 10 10 P/F P Notes: Diagnostic MITT OA 350 350 350 350 Well . In. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA 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 T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 - 426 (Revised 06/2010) MIT KRU 2K -08 04 -12 -11 (2).xls • . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regg @alaska.gov; doa. aoocc.grudhoe.bay(cdalaska.govi phoebe.brooksOalaska.gov; tom.maunder(rDalaska.gov OPERATOR: ConocoPhillips Alaska, Inc FIELD f UNIT / PAD: Kuparuk / KRU / 2K DATE: 04/08/11 OPERATOR REP: Watkins - HES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K -08 ` Type Inj. N TVD 6,097' ' Tubing 1,325 2,500 " 2,415 2,350 ' Interval 0 P.T.D. 1890830 ' Type test P Test psi 1524.25 Casing 0 0 0 0 P/F F Notes: Chuck Scheve waived right to witness OA 360 360 360 360 Top of cement tagged by Slickline @ 8231' SLM Well 2K -08 Type Inj. N TVD 6,097' Tubing 2,350 2,525 2,475 2,440 Interval 0 P.T.D. 1890830 Type test P Test psi 1524.25 Casing 0 0 0 0 P/F F Y . Notes: 2nd attempt OA 360 360 360 360 Well 2K -08 Type Inj. N TVD 6,097' Tubing 2,440 2,525 2,475 2,440 - Interval 0 P.T.D. 1890830 Type test P Test psi 1524.25 Casing 0 0 0 0 P/F F Notes: 3rd attempt OA 360 360 360 360 Well 2K -08 Type Inj. N TVD 6,097' Tubing 2,440 2,530 2,490 2,450 2,400 ' Interval 0 P.T.D. 1890830 Type test P Test psi 1524.25 Casing 0 0 0 0 0 P/F F Notes: 4th attempt OA 360 360 360 360 360 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 T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 - 426 (Revised 06/2010) MIT KRU 2K -08 04 -08 -11 (2).xls • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 30, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 2K -08 Run Date: 3/26/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K -08 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20111 -00 � Atit,,Ld APR 1 8 2Oi PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 ( 9pt5 klinton.wood@halliburton.com Date: Signed: • • SWE OT AELASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 X 7)276 279 : W. 7th AV 90 ENUE, UIT 542 433 E 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 (907) FA PHONE John Peirce g� Wells Engineer (y ConocoPhillips Alaska, Inc. ` D P.O. Box 100360 Anchorage, AK 99510 ._. Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K -08 Sundry Number: 311 -064 Dear Mr. Peirce: 5i4AONEV MAR 0 9 2011 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. (7V6 Chair DATED this day of March, 2011. Encl. STATE OF ALASKA ' ALASKOL AND GAS CONSERVATION COMMISS� ( (� ,� �� APPLICATION FOR SUNDRY APPROVALS 3 ' 20 AAC 25.280 1. Type of Request: Abandon fi Rug for Redrill . p Perforate New Pool fl Repair w ell l Change Approved Program r Suspend r Rug Perforations ' / ik perforate r Pull Tubing l Time Extension E Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r , Exploratory E 189 -083 ` 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20111 -00• 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No 2K -08 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25589 ' Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9445 • 6425 • 9341' 6375' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115' 115' SURFACE 3736 9.625" 3771' 2906' PRODUCTION 9396 7 9423' 6379' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9012'- 9044', 9100' -9140' 6171'- 6189', 6220' - 6240' 3.5 J - 8944 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER 'HB' PACKER MD= 8873 TVD= 6097 TRDP - CAMCO TRDP -1A -SSA MD= 1820 TVD= 1713 12. Attachments: Description Summary of Proposal J 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: , 3/15/2011 Oil Gas / WDSPL r Suspended .. i ' 16. Verbal Approval: Date: WINJ r GINJ r WAG E Abandoned 4 ' Commission Representative: GSTOR E SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Printed Name John Peirce Title: Wells Engineer Signature ' .tom Phone: 265-6471 Date 313 Commission Use Only 3/3W Sundry Number I "Vfr ./ Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test Mechanical Integrity Test r Location Clearance .t 3SOd ,p ` 6 O P - 7::5 .&- RECEIVED Other: / t�s1.v l e 5f ( G"`' � i e — Z 52:;16 p," /J /,tern fit) rd ✓mil R 4 1011 5 p /a«. „z i a p z o AA z s' qz <i, Subsequent Form Required: / Q _ 5( J Aisska 4i1 & 6 s Cons.Consnission 1trhor i ,. APPROVED BY / Approved by / COMMISSIONER THE COMMISSION Date: 3 B • S ''AR Q 8 ^ � !'�' - ' it Form 10 -403 Revised 1 010 • 1VNISIiO ` Q - 3 7 1 � Submit in .fl4I • • 2K -08 Pre -Rig Sidetrack Plug & Abandonment i Current Completion Proposed Pre -ST P &A i L 3.5" J -55 Tubing 9.625" Surface .i L Casing 8 GLM's Est. ST KOP +/- 8130' RKB Tbg Cut at —8274' RKB TOC at 8500' RKB 1 Baker PBR Brown HB Packer 8873' RKB Nipple XN Plug Set at ✓ 2.75" Otis XN Ni pp 8910' RKB Top of rocks & sand at —9015' RKB C Sand Perfs: v ' :::: - 9012 - 9044' RKB _ A Sand Perfs: 9100 - 9140' RKB 7 Prod Csg ::::::.:.:::.:.:: (may be split at perfs) ' .....::::::: : • JWP 2 -15 -11 . KUP • 2K -08 1 I Cl�tlt)C+ 1i) t Well Attributes Max Angle & MD TD WeIlDore APIIUWI Field Name Well Status Inc/ ( °) MD (fl K6) Act Btm MKS) ; A)192901 !TIC, 501032011100 i KUPARUK RIVER UNIT PROD 6147 1 1 9,30000 9,4450 ■ C H25 ( ) Last Tag ELMD 9,015 0 5/18/2009 Date Annotation End Date KB -crd (ft) Rig Release Date yyeltC Mfg, ,21 - ¢d;.7?(22/R91 pM - '_ SSSV 9RDP at 1/ 9 Last W0_ 40 19 9/2/1989 �' _ Schgntakc_AcNaL - A notation Depth (flK61 End Date � Annotation 'Annotation ' _ Last Mod By End Date Rev Reason TAG OBSTRUCTION 1 Imostwr 11/2712010 Casing Strings String OD String ID Set Depth Set Depth (ND) String Wt String Casing Description (in) (in) Top(81(B) (flKB) (FEB) ( /belt/) Grade String Top The CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H -40 IPISIMIN SURFACE (OC) 9 5/8 8.765 35.0 3,770.5 2,905.6 36.00 J -55 BTC c1 PRODUCTION (QC) 7 6.151 27 0 9,423.2 6,378.61 26.00 J -55 BTC `- * I Ibing Strings String OD String ID Set Depth Set Depth (ND) String Wt String i '''' l Tubing Description (in) (in) Top (nKB) (BKB) (FMB) 1 (115s/ft) Grade String Top Thrd safe Vaore, _ TUBING 31/2 2992 00 8,944.0 6,13S_5 9.301) 55 EUE8rdABmod 1,820 - _ _. Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) b t. Top Depth 7 ' (TVD) Top Inc! Top (BKB) (flKB) (°) Description Comment Run Date ID (in) 1,820.0 1,712.6 40.50 Safety Valve Cameo TRDP-1A-SSA 10/27/1989 2.812 GAS LIFT, _ - -- 2,772.0 2,320.7 54.29 GAS LIFT MERLA/TMPOn /GLVBK/.125/1312/ Comment STA 1 2/23/2002 2.875 2,772 4,976.0 3,662.0 50.89 GAS LIFT MERLA/ TMPD /1/GLVBK/.156/1340 /Comment STA2 2/23/2002 2.875 6,051.0 4,347.9 49.61 GAS UFT MERLA/TMPD /1 /DMY /BK/// Comment: STA 3 7/18/1997 2.875 . 6,574.0 4,688.0 49.49 GAS LIFT MERLA/TMPD/1 /GLVBK/.18811365 /Comment. STA 4 2/23/2002 2.875 7,132.0 5,041.0 50.92 GAS LIFT MERLA/TMPD /1 /DMY /BK/ / /Commem: STA 5 7/18/1997 2.875 SURFACE , 7,686.0 5,383.2 52.90 GAS LIFT MERLA/TMPD /1 /GLV /BK/ .188/1352 / Comment: STA6 2/22/2002 2.875 (QC), 3,771 8,249.0 5,725.6 51.38 GAS LIFT CAMCO /MMG- 2/1.5/OV/RK/.156// Comment BURST @ 2/23/2002 2.920 5000 PSI, COLLAPSE @ 3000 PSI STA 7 GAS LFT, _ _ __ 4. fiat' 8,816.0 6,065.2 56.07 GAS UFT CAMCO/ MMG- 2 /1.5/DMY /RK// /Comment: BURST @ 5000 10/19/1993 2.920 PSI, COLLAPSE @ 3000 PSI STA 8 8,859.0 6,089.0 56.82 PBR Baker PBR 10/27/1989 3.000 GAS LIFT, _ r ,, 8,873.0 6,096.6 56.68 PACKER Baker 'FIB' PACKER 10/27/1989 2.892 6,051 8,910.0 6,116.9 56.95 NIPPLE 2.81" Otis 'X2/' Nipple NO GO w/2 75" ID 10/27/1989 2.750 8,943.0 6,135.0 56 57 SOS Baker 10/27/1989 2.992 8,944.0 6,135 5 56.581 TTL 10/27/1989 2 992 GAS61i , , Perforations$ Slots Shot Top (TVD) Bin (TVD) Dens TopjftKB - ] Dint(KB), )BKB) )ftKB) Zone Date (oh... Type - Comment 9,012.0 9,044.0 6,171.3 6,189.4 C4, 2K -08 10/15/1990 6.0 IPERF 2 1/8" Dynasttip, Zero deg. Phasing GAS LIFT, 9,022.0 9,032.0 6,177.0 6,182.7 C-4, 2K-08 1/15/2002 6.0 RPERF 2.5" HSD PJ Chgs, 60 deg ph I 9,100.0 9,140.0 6,219 7 6,240.3 C -4, 2K -08 10/25/1989 2.0 IPERF 4.5" HSD, 180 deg. Phasing '. Stimulations & Treatments Bottom GAS LIFT, R ::' Min Top Max Bttn Top Depth Depth 7,886 k 07 Depth Depth (ND) (TVD) (BKB) (flKB) (BKB) (flKB) Type Data Comment 9,012.0 9,044.0 6,171.3 6,189.4 FRAC 2/18/2002 C -SAND FRAC, 46#M16/20 PROPPANT, 5.5 ppa ' ON PERFS Notes: General & Safety I ' End Date Annotation GAS LFT_ •% e,I2as «„ 4/2112006 NOTE: Tagged Obstruction @ 8253' WLM 11/1/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 ■ t', 11/7/2010 NOTE: TAGGED OBSTRUCTION @ 8976' SLM - i GASL _.._. t 81 6 f P09,8,859- 1 PACKER, 8,873 i NIPPLE, 8,910 t SOS, 8,943 -, l'ii TTL, 8,944 - _____ . I RPERF, 9,022-9,032 IPERF, a.. PERF, 9,0 FRAC, 9,012 RAC, 12 ' -- IPERF,__ _ _ ' 9,100- 9,140 ... PRODUCTION - (OC), 9,423 �_ TD, 9,445 i i • • 2K -08 P &A PTD # 189 -083 The objective of the proposed 2K -08 P &A of is to prepare this well for a Rotary Sidetrack to be followed by coil tubing drilled laterals. A May 2011 rig sidetrack is planned to move the current 2K -08 bottom hole location away from nearby faults believed largely responsible for production underperformance. 2K -08 has been shut -in since 2006 due to low production caused by nearby faults, and due to rocks and sand covering the perforations which cannot be cleaned out due to a hard obstruction existing in the . perforations. This obstruction is thought to be possible collapsed casing. A 2K -08 pump -in test on 11/7/10 failed. Little or no injectivity currently exists to the formation. . On 1/27/11, SBHP at 8900' RKB = 4008 psi. 2K -08 also has IA x OA communication which is believed due to a leaky packoff that has existed since initial completion. 2K -08 laterals will be placed on production after CTD drilling is completed in late summer 2011. T c o l c v W t 1 / 445 lee* S` Poo c Ptodvicer fro•s 7 e j..4 e,'7 Proposed P &A: lKf rtf. /oU bor fo / r4r Aft Sri r «,f 0-4 0: I icVt. cle. ,'re loN. 6 0R we . ReroCa "fr wea4ore a 4e Slickline: re? d v e gait (e CQver /vol 144 oiz ew o' the Of� ��� �/ (att�gk f1� r��Y' �' ✓ 1) Set XN Plug at 8910' RKB in the 2.81" Otis XN Nipple NO GO with 2.75" ID. PT XN Plug to 2500 psi on the tubing to verify a good plug set. l 2) Function test LDS. /3) Set Catcher sub on top of XN Plug at 8910' RKB. /4) Pull DV at 8816' RKB (St #8) and leave pocket open for cement placement to IA. A CMIT will not be performed due to known IA x OA communication via leaky packoff. 5) Pull Catcher Sub from top of XN Plug at 8910' RKB. Coil Tubing: 6) RU CTU & PT equipment. Notify AOGCC Inspector (659 -2714; pager 659 -3607) of date and time of cement P &A operation. Mix -15 bbls ( -75 sxs) of Class G cement with additives, to prepare to pump 13 bbls ( -65 sxs) of cement down coil. Q- ( - Cement volume for P &A: • 0617 7# (XN Plug 8910' - Tbg TOC 8500)(0009714)(2.992 = 3.57 bbls needed in Tbg. / ( g 9 g� � 0.20'g (Packer 8873' - IA TOC 8500')(.0009714)(6.151 — 3.5 = 9.27 **Is needed in IA. ✓ Total cement needed = 12.84 bbls. Pump a cement total - 13.00 bb RIH with CT to 8880' circulating Slick SW at 0.5 - 1.5 bpm down coil to establish rate and pressure while taking returns from IA via open GLM pocket at 8816' RKB. Due to IA x OA communication, monitor and bleed the OA while circulating, if needed. With nozzle at 8880' RKB, circulate Slick SW, then swap to pumping 13 bbls of Class G cement down coil to the nozzle while taking 1:1 returns from the IA. Stabilize rate to 0.7 bpm as lead cement nears nozzle. • With nozzle at 8880' RKB, pump cement at 0.7 bpm through nozzle and spot the first 0.5 bbl of cement on top of the XN Plug at 8910' RKB. After first 0.5 bbl of cement exits nozzle, PU nozzle at 21.3 fpm to 8500' RKB. Let all remaining 12.5 bbls of cement exit nozzle at 0.7 bpm while taking 1:1 returns from IA. POOH at 21.3 fpm while cementing at 0.7 bpm and taking all returns up the IA enables TOC to rise at identical rate up tubing and IA, which ensures keeping cement away from target tubing cut area. Shut in IA as soon as the nozzle arrives at 8500' RKB and the last barrel of cement has exited the nozzle. Do not overdisplace cement to IA through open mandrel pocket. Estimated TOC after all cement exits nozzle will be +/- 8500' RKB in the tubing and IA. Tubing will be E -line cut at —8274' RKB and Rig -ST kickoff point is —8130' RKB. After IA has been SI with the CT at 8500' RKB, swap to pumping Biozan to POOH with CT circulating out contaminated cement to tanks via CT x Tbg annulus. FP upper 2500' of tubing with 22 bbls Diesel. RD CTU. Slickline: 7) WOC 24 hours. Notify AOGCC Inspector (659 -2714; 659 -3607 pager) of the timing of the post - cement plug tag and PT. RIH & drift tubing to PBTD (TOC) with 2.80" gauge. PT cement plug to 2500 psi on the tubing; hold for 30 minutes. Due to known IA x OA communication believed to exist via a leaky packoff, a PT on the IA is not requested. Record test results. Perform a drawdown test by bleeding down the tubing, IA and OA pressure to open top tank. Tubing & IA should bleed to 0 psi to verify good cement P &A integrity. E -line: 8) RIH with cutter with anchor arms for 3 -1/2" tubing, and cut the tubing at 8274' RKB. This puts the cut near the middle of the first full joint below GLM #7 at 8249' RKB. This location is —283' below planned sidetrack KOP of 7966' RKB. POOH with E -line. Pump diesel down tubing while taking returns from IA noting rates and pressures to verify likelihood of a successful cut. RD. 9) Set BPV & VR Plug. Pull well house and prepare site for the rig. Notify Wells Group .� of well status. • • Rig Operations: 1) Move on and rig up Doyon 141 on 2K -08. 2) Circulate well with seawater through tubing cut at +/- 8274' MD displacing diesel. - 3) Nipple down tree and nipple up BOP. Test BOPE to 250 psi low and 3500 psi high. ' 4) Pull and lay down 3 -1/2" hanger and tubing. , 5) Run 7" casing scraper to top of tubing stub. 6) Rig up a -line and run gyro /caliper in 7" casing. 7) Using e -line perforate at 7988' — 7998' MD for cement squeeze. 8) Set 7" cement retainer bottom at 7987' MD with 4" drill pipe and squeeze 4.5 bbls cement (200') to allow for kickoff. 9) Nipple down BOP and tubing head. Pull 7" packoff and expect casing growth. 10) Run 7" casing spear and engage 7" casing with overpull. Cut excess casing and reset slips. 11) Install 7" packoff, nipple up tubing head and BOP. Retest same. P£P 12) Test 7" casing. 13) Set whipstock placing top of window at 7966' MD. 14) MiII 6 -1/8" window and 20' of new formation to 7999' MD. Perform FIT to 16 ppg. 15) Run 6 -1/8" intermediate drilling BHA and drill to TD of 9891' MD. r 0 • 2K-08A Rotary Sidetrack — CTD Setup ' • 16' 62_5P H -40 upper Completion Top AiI I TSD A P . 115' hID ' 115.117 1) 1-':: ' TRNIAZ'X -cur SSSV 2.812" ID "X" Profile ® s` .'X1 "KBMGGLM2867'ID 3) 3- X -867 ' ID 4) Baker GBH -22 8040 Bow Seal Assembly Arctic Set 29 Vats -1072' Lower Completion Top MD r/ TNT) , , 5) Bo er 5" X : " L-80 C-2 2 Liner Top Packer =°'' 9- 51,. 36.00 155 6) Bakff 5" X 7'° L-80 Fleslock Liner Hanger sill 3 > ?71' h IIl; , -90�° I E D ) Seal Bore Eetension n TKC' coupling S HES ' ' Nipple 1-.81' M 9) Baker Landing Collar Tspe I 3 " -" Liner Top Es 3 -1:2 9.30 L -80 Ei E -M 7,760' ? 5.427 TOL - Szuface Sidetrack KOP thru window in 7 7,966 2 5,549' HRZ 8,345' / 5,770' 7" Cement Retatne L -4 .. ' , 7,984' 5,343' 1. \, 7" Perforations I I = \\\\\ Upper Katubik 9,225' f 6,062' 7,988' - 7,995 ` \\\ / Tubiag Cut Lower Kaki* 9,312' f 5,905' 82' 4° ' 5,742 B-'4" S 7' TOE. UK/ 5.756 '` C -Sand 9,538' f 5,980' A&A TOC `� \` //' A -Sand 9,625' t 6,160' C 2 Opec • 3.S1 6:65' � ?M . BakerI -B Parke_ S. S 09.' ' 2. SEs" Oas?C' t3 ' at: 11 - ..9-301, -80 FBT- 1,1 t8" - open Hole'1D _- PerforatPerforations (2,1 1) 9 D 6,-x#7' Tt7D' 9.891' MD , 6 248' T 'D - 9,012' — 9,041' -e - 9.022' —9,032° ------ - - - 9,100'— 9,140° 7" 26# J-55 came Revised try 9.4,3' MID 6 Dm Elmo Cecchetti March 3, 2011 410 • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 / form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on f both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve / D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 ( AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accu racy. Thanks, Steve D. file: / /F: \Daily_Docum.ent_ Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 3/7/2011 Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, February 14, 2011 9:34 AM To: 'Peirce, John W Subject: RE: 2K -08 Pre -Rig ST Plug and Abandonment (PTD 189 -083) John, I looked the procedure over and have a couple of comments. 1) Commission will not require a FCO to uncover perfs. 2) I think it would be better to put a CIBP in the tubing tail at approx. 8900' md. Then cement as you stated through the GLM ( IA and tubing with cement to 8500') ... Guy Schwartz Senior Petroleum Engineer a , FEB 2011 AOGCC 793 -1226 (office) 444 -3433 (cell) From: Peirce, John W [mailto: John .W.Peirce @conocophillips.com] Sent: Friday, February 11, 2011 3:31 PM To: Schwartz, Guy L (DOA) Subject: Re: 2K -08 Pre -Rig ST Plug and Abandonment Guy, We're Sidetracking 2K -08 in May '11, so I'm working on a 2K -08 Pre -Rig ST P &A. I have a question for you before sending a 10-403 for approval. 2K -08 is a single packer well with A & C perfs below the tubing tail. It has possible collapsed 7" casing, and it has rocks & gravel covering all of the perfs. This well has had 4 Fracs. Currently we cannot inject into the well. Last CT FCO in 2006 yielded Tots of sand & rocks in returns. Post -FCO tags showed sand & rocks returned back above all the perfs, and we've run into shallow fill bridges in the tubing. The well has low production rate and freezes off, so it's been SI since mid -2006. 2K -08 has IA x OA due to leaky PO. Our planned rig -ST KOP is - 8130' MD. CTD will come in to drill laterals after the rig ST. For the P &A, does AOGCC require an FCO attempt of sand / gravel with possible collapsed 7 "casing to try to reestablish injectivity for a cement squeeze of the formation? My concern is risk of getting coil stuck, plus no guarantee we'll achieve the objective of regaining injectivity to enable cement placement to the formation. Thus, I request your feedback or any concerns regarding my preliminary P &A proposal: 1) SL tag (to verify PBTD), 2) Optional E -line tubing punch TT at 8890' (to enable cement placement behind 3.5" TT from bottom of TT to near the base of the Packer at 8873'), 3) SL pull DV at 8816' (leave pocket open for cement placement into IA above packer), and pull GLV at 7686' (leave open to take returns up CTxTbg during step #4), 4) CT set Cmt Retainer at 8795' in 1st full joint just above GLM at 8816' (open pocket). Pump 15 bbls CI G Cmt through Cmt Rtr taking returns up CT x Tbg from by way of the IA via the open pocket at 7686'. Note, first 15 bbls of cement will fill 7" Csg from top of fill at 9105' to base of packer, and IA above packer to 8495', plus all the 3.5" tbg below the retainer. PU off cement retainer and pump last 2.5 bbls of cement on top of retainer. Total cement pumped is 17.5 bbls. Est.TOC in Tbg & IA will be 8500' for total cement plug length of +/- 600'. WOC. 5) SL Tag TOC (verify TOC is -8500') 6) E -line Cut tubing at -8274' MD 7) Set BPV, pull well house, prep site for rig. 2/14/2011 • Page 2 of 2 1 110 Rig: MIRU, set CIBP at XXXX' (per Well Plan) then KO at 8130' per Well Plan. Thanks, John Peirce Wells Engineer CPAI Drilling & Wells (907)- 265 -6471 office 2/14/2011 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a short list of wells fi'om the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. The top-fill operation was completed on August 24, 2003. Dowell-Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender for each well. The cement was pumped from the bottom of the void to the top of the conductor on each well via high pressure hose. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call Nina Woods or me at 907-659-7224, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Problem Well Supervisor Attachment CANNEC' SEP 0 8 20t]3 ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field WELLS PTD# TOC VOLUME TYPE SACKS ft BBLS Cement 1H-01 1930060 18.0 3.74 Prod 22.6 1 H-21 1930460 21.0 3.66 Prod 22.1 '-~ 2K-08 1890830 6.0 1.8 Prod 10.9 3M-09 1870290 46.0 8.32 Prod 50.2 3M-10 1870350 52.0 10.1 Inj 61.0 3Q-03 1911260 14.5 3.44 Prod 20.8 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 March 18,2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2K-08 (189-083) Dear Commissioner Oechsli Taylor: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent frac operations on the KRU well 2K-08. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad Alaska Oi & Gas Cons. Commission gnchora!zle STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 154 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 5157' FNL, 94' FEL, Sec. 2, T10N, R8E, UM (asp's 498310, 5938425) 2K-08 At top of productive interval 9. Permit number / approval number 1099' FSL, 765' FEL, Sec. 3, T10N, R8E, UM 189-083 / At effective depth 10. APl number 50'103-20111 At total depth 11. Field / Pool 4066' FNL, 1122' FEL, Sec. 3, T10N, R8E, UM (asp's 492002, 5939520) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 9445 feet Plugs (measured) true vertical 6425 feet Effective depth: measured 9205 feet Junk (measured) true vertical 6309 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 15o sx 115' 115' SUR. CASING 3770' 9-5/8" 110o sx AS III, 520 sx Class G 3770' 2920' PROD. CASING 9423' 7" 200 sx Class G 9423' 6414' Perforation depth: measured 9012' - 9044', 9100' - 9140' true vertical 6208' - 6225', 6255' - 6275' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 8944' MD. Packers & SSSV (type & measured depth) BAKER 'HB' @ 8873' MD. CAMCO TRDP-1A-SSA @ 1820' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attachment Treatment description including volumes used and final pressure 14. Representative Daily Avera,qe Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation SI - Subsequent to operation 202 515 280 - 240 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ X Gas __ Suspended __ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney263-4574 Signed Title: Wells Team Leader Date ~ ~_/~ Michael Mooney . Prepared b~/ Sharon AIIsup-Drake¢ 263-4612 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE Date Comment 2K-08 Event History 02/18/02 02/20/02 02~1~2 PUMPED FRAC AT 15 BPM USING 50# X-LINKED GEL DURING PAD AND SWITCHED TO 40# X-LINKED GEL DURING PROPPANT STAGES DUE TO HIGH FRICTION PRESSURE. SCREENED OUT WITH 5.5 PPA ON PERFS. PUMPED A TOTAL OF 64,381 LBS OF 16/20 CERAMIC PROPPANT. PLACED 46,397 LBS OF PROPPANT BEHIND PIPE AND LEFT 17,984 LBS OF PROPPANT IN WELLBORE. PERFORMED A FCO TO 9200' ,( APROX. 9220' RKB), CTMD. RETURNS 1-1+ ALL DAY. WELL FREEZE PROTECTED TO 3500'. LEFT WELL SHUT IN FOR WIRELINE TO RE-RUN LIVE GLV'S, AND TO PULL THE FRAC SLEEVE @ 1791' WLMD. 120" LONG, 2.850" NO GO, 2.29" ID. SIWHP = 1360# PULL FRAC SLEEVE @ 1820' RKB. TAG @ 9205' RKB. EST 65' OF RAT HOLE.IN PROGRESS. [SSSV WORK, TAG] 02/22/02 02/23/02 PULLED 1" DV'S @ 6574' & 7686' RKB. SET GLV @ 7686' RKB.MADE SEVERAL ATTEMPTS BUT WAS UNABLE TO PULL 1.5" DV @ 8816' RKB.IN PROGRESS. INSTALL 1" GAS LIFT VALVES PER DESIGN.PULLED DV & SET 1.5" X 5/32" OV @ 8249' RKB. TESTED VALVES W/750 PSI DP. JOB COMPLETE. [GLV] Page 1 of I 3/15/2002 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 February 19, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of gundry Well Operations 2K-08 Dear Commissioner Oechsli Taylor: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforations on the KRU well 2K-08. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad : Re. CEivED Alaska Oil & Gas Coils. Commission Anchorage, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 995 t0-0360 Perforate _X Other _ I5. Type of Well: Development Exploratory Strafigraphic , Service 6. Datum elevation (DF or KB feet) RKB 154 feet 7. Unit or Property name 4. Location of well at surface 5157' FNL, 94' FEL, Sec. 2, T10N, RSE, UM At top of productive ir:terval 1099' FSL, 765' FEL, ,..Sec. 3, T10N, RSE, UM At effective depth (asp's 498310, 5938425) At total depth 4066' FNL, 1122' FEL, Sec. 3, T10N, RSE, UM (asp's 492002, 5939520) 8. Well number 2K-08 189-083 / 10. APl number 50-103-20111 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 1 15' SUR. CASING 3616' PROD. CASING 9269' 9445 feet Plugs (measured) 6425 feet 9072 feet Junk (measured) 6240 feet Size Cemented Measured Depth 16" 150 sx (approx) 115' 9-5/8" 1100 sx AS III, 520 sx Class G 3770' 7" 200 sx Class G 9423' True vertical Depth 115' 2920' 6414' Perforation depth: measured 9012' - 9044', 9100' ~ 9140' true vertical 6208' - 6225', 6255' - 6275' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 8944' MD. Packers & SSSV (type & measured depth) BAKER 'HB' @ 8873' MD. CAMCO TRDP-1A-SSA - SET FRAC SLEEVE (120") 1/20/02 @ 1820' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Averaqe Production or Injection Data Gas-Mcf Water-Bbl SI Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations .__X Oi1_ X Gas~ Suspended__ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedMichael Mooney/¢f/~~/'Ct/J,C/J¢"~ Title Wells Team Leader 7 - Form 10-404 Rev 06/15/88 · Questions? Call Mike Mooney 263-4574 Date -g-?/~~ Prepared b~/ Sharon A//sup-Drake 263-4612 SUBMIT IN DUPLICATE Date Comment 2K-08 Event History 01/09/02 01 / 14/02 01/15/02 01/16/02 01/17/02 TAGGED @ 9141' RKB, EST 1' OF RATHOLE; DRIFTED TBG W/2.62" X 10' HC TO 9141' RKB [PERF, TAG] A'I-FEMPT PULL GLV @ 7686' RKB, TOOLS FAILED TWICE. [GLV] RE-PERFORATED C SAND INTERVAL @ 9022'-9032', W/2.5" HSD, 6 SPF (10') GUN, NOTE: TAGGED TD @ 9116', LEFT WELL SI. [PERF] INSTALLED DV'S @ 2772',4976',6574',7686' RKB. TAGGED FILL @ 9131'RKB. EST 9' FILL. [TAG, GLV] LOADED IA W/SW & DIESEL CAP. PTTBG & CSG GOOD. BLED OA. * .... OA SHOULD BE MONITORED DURING FRAC ..... [PT TBG-CSG] 01/18/02 01/2 O/O2 PUMPED 1300# 20/40 RIVER SAND FROM SURFACE TO COVER "A" SAND PERFS, FLUSH 2 BBL SHORT OF TOP PERF. TUBING FP'D WITH 20 BBL DIESEL. TAGGED SAND PLUG @ 9072' RKB. GAUGED TBG (2.86") TO 1820' RKB. SET FRAC SLEEVE @ 1820' RKB. [TAG] Page I of I 2/11/2002 STATE OF ALASKA ALA~, .,~ OIL AND GAS CONSERVATION COMMISS~.,~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other ~ 2. Name of Operator ARCO Alaska, 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 121' FSL, 1460' FEL, Sec. 2, T10N, R8E, UM At top of productive interval 1099' FSL, 765' FEL, Sec. 3, T10N, R8E, UM At effective depth 1184' FSL, 1045' FEL, Sec. 3, T10N, R8E, UM At total depth 1214' FSL, 1122' FEL, Sec. 3, T10N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 9445 6424 feet feet 6. Datum elevation (DF or KB) RKB 154 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-08 9. Permit number/,.a~t~.r.~val numbre~.c.~ -88-83 O 10. APl number 5o-103-20111-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 9 3 41 true vertical 6374 feet feet Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 3 7 3 5' 9 - 5 / 8" Intermediate Production 9396' 7" Liner Perforation depth: measured 9012'-9044', true vertical 6208'-6225', Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 8944' Packers and SSSV (type and measured depth) Cemented 150 Sx (Approx) 1100SxAS III& 520 Sx Class G 200 Sx Class G Measureddepth 115' 3770' 9423' 9100'-9140' 6255'-6275' Packer: Brown HB @ 8873'; SSSV: Camco TRDP-1A-SSA @ 1820' 13. Stimulation or cement squeeze summary Fracture stimulate 'A' Sands on 7/20/97. Intervals treated (measured) 9012'-9044', 9100'-9140' Treatment description including volumes used and final pressure Pumped 137.5 Mlbs of 20/40 & 12/18 ceramic proppant into formation, fp was 7800 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure True vertical depth 115' 2920' 6414' RECEIVED 22 Naska 0il & Gas Cons. 60mmissio.n Anchorage Tubing Pressure Prior to well operation 78 7 87 1224 266 Subsequent to operation 108 10 71 1227 274 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form "10-404 Rev 06/~5~r8 ~'~'"]"~ ~.~..~ '~'~,~ Title Wells Superintendent Date i)_-17-?7 SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT ~ K1(2K-08(W4-6)) WELL JOB SCOPE JOB NUMBER 2K-08 FRAC, FRAC SUPPORT 0716971735.1 DATE DAILY WORK UNIT NUMBER 07/20/97 "A" SAND REFRAC DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR 2 i~ Yes (-~ NoI i~ Yes (~ No DS-GALLEGOS CHANEY FIELD AFC~ CC~ DAILY COST ACCUM COST Signed ESTIMATE KD1379 230DS28KL $1 1 1,968 $125,509 Initial Tbq Press Final Tbq Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 1 975 PSI 2500 PSI 600 PSI 500 PSII 1 300 PSII 1 200 PSI DAILY SUMMARY "A" SAND FRAC COMPLETED. SCREENED OUT BACK TO SURFACE. INJECTED 137461 LBS OF PROP IN THE FORMATION W/8.7# I PPA OF #12/18 @ THE PERF'S. MAXIMUM PRESSURE 7800 PSI AND F.G. (.97/ TIME 09:30 12:15 12:30 13:30 14:30 LOG ENTRY MIRU DOWELL FRAC EQUIP, LRS HOT OIL TRK, AND APC VAC TRUCK. HELD SAFETY MEETING (16 ON LOCATION). PT'D BACKSIDE LINES TO 4000 PSI AND RAISED THE INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 10000 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW @ 25 TO 15 BPM. VOLUME PUMPED 470 BBLS. USED 9931 LBS OF #20/40 PROP. MAXIMUM PRESSURE 8300 PSI AND ENDING PRESSURE 4800 PSI. S/D AND ISIP @ 2961 PSI W/ F.G. OF (.92). STOOD-BY AND MONITORED WHTP, PULSED FOR CLOSURE. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 242 BBLS. MAXIMUM PRESSURE 6000 PSI AND ENDING PRESSURE 5300 PSI. S/D AND OBTAINED ISIP OF 3272 PSI W/A F.G. OF (.97). STOD-BY AND MONITORED WHTP FOR CLOSURE. PUMP FRAC W/50~ DELAYED XL GW @ 5 TO 15 BPM. SCREENED OUT BACK TO SURFACE. PUMPED 159970 LBS OF PROP (19822 LBS OF #20/40 & 140148 LBS OF #12/18). INJECTED 137461 LBS OF PROP IN THE FORMATION W/ 8.7# PPA OF #12/18 @ THE PERF'S. LEFT 22509 LBS OF PROP IN THE WELLBORE. VOLUME PUMPED 2110 BBLS. MAXIMUM PRESSURE AND ENDING PRESSURE 7800 PSI. 17:30 STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D LRS TRUCK. 18:30 19:30 REMOVED TREESAVER (LOST 15% OF CUPS). CONTINUED R/D. R/D COMPLETED AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $442.00 APC $6,400.00 $6,400.00 DIESEL $250.00 $250.00 DOWELL $103,118.42 $103,118.42 HALLIBUI=iTON $634.59 $9,423.96 LITTLE RED $2,200.00 $5,875.00 TOTAL FIELD ESTIMATE $112,603.01 $125,509.38 ARCO Alaska, Inc. Post Office Box 000360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 13, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive .Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate is a Report of Sundry Well Operations (Form 10-404) notice in the Kuparuk field. The well is listed below. WELL ACTION 2K-08 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA Al,~.,r~ OIL AND GAS CONSERVATION COMM~,....K~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Stimulate ~( Pull tubing Alter casing . Repair well Plugging Perforate Other 2. Name of Operator 5. Type of Well: Development ~V~ ARCO Alaska. Ir~. Exploratory _ 3. Address Stratigraphic .- ip. O. Box 100360, Anchorage, AK 99510 Service Q _ 4. Location of well at su'rface 121' FSL, 94' FEL, SEC.2, T10N, R8E, UM At top of productive interval 1099' FSL, 765' FEL, SEC.3, T10N, R8E, UM ~ ...... At effective depth 1184' FSL, 1045' FEL, SEC.3, T10N, R8E, UM At total depth 1214' FSL, 1.122' FEL, SEC.3, T10N, R8E, UM 12. Present well condition summary Total Depth: 6. Datum elevation (DF or KB) 154' RKB feet 7. Unit or Property name KuParuk River Unit 8. Well number 2K-08 9. Permit number/approval number 10. APl number 50-103-20111 11. Field/Pool Kuparuk River Oil Pool measured 9445' feet Plugs (measured) true vertical 6424' feet Effective depth: measured 9341' feet Junk (measured) true vertical 6374' feet Casing Length Size Cemented Structural 115' 1 6" Conductor 3770' 9 5/8" 1100 SX AS III & Surface 520 SX CLASS G Intermediate Production 9423' 7" 200 SX CLASS G Liner Perforation depth: measured 9012'-9044', 9100'- 9140' true vertical 6208'-6225', 6255'-6275' Tubing (size, grade, and measured depth) 3 1/2" 9.3#, EUE, ABMOD, IPC, 8944' Packers and SSSV (type and measured depth) SSSV: CAMCO TRDP-1A-SSA, 1820', PACKER: BROWN HB, 8873' Measured depth 115' 3770' 9423' True vertical depth 115' 2920' 6414' RECEIVED .... ~'a Ui[ & Gas Cons. Commission Anchora,q~:: 13. Stimulation or cement squeeze summary Hydraulically fractured A&C Sands with crosslinked gelled water and 16/20&12/18 Mesh Carbolite. Intervals treated (measured) 14, Treatment description including volumes used and final pressure Placed 63,300 lbs 16/20&12/18 Mesh Carbolite and 1003 bbl gelled water. Final WHTP = 3561 psi. Representative Daily Averaoe Production or Iniectlon Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 189 128 81 1025 280 . 264 ~ 1007 29 1500 234 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Water Injector __ Daily Report of Well Operations ~-".. Oil X Gas Suspended 7. i hereby ce_.rtify that the foregoing is true and correct to the best of my knowledge. Signed. ?~,~t, ~ Tit,e Senior Engineer , , Service Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Post ,Office Bo× 100360 Anchora~je, A~aska 995'~0-03,~0 Telephone 907 276 I2t5 October 31, 1990 RECCEIVED Mr. L. C. Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith' Attached in duplicate is a Report of Sundry Well Operations for the well listed below. WELL AOTION 2K-08 Perforate If you have any questions, please call me at 263-4241. P. S. White Senior Operations Engineer CC.' J. R. Brandstetter ATO 1120 L. L. Perini ATO 1130 S. M. Renke ATO 1126 KOE1.4-9 w/o attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM,v~IS,b~ON REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: 2. Name of Operator ARCO Alaska. Inc. 3. P. Operation Shutdown Plugging Pull tubing Alter ... Address O. Box 100360, Anchorage, AK Stimulate casing Repair well 5. Type of Well: Development X Exploratory _ Stratigraphic _ 99510 Service 4. Location of well at surface 121' FSL, 94' FEL, Sec. 2, T10N, R8E, UM At top of productive interval 1099' FSL, 765' FEL, Sec. 3, T10N, R8E, UM At effective depth 184' FSL, 1045' FEL, Sec. 3, T10N, R8E, UM R8E, UM 1 At total depth 1214' FSL, 1122' FEL, Sec. 3, T10N, Present well condition summary Total Depth: measured 9 true vertical 6 12. Perforate X Other 6. Datum elevation (DF or KB) 154' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-08 _9. Permit number/approval I10. APl numbor 5o-103-20111 11. Field/Pool Kuparuk River Oil Pool feet. number 445' feet 424' feet Plugs (measured) Effective depth: measured 9341 ' true vertical 6374' feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 115' 16" 3770' 9 5/8" 9423' 7" measured 9100'-9140' true vertical 6255 '-6275' Tubing (size,-grade, and measured depth) 3 1/2" 9.3#, EUE, ABMOD, IPC, 8944' Packers and SSSV (type and measured depth) Cemented 1100 Sx AS III & 520 Sx Class G Measured depth True vertical depth 115' 115' 3770' 2920' 200 Sx Class G 9423' 6414' ECEIVED i'0V U 6 I9.90 .Oil & Gas Cons. Co. mmissiOr~ SSSV: Camco TRDP-1A-SSA, 1820', Packer: Brown HB, 8873' "i ~J1choraffe, 13. Stimulation or cement squeeze summary Perforate C Sand interval from 9012' - 9044' MD-RKB @ 6 SPF, O° Phasing Intervals treated (measured) Treatment description including volumes used and final pressure 14. Re0resentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 717 409 - 0 - 1000 283 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations . X. 832 578 -0- 1050 279 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I here.by certify that the foregoing is true and correct to the best of my knowledge. .Sic, tned~~'~' (~~ Title ~~ ~"~~ ~'/[,~ Date /0-.~/~:~) Form 10-404 Rev 09/12/90 ~/ SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company " C~rno~ ~ ' ' WELL DE~ F WORK 2K-08 KUPARUK 'A' SAND REFRACTURE DA'I~ 'CO-'NTRACTOR/KEYPERSON" 10/22/93 DOWELL- YOAKUM _ 1 9341' [ 9 156' -' 8/6/93 [[ [ i [ i1[ [ KUPARUK RIVER UNIT WELL SERVICE REPORT AFC/CC# . SCA# , [ ,9.98t4~ FIELD COST EST. ]ACCUMULATED COST"' $127,167 [ $133,624 I I I II ,S$8V TYPE I STATUS CAMCO 1A-SSA, OPEN II II I II I I I II I I I I I Il Il I I IIl~ I Ill . I 0700 MIRU FRAC EQUIPMENT, QC GEL, HOLD SAFETY MEETING. , 084.5 PRIME AND PFF EQUIPMENT. TO 10,000 PSI. .... 1000 PUMP STAGES AS FOLLOWS: i~T~] 1,.~,~s~VOL.! BREAKDOWN W/SLK WTR PI #1 W/SLK WTR ,., 25 I. 6257-62,30_ I 25. I,, 3520 PI ~t2 W/SLK WTR °! ,~ !",, ,2oo-~,d ! ~ I' '~0 I, ' BREAI~[ 0WN'FLUSH W/NXL GW DATA FRAC W'/DXL-GW DATA FRAC FLUSH W/NXL-GW EX. FR = 750, MTR -- 98%, FL. EFF. -- 28% I,, !- I , ,I ....... I I, I Xlcm~cx~ Tins Weather 7" CSG [, ,FWHTP [ ISIP/FG/CLOSE [1 .... 59~, ] 2884/.9.015260 [ [ [ 5660 [ 2992/.92/5400 , 56..30I 30501.93/5480 [,[ , 5772 [ 2746/.8.8/5160 BLOCK IF SUMMARY IS CONTINUED ON BACK II , RepoR INCOMPLETE =uos~amry o~ Aimn~c Richfield e:LL CONTRACTOR FIELD. DISTRICT- STATE OPERATION AT REPORT TIME C o~ eL ~0 REMARKS ..:: :'CosT: / 2 o 77 ~' ' 0~00 His to,vo Ct~ LO~TH ~ .3Z 2.~/e OY~ .~1~0 Lo6 r'~¢ tM 5T~ P i-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ' ADDENDUM WELL 2K-8 4/24/90 Frac Kuparuk "A" sand perfs 6764'-6796' @ 2 spf 180 deg ccw in eight stages as follows. Stage 1: Stage Stage Stage Stage Stage Stage Stage Prop 150 bbls YF240 prepad @ 25 bpm 7610-5140 psi 60 bbls YF240 prepad @ 20 bpm 4760-4880 psi 45 bbls YF240 prepad @ 15 bpm 4390-5230 psi 30 bbls YF240 prepad @ 10 bpm 4730-5225 psi 2:70 bbls Slick diesel flush @ 25-15 bbm 6360-4420 psi 3:1200 bbls YF240 pad @ 25 bpm 6050-4970 psi 4:83 bbls YF240 w/2 ppg 16/20 Carbolite @ 25 bpm 4970-4700 psi 5:85 bbls YF240 w/4 ppg 16/20 Carbolite @ 25 bpm 4700-4570 psi 6:87 bbls YF240 w/6 ppg 16/20 Carbolite @ 25 bpm 4570-4780 psi 7:93 bbls YF240 w/8 ppg 16/20 Carbolite @ 25 bpm 4780-5180-5190 psi 8:26 bbls YF240 Flush 20 bbls YF240 Slick diesel flush @ 20-18 bpm 8660 psi Screened out to 8660 psi Fluid to recover: 1743 bbls Sand in zone: 70,550 lbs Sand in csg: 9370 lbs Avg pressure: 4800 psi D~l~n~~p-ervi s or -- Date ARCO Alaska, Inc. Date: January 19, 1990 Transmittal Ct: 7650 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. signed copy of this transmittal. I2K - 0 7 5" Acoustic Cement Bond Log 22 K 07 5" PET Log K 0 8 5" Acoustic Cement Bond Log K 1 3 5" Acoustic Cement Bond Log Please acknowledge receipt and return one 09-27-89 10-20-89 09-27-89 1 I-05-89 5144-7993 6570...-8016... 6384-9315 6400-9464 Receipt Acknowledged: RECEIVED JAN2 zt 1990 i~,~Se..ka Oil 8;,~Gas,,,hnraneC°ns' COm~[sSlO'p' Il lily,,--- ,1~ DISTRIBUTION: Drilling NSK State of Alaska(+Sepia) ~ ~',' STATE OF ALASKA " 0 J~ I ~ ~ ~] ,_~ ALASKA ,JIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG' 1. Status of Well Classification of Service Well / OIL ~ GAS ?) SUSPENDED ~_1 ABANDONED ~ SERVICE [] .. 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 8~'83 ,, 3'. Address 8. APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50- 103-20111 z~. Location of well at surface ir- , ,L . 9. Unit or"L;ase Name j OCAT~ON.S: Kuparuk River Unit 121' FSL, 94' FEL, Sec. 2, T10N, R8E, UM ! VERIFIED " .... At Top Producing Interval 10. Well Number 1099' FSL, 765' FEL, Sec. 3, T10N, R8E, UM ~ 2K-8 At Total Depth I. ~.~,)/7-N i 1. Field and Pool 1214' FSL, 1122' FEL, Sec. 3, T10N, RSE, UM Kuparuk River/ 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 154' RKB I ADL:25589 ALK:2675 Kuparuk Oil Pool ..... 12. Date Spudded 13. Date T.D. Reached 14. Da.re Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions / 08/24/89 8/31/89 /O/.?.. .~'"/~'~ ~ ---,eetMSL 1... 17. TotaIDepth(MD+TVD) 18.PIUgBackDepth(MD+'FVD)lO.D~r~tionalSurvey I 20. Depth where SSSV se, I 21.' ThiCk~ess of Permafros, 9445'MD&6424'TVD 9341 'MD&6375'TVD YES ¢~J NO [] 1819' feet MD ___ 22. Type Electric or Other Logs Run ..... DIL/SP/GR/SFL. FDC/CNL/CAL. CET, Gyro 23. ' CASING, LINER AND CEMENTING RECORD - ......... SETTING DEPTH MD CASING SIZE WT, PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED , , ir-,,, ...... ~;,,~f 115' -- . 9-5/8" 3~ I-r,r, S,-rf 'z77! ' !9-!/4" 1100sx AS 7- 26# J-55 S,jrf 9423' 8-~'' ~nn "'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) '3½" ,9.3#,J"55 8'943 i 8873 ' '" 9100'-9140' MD w/4½" HSD ~ 2 spf ......... 6255 ' -6276' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MAI:ERIAL USED .. . .... ...... · , , 27. PRODUCTIQN TEST '1 Date First Production Method of Operation (Flowing, gas lift, etc.) , . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WA~I'ER-BBL CHOKE SIZE 1GAS'OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure cALCULATED OIL-BBL 'GAS-MCF WATER-BBL CIE 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. REC£!VED ~ ,,;,~.,.. '~ .._ 'q 10407 Submit in duplicate '.1-80 WCl /25 CONTINUED ON REVERSE SIDE 29. 3O. NAME Kuparuk C Kuparuk A GEOLOGIC MARKERS TOPS TRUE VERT. DEPTH 6207' MEAS. DEPTH 9011 ' 9047' 6227' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31, LISl" OF ATTACHMENTS Gyro 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. item 16 and 24: If this well is completed for separate production from more than one.interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ~tem 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 i . ARCO Oil and Gas Company Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a wail is spudded or workover operations are started. Daily work prier to spudding should be summarized on the form giving inclusive date~, on:y. District ARCO ALASKA INC. KUPARUK RIVER UNIT County, parish or borough NORTH SLO?g Lease or Unit ADL: 25589 ALK: 2675 COMPLETIONS Field Auth, or W.O. no. AK3633 State 2K-8 Well no. Operator ARCO Spudded or W.O. begun JDete JHour SPUD ~-:' J 08/24/89 J 00:00 Date and dePth as of 8:00 a.m. 10/26/89 (11) TD: 9445 PB: 9341 SUPV:GB 10/27/89 (12) TD: 9445 PB: 9341 SUPV:GB IARCO w.i. 55.8533 Prior stalus if a W.O. Complete record for each day reported NORDIC #1 PICKUP AND TIH W/TBG 9-5/8"@ 3770' MW: 0.0 NaC1 MOVE RIG FROM 2K-11 TO 2K-8, ACCEPT RIG AT 0900 10/25/89, ND DRYHOLE TREE, NU BOPE, TEST BOPE TO 3000 PSI, RU SOS, PERF 9120-9140 & 9100-9120 AT 2SPF, 180 DEG PHASING, ORIENTED 163 DEG FROM HIGH SIDE, RD SOS, MONITOR WELL - 2 BBL GAIN (NO SI PRESSURE), PICKUP AND TIH WITH OPEN ENDED TBG, CIRC. AT 3100', RETURNS CUT TO 9.3, CIRC, CONT. TIH, CIRC. AT 3600' TO BALANCE TBG, CONT. TIH (TOTAL GAIN 15 BBLS) DAILY:S68,820 CUM:$993,493 ETD:S993,493 EFC:$1,488 RIH W/ COMP STRING 9-5/8"@ 3770' MW: 0.0 NaCl TEST BOP'S. CONT TRIP IN HOLE W/ 3-1/2" TBG TO 7500'. FLUID UNBAL. WT UP TO 10.3 PPG. CIRC AND COND UNTIL 10.3 ALL AROUND. TIH TO 9048'. CIRC BTMS UP. POOH. MU COMP ASSY AND START IN HOLE. WT UP BRINE PILL TO 11.0 PPG AND FILL TBG. CONT IN HOLE SLOWLY. DAILY:S31,472 CUM:$1,024,965 ETD:S1,024,965 EFC:$1,488 The above is c_.~rrect For form preparatiqKa~ld distribution, see Procedures M~ll, Section 10, Ddlllng, Pages 86 and 87. AR3B-459-1-D Number ell daily well history forms consecutively &e they are prepared for each well. jPage no. ARCO uil and Gas Company Daily Well History-Final Report Instructions: ~"re[~are and submit the "Final Report" on the first Wednesday atte~ allowable has been assigned or well is Plugged, Abandoned, or Sold. "Fina~ Report" should De suwnit[ea also when operations are suspen~ted for an indefinite or appreciable length of time. On wo~kovers when an olficial test is pot required upon completion, report completion and representative test data in blocks provided. The "Final Reporl" form may be used for reporting the entire operation if space is available. J Accounting cost center code District I SLate ARCO ALASKA INC. County or Parish NORTH ST,O?R. Field ILease or Unit ]Well no, KUPARUK RIVER UNIT IT~tleADL: 25589 ALK: 2675 2K-8 Auth. or W.O. no. I AK3633 I COMPLETIONS Operator A.R.Co. W.I. ARCO Date 55. 8533 Spudded or W.O. begun SPUD 08/24/89 Date and depth as of 8:00 a.m. 10/28/89 (13) TD: 9445 PB: 9341 SUPV:GB Complete record for each day reported NORDIC fl otal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well IHour IPrlor ~tatus If a W.O. ! 00:00 RIG RELEASED 9-5/8"@ 3770' MW: 0.0 NaCl FINISH RUNNING 3-1/2" COMPLETION, TEST CONTROL LINE, LAND TBG, DROP BALL,SET PKR AT 2500 PSI (TBG OK), PU & SHEAR PBR, RELAND TBG, RILDS, TEST ANNULUSTO 2500 PSI, CLOSE SSSV, TEST SSSV TO 1000 PSI, PRESS. UP AND SHEAR BALL, RELEASE PRESSURE, CLOSE SSSV, SET BPV, ND BOPE, NU TREE, TEST TREE AND PACKOFF TO 5000 PSI, OPEN SSSV, DISPLACE ANNULUS WITH 5 BBLS DIESEL, BULLHEAD 2 BBLS DIESEL DOWN TBG, RELEASE RIG AT 1900 10-27-89 DAILY:S168,412 CUM:$1,193,377 ETD:S1,193,377 EFC:$1,488 Old TD New TD Released rig Date Classifications (oil, gas, etc.) Producing method PB Depth Kind of rig Type completion (single, dual, etc,) IOfficia reservoir name(s) Potential test data Will no. Date Reservoir Producing Interval Oil or gasTest time Production Otl on te~t Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity AIIowabl~ Effective date corrected The above is correct distribution, see Procedures Manu~/MSection 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all dally well history forms consecutively I Page no. as they are prepared for each well. I Dlvliion of AtllntlcRIchflaldCompany October 9, 1989 Mr. Brit Brown Drilling Manager ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 MICROFILMED Re: Boss Gyroscopic Survey Job No. AK-BO-90099 Well: 2K-8 Field: Kuparuk Survey Date: 9/18/89 Operator: T. McGuire Mr. Brown: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Also enclosed is one diskette. As per A. Thompson, copies have been sent to UNOCAL and BP EXPL. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard District Manager Directional Services Enclosures RECEIVED JAN 2 6 ~chor~ 8537 Corbin Drive (99507) · P.O. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522-3432 A Baroid Company SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA, INC. 2K-8 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 DATE OF SURVEY: 9-18-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90099 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -154.00 100 100.00 -54.00 200 199.99 45.99 300 299.98 145.98 400 399.97 245.97 0 0 N .00 E .00 .00 .00 0 37 N 29.90 E .62 .47N .27E 0 41 N 35.40 E .09 1.43N .89E 0 47 N 32.50 E .11 2.50N 1.61E 0 44 N 40.00 E .11 3.58N 2.39E .O0 -.19 -.63 -1.16 -1.75 500 499.97 345.97 550 549.96 395.96 600 599.95 445.95 650 649.86 495.86 700 699.65 545.65 0 28 N 23.60 E .31 4.46N 2.98E 0 49 N 23.20 W 1.22 4.98N 2.92E 2 3 N 63.50 W 3.05 5.71N 1.97E 4 19 N 71.40 W 4.59 6.72N .62W 6 2 N 69.50 W 3.46 8.24N 4.87W -2.17 -2.02 -.97 1.76 6.20 750 749.31 595.31 800 798.82 644.82 900 897.21 743.21 1000 994.57 840.57 1100 1090.54 936.54 7 9 N 68.10 W 2.24 10.32N 10.22W 8 57 N 64.30 W 3.77 13.17N 16.61W 11 32 N 60.80 W 2.65 21.43N 32.37W 14 46 N 62.10 W 3.24 32.27N 52.37W 17 51 N 65.30 W 3.21 44.65N 77.56W 11.83 18.62 35.55 57.11 84.05 1200 1184.89 1030.89 1300 1277.25 1123.25 1400 1367.40 1213.40 1500 1455.17 1301.17 1600 1540.27 1386.27 20 51 N 71.40 W 3.62 56.73N 108.37W 24 11 N 74.70 W 3.56 67.82N 145.02W 27 4 N 76.20 W 2.96 78.66N 186.90W 30 9 N 76.40 W 3.08 90.00N 233.43W 33 10 N 76.60 W 3.01 102.25N 284.47W 116.47 154.47 197.58 245.37 297.75 1700 1622.51 1468.51 1800 1701.72 1547.72 1900 1777.79 1623.79 2000 1850.92 1696.92 2100 1920.72 1766.72 36 10 N 77.70 W 3.06 114.88N 339.93W 39 3 N 79.50 W 3.09 126.91N 399.75W 41 51 N 80.20 W 2.84 138.33N 463.62W 44 7 N 81.30 W 2.39 149.28N 530.91W 47 19 N 80.70 W 3.23 160.49N 601.63W 354.55 415.55 480.43 548.60 620.19 2200 1987.02 1833.02 2300 2050.96 1896.96 2400 2112.38 1958.38 2500 2171.95 2017.95 2600 2230.99 2076.99 49 35 N 81.60 W 2.36 171.99N 675.57W 50 54 N 80.50 W 1.57 183.96N 751.51W 53 16 N 80.20 W 2.38 197.18N 829.28W 53 35 N 80.00 W .35 210.99N 908.40W 54 2 N 80.00 W .45 225.01N 987.88W 695.01 771.88 850.77 931.08 1011.79 2700 2289.62 2135.62 2800 2347.92 2193.92 2900 2405.61 2251.61 3000 2462.87 2308.87 3100 2520.29 2366.29 54 10 N 79.70 W .28 239.28N 1067.63W 54 30 N 79.20 W .53 254.16N 1147.50W 55 1 N 78.80 W .61 269.75N 1227.68W 55 7 N 79.20 W .34 285.39N 1308.16W 54 47 N 79.70 W .53 300.38N 1388.64W 1092.8C 1174.04 1255.7¢ 1337.67 1419.54 RECeiVeD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA, INC. 2K-8 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN 3200 2579.13 2425.13 3300 2639.27 2485.27 3400 2699.16 2545.16 3500 2758.15 2604.15 3600 2816.65 2662.65 53 6 52 57 53 28 54 13 54 10 DATE OF SURVEY: 9-18-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90099 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. N 81.80 W 2.39 313.39N 1468.41W N 81.80 W .16 324.78N 1547.49W N 81.50 W .57 336.41N 1626.73W N 80.90 W .90 348.77N 1706.52W N 80.70 W .17 361.74N 1786.58W 1500.36 1580.22 1660.28 1741.01 1822.11 3700 2876.74 2722.74 3800 2938.33 2784.33 3900 3000.57 2846.57 4000 3063.68 2909.68 4100 3127.20 2973.20 51 56 52 1 51 0 50 44 50 22 N 81.80 W 2.40 373.90N 1865.55W N 82.40 W .48 384.73N 1943.58W N 82.50 W 1.02 395.01N 2021.17W N 82.80 W .35 404.94N 2098.11W N 83.60 W .72 414.08N 2174.79W 1902.00 1980.73 2058.94 2136.44 2213.56 4200 3191.32 3037.32 4300 3255.62 3101.62 4400 3318.99 3164.99 4500 3381.60 3227.60 4600 3444.18 3290.18 49 51 50 6 51 14 51 13 51 17 N 84.10 W .65 422.31N 2251.09W N 84.50 W .40 429.91N 2327.30W N 84.10 W 1.17 437.60N 2404.27W N 84.50 W .31 445.34N 2481.85W N 84.70 W .17 452.68N 2559.50W 2290.14 2366.52 2443.68 2521.45 2599.21 4700 3506.79 3352.79 4800 3569.48 3415.48 4900 3632.25 3478.25 5000 3695.25 3541.25 5100 3758.46 3604.46 51 10 51 10 51 3 50 50 50 44 N 84.80 W .13 459.82N 2637.15W N 85.00 W .16 466.74N 2714.75W N 85.10 W .14 473.46N 2792.31W N 85.60 W .45 479.75N 2869.71W N 85.70 W .13 485.63N 2946.97W 2676.93 2754.58 2832.15 2909.49 2986.62 5200 3822.25 3668.25 5300 3886.57 3732.57 5400 3950.85 3796.85 5500 4014.98 3860.98 5600 4079.06 3925.06 5O 0 49 55 50 4 50 9 50 9 N 83.50 W 1.85 492.87N 3023.63W N 83.70 W .17 501.40N 3099.72W N 83.80 W .16 509.74N 3175.87W N 83.50 W .25 518.23N 3252.13W N 79.30 W 3.22 529.71N 3328.02W 3063.39 3139.82 3216.27 3292.86 3369.60 5700 4143.06 3989.06 5800 4207.13 4053.13 5900 4271.38 4117.38 6000 4336.00 4182.00 6100 4401.01 4247.01 50 15 50 4 49 58 49 30 49 23 N 79.60 W .25 543.78N 3403.56W N 79.80 W .24 557.51N 3479.10W N 80.00 W .18 570.94N 3554.54W N 80.50 W .60 583.87N 3629.75W N 80.90 W .33 596.15N 3704.73W 3446.42 3523.21 3599.83 3676.14 3752.12 6200 4466.45 4312.45 48 51 6300 4532.40 4378.40 48 37 6400 4598.29 4444.29 48 55 6500 4663.53 4509.53 49 37 6600 4728.28 4574.28 49 40 N 81.50 W .70 607.72N 3779.46W N 81.70 W .27 618.70N 3853.83W N 78.60 W 2.35 631.57N 3927.91W N 78.00 W .83 646.94N 4002.12W N 77.70 W .24 662.98N 4076.62W 3827.72 3902.88 3978.07 4053.81 4129.96 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC. 2K-8 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 TRUE SUB-SEA COURS COURSE MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DGMN DEGREES DG/ DATE OF SURVEY: 9-18-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90099 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE DLS TOTAL RECTANGULAR COORDINATES 100 NORTH/SOUTH EAST/WEST 6700 4792.72 4638.72 50 4 N 77.30 W .49 679.53N 4151.27W 6800 4856.69 4702.69 50 23 N 77.20 W .33 696.49N 4226.24W 6900 4920.29 4766.29 50 37 N 77.30 W .25 713.52N 4301.51W 7000 4983.44 4829.44 51 2 N 77.50 W .44 730.43N 4377.17W 7100 5046.48 4892.48 50 48 N 77.90 W .39 746.97N 4453.02W VERT. SECT. 4206.34 4283.10 4360.17 4437.61 4515.17 7200 5110.70 4956.70 49 15 N 78.70 W 1.67 762.52N 4528.06W 7300 5175.47 5021.47 50 0 N 79.20 W .83 777.12N 4602.84W 7400 5237.92 5083.92 52 42 N 79.60 W 2.72 791.48N 4679.60W 7500 5298.94 5144.94 52 5 N 79.70 W .62 805.71N 4757.53W 7600 5360.29 5206.29 52 13 N 79.90 W .21 819.70N 4835.25W 4591.77 4667.94 4746.02 4825.24 4904.21 7700 5421.27 5267.27 52 37 N 79.80 W .40 833.66N 4913.27W 7800 5481.77 5327.77 52 55 N 79.80 W .30 847.76N 4991.63W 7900 5542.56 5388.56 52 12 N 82.60 W 2.33 859.92N 5070.07W 8000 5603.92 5449.92 52 5 N 83.70 W .88 869.33N 5148.47W 8100 5665.36 5511.36 52 5 N 83.60 W .08 878.06N 5226.88W 4983.46 5063.08 5142.45 5221.30 530O.05 8200 5726.68 5572.68 52 16 N 83.80 W .24 886.73N 5305.40W 8300 5787.86 5633.86 52 17 N 83.90 W .08 895.20N 5384.04W 8400 5849.04 5695.04 52 15 N 84.00 W .08 903.54N 5462.70W 8500 5910.13 5756.13 52 26 N 84.20 W .24 911.68N 5541.46W 8600 5971.14 5817.14 52 21 N 84.60 W .33 919.41N 5620.31W 5378.90 5457.83 5536.76 5615.75 5694.76 8700 6031.60 5877.60 53 14 N 83.40 W 1.30 927.74N 5699.52W 8800 6090.00 5936.00 55 17 N 80.40 W 3.19 939.20N 5779.86W 8900 6146.10 5992.10 56 27 N 77.50 W 2.67 955.08N 5861.09W 9000 6201.24 6047.24 56 36 N 74.70 W 2.34 975.12N 5942.05W 9100 6255.06 6101.06 58 16 N 73.10 W 2.14 998.49N 6023.01W 5774.23 5855.35 5938.10 6021.29 6105.05 9200 6306.29 6152.29 60 4 N 72.50 W 1.88 1023.89N 6105.03W 9300 6355.12 6201.12 61 27 N 70.90 W 1.96 1051.29N 6187.86W 9400 6402.90 6248.90 61 27 N 70.90 W .02 1080.04N 6270.88W 9445 6424.40 6270.40 61 27 N 70.90 W .04 1092.97N 6308.23W 6190.20 6276.50 6363.20 6402.22 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6402.22 FEET AT NORTH 80 DEG. 10 MIN. WEST AT MD = 9445 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 279.83 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA, INC. DATE OF SURVEY: 9-18-89 2K-8 KUPARUK JOB NUMBER: AK-BO-90099 ALASKA KELLY BUSHING ELEV. = 154.00 FT. COMPUTATION DATE: 9/22/89 OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 .00 -154.00 1000 994.57 840.57 2000 1850.92 1696.92 3000 2462.87 2308.87 4000 3063.68 2909.68 5000 3695.25 3541.25 6000 4336.00 4182.00 7000 4983.44 4829.44 8000 5603.92 5449.92 9000 6201.24 6047.24 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9445 6424.40 6270.40 .00 .00 .00 32.27 N 52.37 W 5.43 5.43 149.28 N 530.91 W 149.08 143.65 285.39 N 1308.16 W 537.13 388.05 404.94 N 2098.11 W 936.32 399.19 3020.60 221.85 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. 1092.97 N 6308.23 W 479.75 N 2869.71 W 1304.75 368.43 583.87 N 3629.75 W 1664.00 359.25 730.43 N 4377.17 W 2016.56 352.56 869.33 N 5148.47 W 2396.08 379.53 975.12 N 5942.05 W 2798.76 402.67 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. DATE OF SURVEY: 9-18-89 2K-8 KUPARUK JOB NUMBER: AK-BO-90099 ALASKA KELLY BUSHING ELEV. = 154.00 FT. COMPUTATION DATE: 9/22/89 OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 .00 -154.00 54 54.00 -100.00 154 154.00 .00 254 254.00 100.00 354 354.00 200.00 454 454.00 300.00 554 554.00 400.00 654 654.00 500.00 754 754.00 600.00 855 854.00 700.00 958 954.00 800.00 1061 1054.00 900.00 1167 1154.00 1000.00 1274 1254.00 1100.00 1384 1354.00 1200.00 1498 1454.00 1300.00 1616 1554.00 1400.00 1739 1654.00 1500.00 1868 1754.00 1600.00 2004 1854.00 1700.00 2149 1954.00 1800.00 2304 2054.00 1900.00 2469 2154.00 2000.00 2639 2254.00 2100.00 2810 2354.00 2200.00 2984 2454.00 2300.00 3158 2554.00 2400.00 3324 2654.00 2500.00 3492 2754.00 2600.00 3663 2854.00 2700.00 3825 2954.00 2800.00 3984 3054.00 2900.00 4142 3154.00 3000.00 4297 3254.00 3100.00 4455 3354.00 3200.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST .00 .00 .07 N .04 E .98 N .57 E .97 N 1.27 E .12 N 2.01 E MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 .00 .01 .01 .01 .01 .02 .01 4.10 N 2.81 E .03 .01 5.03 N 2.89 E .04 .01 6.82 N .92 W .15 .12 10.54 N 10.76 W .72 .57 17.43 N 25.02 W 1.99 1.26 27.48 N 43.39 W 39.81 N 67.30 W 52.91 N 97.60 W 65.06 N 135.19 W 77.03 N 180.33 W 89.84 N 232.78 W 104.33 N 293.30 W 119.74 N 362.93 W 134.72 N 442.98 W 149.74 N 533.90 W 166.31 N 637.53 W 184.58 N 755.20 W 206.77 N 884.43 W 230.52 N 1019.12 W 255.76 N 1155.88 W 283.01 N 1295.66 W 308.58 N 1435.23 W 327.57 N 1566.80 W 347.86 N 1700.83 W 369.76 N 1836.81 W 387 403 417 429 442 .38 N 1963.48 W .45 N 2086.36 W .68 N 2206.94 W .73 N 2325.37 W .04 N 2447.64 W 4.17 2.18 7.74 3.57 13.06 5.33 20.61 7.54 30.99 10.39 44.65 13.66 62.46 17.80 85.30 22.84 114.29 28.99 150.31 36.02 195.31 45.00 250.82 55.52 315.75 64.93 385.18 69.43 456.47 71.29 530.49 74.02 604.09 73.60 670.44 66.35 738.90 68.46 809.11 70.21 871.46 62.34 930.71 59.25 988.01 57.30 1043.48 55.47 1101.92 58.45 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. 2K-8 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 DATE OF SURVEY: 9-18-89 JOB NUMBER: AK-BO-90099 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4615 3454.00 3300.00 453.81 N 2571.71 W 4775 3554.00 3400.00 465.06 N 2695.59 W 4934 3654.00 3500.00 475.76 N 2819.13 W 5092 3754.00 3600.00 485.22 N 2941.52 W 5249 3854.00 3700.00 497.14 N 3061.22 W MD-TVD VERTICAL DIFFERENCE CORRECTION 1161.70 59.78 1221.31 59.60 1280.61 59.30 1338.94 58.34 1395.39 56.45 5404 3954.00 3800.00 510.15 N 3179.61 W 5560 4054.00 3900.00 524.56 N 3298.45 W 5717 4154.00 4000.00 546.15 N 3416.49 W 5872 4254.00 4100.00 567.35 N 3534.17 W 6027 4354.00 4200.00 587.35 N 3650.54 W 1450.91 55.51 1506.90 55.99 1563.11 56.21 1618.98 55.88 1673.72 54.74 6181 4454.00 4300.00 605.61 N 3765.36 W 6332 4554.00 4400.00 622.24 N 3878.10 W 6485 4654.00 4500.00 644.61 N 3991.15 W 6639 4754.00 4600.00 669.43 N 4106.23 W 6795 4854.00 4700.00 695.77 N 4223.06 W 1727.07 53.35 1778.69 51.62 1831.29 52.60 1885.75 54.47 1941.78 56.02 6953 4954.00 4800.00 722.55 N 4341.66 W 7111 5054.00 4900.00 748.91 N 4462.05 W 7266 5154.00 5000.00 772.32 N 4577.70 W 7426 5254.00 5100.00 795.29 N 4700.35 W 7589 5354.00 5200.00 818.27 N 4827.26 W 1999.20 57.43 2057.91 58.70 2112.59 54.69 2172.53 59.94 2235.73 63.20 7753 5454.00 5300.00 841.26 N 4955.49 W 7918 5554.00 5400.00 861.82 N 5084.71 W 8081 5654.00 5500.00 876.43 N 5212.39 W 8244 5754.00 5600.00 890.54 N 5340.51 W 8408 5854.00 5700.00 904.21 N 5469.07 W 2299.96 64.23 2364.67 64.71 2427.52 62.84 2490.65 63.14 2554.10 63.45 8571 5954.00 5800.00 917.32 N 5598.18 W 8737 6054.00 5900.00 931.55 N 5729.70 W 8914 6154.00 6000.00 957.66 N 5872.73 W 9097 6254.00 6100.00 998.00 N 6021.37 W 9297 6354.00 6200.00 1050.62 N 6185.92 W 2617.93 63.83 2683.78 65.85 2760.29 76.52 2843.99 83.70 2943.65 99.66 9445 6424.40 6270.40 1092.97 N 6308.23 W 3020.60 76.95 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 7 ARCO ALASKA, INC. 2K-8 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 DATE OF SURVEY: 9-18-89 JOB NUMBER: AK-BO-90099 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MARKER 3770 2919.87 2765.87 381.60 N 9011 6207.30 6053.30 977.54 N 9047 6227.11 6073.11 985.47 N 9047 6227.11 6073.11 985.47 N 9260 6336.01 6182.01 1039.79 N 1920.15 W 9 5/8" CSG 5950.91 W TOP KUPARUK C 5979.90 W BASE KUPARUK C 5979.90 W TOP KUPARUK A 6154.66 W BASE KUPARUK A 9300 6355.12 6201.12 1051.29 N 9341 6374.71 6220.71 1063.08 N 9423 6413.89 6259.89 1086.65 N 9445 6424.40 6270.40 1092.97 N 6187.86 W SURVEY DEPTH 6221.90 W PBTD 6289.97 W 7" CSG 6308.23 W TD ARCO ALASKA, INC. 2K-8 STRATIGRAPHIC SUMMARY BKB BKB SUB-SEA 9 5/8" CSG TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A COORDINATES WITH REF. TO WELLHEAD ORIGIN: 121FSL 94FEL SEC 02 T10N R08E 3770 2919.87 2765.87 381.60N 1920.15W 9011 6207.30 6053.30 977.54N 5950.91W 9047 6227.11 6073.11 985.47N 5979.90W 9047 6227.11 6073.11 985.47N 5979.90W 9260 6336.01 6182.01 1039.79N 6154.66W PBTD 9341 6374.71 6220.71 1063.08N 6221.90W 7" CSG 9423 6413.89 6259.89 1086.65N 6289.97W TD 9445 6424.40 6270.40 1092.97N 6308.23W mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmm~mmmmmm! COMPUTER PROGRAM - SPERRY-SUN THREE DIMENSION RADIUS OF CURVATURE mmmmmmmmmmmmmmmmmmmmmmmmmmm, DATE OF SURVEY: 9-18-89 COMPUTATION DATE: 9/22/89 JOB NUMBER: AK-BO-90099 KELLY BUSHING ELEV. = 154.00 FT. SPERRY-SUN DRLG. S¥CS. 2K-8 KUPARUK ALASKA 9-18-89 HORIZONTAL PROJ ECT'~ON START F'fN:[SH TVD = SCALE :IS 1500 TVD = 0 6424.4.0 FEET/]:N it -0000 ~-- oooo ?sbo oobo 4sbo soho ssoo o DEPARTURE .?SOO .CO00 .4,S00 -~000 1~00 0 2K-8 KUP ARUK ALASKA 9-18-89 SPERR -C-SUN VERT:I:CAL DRLG. PROJ ECT:I:ON SVCS. START TVD = 0 FINISH TVD = 6424.40 SCALE IS 1500 FEET/IN .J 1500 8000 4500 0000 7500 0000 10500 94.45 15b0 8402.22 oobo ~sbo oobo VERTICAL SECTION DIRECTZON = O. O0 75bo J 0000 MEMORANDUM State ur Alaska ALASKA OIL AN~~.."GAS CONSERVATION COMMISSION TO: Lonnie C. Smit~//~?~ DATE: November 1, 1989 Commissioner i/ ' FILE NO: D.BDF.115 THRU: FROM: Michael T. Minder Sr, Petroleum Engineer Bobby D. Foster~~ Petroleum. Inspector TELEPHONE NO: SUBJECT.' BOP Test AAI KRU 2K-8 Permit No. 89-38 Kuparuk Rv Wednesday, October 25, 1989,. The test on Nordic Rig #1, began at I1:00 am End was concluded` at 1:00 pm. As the attached BOP test report shows, there were no failures, however there were several items that were not in compliance with AOGCC regulations 20 AAC 25.285(b) (1). The items in non compliance includes treaded connections in kill line, chicshan joints, treaded connections, in choke line and treaded connections in line down stream of chokes going to the gas buster, non targeted 90° turns on these lines and non targeted 90° turns between gas buster and mud system. .. I spoke with'GeOrge Bean, AAI rep. and Skip Gouchee, Nordic rig manager, concerning these items. George Bean assured me that the choke line would be replaced with a shock hose as soon as the welder coUld weld on the connections and the kill line threaded connection would be eliminate as. soot'S'as_material could be acquired . I told Ge.orge.that~ i would _.r~ot~--set a time limit for the work to be completed, but do it~as S0on as possible · In summary, I witnessed the BOP Test on AAI's 2K-8. Attachment 02-00 lA (Rev. 8~85) 5/84 .STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report' '~ Location: Sec Drilling Contractor Location, General ~--'"~' Well Sign General Housekeeping / Rig Re, eryc Pit A///~ Visual AUdio Hud Systems · Trip Tank Pit Cauge Flow Monitor Gas Detectors Test Pressure BOPE S tack Annular Preventer , Pipe Rams Blind Rams Choke Line Valves . H. C.R. Valve * Kill Line ValVes Check Valve _ 7''~ Casing Set @ 94a~ ft. ACCUMULATOR SYSTEM Test Results: Failures ~ Repair or Replacement of failed equipment to be made within Full Charge Pressure .~D~ O psig Pressure After Closure., J ~/D psig Pump incr. clos. pres. 200 psig - min/~sec. Full Charge Pressure Attained: / min. ~. sec. "2, · Controls: Master ~,~ ,,, Remote~~Blinds switch cover~~ Ke and Floor Safer~ Valves Upper Pressure . Lower Kelly ~/~ Test Pressure /, . Ball Type I Test Pressure Inside BOP .~ Test Pressure., Choke Manifold~Test Pressure .o. No. flanges Adjustable Chokes ]. Hvdrauicall~ choke / Test T~e ~ hrs. days and Inspector/ Comm!ssionnf f ic,e notified. , , Distribution ~ ~e~~. ~ .~ ~,u ~ .~~ ~,J~o ~~ ~o~, ' cc - Operator . I -- ~~~;~~' ~ ~~~ 'l~.~r, ~~~ '~ ] - ;L / -' - - -:~ DEC-12-'~ 05:~6 ID:NOrDIC RIB 1 .~.. IEL HU: ~OYB~'('iI~,_t · ,~ General Purpose Worksheet By ID&t®. A' OIL AND GAS CONSERVATION COMI' N FOR SUNDRY APPROVALS0 I G IN A L APPLICATION 1. 'i'ype of Request: Abandon _ Suspend _ Alter casing _ Repair well _ Plugging _ · Change approved program_ Pull tubing _ 2. Name of Operator ~ 5. Type of Well' Development ~X ARCO Alaska. Inc. Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service _ 4. Location of well at surface 121' FSL, 94' FEL, Sec. 2, T10N, R8E, UM At top of productive interval 1076' FSL, 575' FEL, Sec. 3, TI ON, R8E, UM (approx) At effective depth 1184' FSL, 1036' FEL, Sec.3, TI ON, R8E, UM (approx) At total depth 1214' FSL, 1122' FEL, Sec. 3, TI ON, R8E, UM (approx) Present well condition summary Total Depth: measured (approx) true vertical · Operation Shutdown ~ Re-enter suspended well _ Time extension _ Stimulate _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) RKB 154 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-8 L~' Permit number 3 10. APl number 50-103-20111 9445' feet Plugs (measured) 6424' feet None feet Ill. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool 12. Effective depth: measured (approx) true vertical 9341' feet Junk (measured) 63 75' feet None Casing Length Size Structural 8 0' 1 6" Conductor Surface 3770' 9 5/8" Intermediate Production 9423' 7" Liner Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Attachments Description summary of proposal Cemented Measured depth True vertical depth 115' 115' 1100 Sx AS III & 3770' 2920' 520 Sx Class G 200 Sx Class G 9423' 641 4' RECE. VED A!~ska Oil & Gas Oo~s,, Oomm[ss[o~ Anch0rag~ Detailed operation program X BOP sketch _ 13. 14. Estimated date for commencing operation November, 1989 16. If proposal was verbally approved Date approved 15. Status of well classification as: Oil ;~ Gas __ Suspended Service Name of approver 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned Fcv~--~;~.J-.-, ~. ~~-.~,' Title Area Drillin~l Engineer / FOR COMMISSION USE ONLY IApproval No.~, 'L~'~ "~ Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require ORIGINAL ~, GN~.D BY I I'~NNiF P,, ~MITH Approved Copy Commissioner Date /0 "J '~2 SUBMIT IN TRIPLICATE Approved by the order of the Commission Form 10-403 Rev 06/15/88 ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial R®l~ort" 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, Field KUPARUK RIVER Auth. or W.O. no. AK3633 ICounty. parish or borough NORTH SLOPE Lease or Unit ADL 25589 ALK 2675 Title DRILLING 2K-8 IWell no. Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 08/24/89 ( 1) TD: 803'( 803) SUPV:CD 08/25/89 (2) TD: 2563' (1760) SUPV:CD 08/26/89 (3) TD: 3790'(1227) SUPV:CD 08/27/89 (4) TD: 3790'( 0) SUPV:CD 08/28/89 (5) TD: 6394' (2604) SUPV:CD 08/29/89 (6) TD: 8600'(2206) SUPV:CD 08/30/89 (7) TD: 9216'( 616) SUPV:CD Dat%8/24/89 Complete record for each day reported DOYON l 4 DRILLING MW: 9.1 VIS: 77 ACCEPT RIG 8/23/89 1900 HRS. NU DIVERTER SYSTEM, PU BRA, FUNCTION TEST SAME. DRILL F/l15' - 803' DAILY:S56,376 CUM:$56,376 ETD:S56,376 EFC:$1,488 DRILLING MW: 9.2 VIS: 88 DRLG F/803'-2240', CBU, DROP SS, TOH, PU NEW NAVIDRILL, TIH. WASH & REAM F/1700'-1837' CONTINUE TIH. DRLD F/2240'-2563'. DAILY:S50,268 CUM:$106,644 ETD:S106,644 EFC:$1,488 CIRCULATE HOLE CLEAN 9-5/8"@ 3770' MW: 9.4 VIS: 85 DRLG F/2563''-3790', CIRC, DROP SS. POOH, HOLE TIGHT AT 1763'. PU 12-1/4" HOLE OPENER, TIH. WASH & REAM 'F/1654'-1844'. CONTINUE TIH, CBU. DAILY:S51,838 CUM:$158,482 ETD:S158,482 EFC:$1,488 TIH 9-5/8"@ 3770' MW: 8.5 VIS: 30 TOH W/HOLE OPENER, RU & RUN 95 JTS 9-5/8" CSG TO 3770, RU CIRC HEAD, CIRC, PUMP 80 BBL CL 'G' (520 SX) AT 15.8 PPG, DISPLACED W/285 BBL WATER, BUMP PLUG TO 2000 PSI, (51BBLS CMT TO SURF), ND DIVERTER, MU BRADENHEAD, NU BOPE, TEST BOPE TO 3000 PSI, MU 8-1/2" BNA, TIH. DAILY:S244,030 CUM:$402,512 ETD:S402,512 EFC:$1,488 DRILLING 9-5/8"@ 3770' MW: 9.3 VIS: 37 CONTINUE TIH, TEST CSG TO 2000 PSI, DRLD FC, FS, & 10' NEW HOLE, CIRC HOLE CLEAN. PERFORM LOT TO 12.5 PPG, DRLD F/3800'-6394' DAILY:S49,597 CUM:$452,109 ETD:S452,109 EFC:$1,488 POOH TO CHANGE BHA 9-5/8"@ 3770' MW: 9.7 VIS: 33 DRLG F/6394'-7505', CBU, SHORT TRIP TO CSG SHOE, CIRC, PERFORM OH LOT TO 10.3 PPG EMW (OK). TIH (HOLE TIGHT AT 6650'), DRLD F/7505'-8600'. CBU, DROP SINGLE SHOT, TOH F/ROTARY ASSY. DAILY:S46,026 CUM:$498,135 ETD:S498,135 EFC:$1,488 DRILLING 9-5/8"@ 3770' MW:10.0 VIS: 36 TOH TO CSG SHOE, PERFORM OH LOT TO 10.3 PPG EMW, CONTINUE TOH. PU ROTARY BHA. TIH, REAM 50' TO BTM. DRLD F/8600'-9216'. DAILY:S58,707 CUM:$556,842 ETD:S559,842 IisRCO w.I. .8533 riot status if a W.O. AR3B-459-1-D INumber all daily well history forms consecutively as they are prepared for each well. iPage no. ARCO Oi, -,nd Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work Derformed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wedr~esday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string unlil completion. District ICounty or Parish State ARCO ALASKA INC. I NORTH SLOPE I AK Field ILeaseorUnit IWellno. KUPARUK RIVER I ADL 25589 ALK 2675 2K-8 Date and depth as of 8:00 a.m. 08/31/89 ( TD: 9445'( SUPV:CD 09/01/89 ( TD: 9445'( SUPV:JER 8) Complete record for each day while drilling or workover in progress DO¥ON 1 4 RD SCHLUMBERGER 9-5/8"@ 3770' MW:10.2 VIS: 40 DRLD TO 9445', CBU, SHORT TRIP, POOH TO LOG. RU SCHLUMBERGER, LOG HOLE. RD SCHLUMBERGER. DAILY:S54,633 CUM:$611,475 ETD:S611,475 EFC:$1,488 RUNNING 7" CASING 9-5/8"@ 3770' MW:10.3 VIS: 44 FIN RD SCHLUMBERGER. RIH, CBU, SHORT TRIP. POOH TO RUN 7" CASING. PULL WEAR BSHG. RU CSG TOOLS, RUN 7" 26~ J-55 BTC CSG. DAILY:S111,342 CUM:$722,817 ETD:S722,817 EFC:$1,488 above is correct DrHlin'rl, ~ages 86' ~n~l 7 AR3B-459-2-B Number all daily well history forms as they are prepared for each well. corlseculively ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is 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. I County or Parish I NORTH SLOPE Field ILease or Unit I Well no. KUPARUK RIVER I ADL 25589 ALK 2675 2K-8 I Title I DRILLING District ARCO ALASKA INC. IAccounting cost center code Auth, or W,O, no. AK3633 Operator A.R.Co. W.I. ARCO 55.8533 Spudded or W.O. begun Date SPUD 08/24/89 Date and depth as of 8:00 a.m. 09/02/89 (10) TD: 9341'( 0 SUPV:JER Complete record for each day 'reported DOYON 14 Iotalnumber of wells (active or inactive) on this t est center prior to plugging and bandonment of this well our Prior status if a W.O. 00:00 RIG RELEASED 7"@ 9423' MW:10.2 VIS: 0 FINISH RUNNING 7" CASING, SHOE @ 9423, COLLAR @ 9341. CIRC AND CONDITION WELL AND CEMENT WITH 20 BBL SPACER 3000 AND 200 SX(41 BBL) CLASS G WITH ADDITIVES DISPLACE WITH 357 BBL 10.2 PPG BRINE. BUMP PLUG WITH 3500 PSI, OK. RELEASE PRESSURE, FLOATS HELD OK. CIP 0430 SEPT 1. RD DOWELL, ND BOP, SET SLIPS, CUT CASING, INSTALL PACKOFF AND NU TUBING SPOOL. TEST TO 3000 PSI, OK. RELEASE RIG 1930, SEPT 1, 1989. DAILY:S201,856 CUM:$924,673 ETD:S722,817 EFC:$203,344 Old TD Released rig INew TD I PB Depth Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc,) Producing method Officia reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production OII on test Gas per day 1_ Pump size, SPM X length i~?3~e size T.P. C.P. Water % GOR Gravity Allowable :Effective date corrected The above is correct ~e°; fl~;o~ e%ruerPe~s~ ds ed i¢~ ti r(~ nb u ~ iO°,n ''4L'~ ~~/~'~ -- d' Drilling, Pages 86 and 87. AR3B-459~3-C INumber all daily well hlstory forms consecutively Par~,? no as they are prepared for each well. I I Division of AHantlcRichfieldCompany ARCO Alaska, Inc. Date: September 22, 1989 Transmittal #: 7566 RETURN TO: ARCO Alaska, Inc. Attn: Brianna Knettle Cpf-3 Eng. Aide ATO-1152 P.O. Box 100360 Anchorage, AK 9951.0-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 2K-08 2K-12 OH Tape and Listing OH Tape and Listing Please acknowledge receipt and return #73460 #73465 Receipt Acknowledged: ........................... Date: DISTRIBUTION: State of Alaska ARCO Alaska, Inc. Date: September 22, 1989 Transmittal #: 7566 RETURN TO: ARCO Alaska, Inc. Attn: Brianna Knettle Cpf-3 Eng. Aide ATO- 1152 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 2K-08 2K-12 OH Tape and Listing OH Tape and Listing Please acknowledge receipt and return #73460 #73465 Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: State of Alaska ARCO Alaska, Inc. Date: September 8, 1989 Transmittal #: 7556 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2K-08 2" Dual Induction - SFL 8-30-89 1 000-9432 2 K - 08 5" Dual Induction .- SFL 8 - 3 0 - 8 9 1 000 - 9432 2K-08 2" & 5" Raw FDC 8-30-89 8790-9382 2K-08 2"& 5" Porosity FDC 8-30-89 8790-9382 2K-08 Cyberlook 8-31 -89 8790-9360 Receipt Acknowledged: DISTRIBUTION: NSK D&M Drilling Franzen State of Alaska(+sepia) L. Johnston(vendor package) TO: THRU: state¢, f Alaska ~~ OIL AND GAS CONSERVATION ~SSION · Lonnie C. Smi~/ DATE: September 6-, 1989 Co_~ issioner / o F~LE NO: D. BDF. 094 TELEPHONE NO: Sr. Petroleum Engineer BOP Test Permit No. ~89-83 Kuparuk Rv Field FROM: S'.~.daY, .A~st ,27, 198'9,~ I crave!ed this date to 2K pad .after bei~ notified by'Charlie DiXOn,`; 'of' the'up comt~ te,s:t, Due being involved on anoth r job, 1! , ~ '. Was.. ~ ~d arrive 'at the location until Said the test 11:0 on ,. I wi~ the of upper an Lower kelly rep- were disassembled and all ~laced and: ~he ~nu. lar preventer In: s~ry., I witnessed the .above l.iSted components of the BOP tes~ on Attachment STATE OF ALASKA ALASKA OIL AND GP~S CDNS£RVATION BOrE inspection Report S ION General housekeeping _ (") i< Rig ~1< -- MUD SYSTEMS: Vi ~ual Audi o Trip teak Pi % gauge ~' Flow monitor .... ?. J__~_ ~-~ Ga% detector~ BDPE' STACKJ ...... Test Pressure Annular preventer ii Blind ramm Choke l~ne v~lve~ HeR v~lve ~. . '~0 .... Cheak valve .... ~/~ ..... TEST RESULTS: F~(lure$ Representative Parr, it # I ^CCU~UL^TOR Full charge Prees after cl Pu~p tncr Full charge Control,~ Master Remote KELLY AND FLOOR SA Upper Kelly __ Lower Kelly .-- B~ll type in~ide BOP Cho~e manifold Number valve~ Number flenge~ AUjuatable chokes · Hydraulically ope ~ I I IIII Repair or replacement of felled equipment to be made within end Inspector/Commission office notified. Blind switch cover. VALVES: ~e~t pre~aur~ .. daya August 3, 1989 Telecopy: (907)276-754Z Patrick J. Archey Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 A~chorage, Alaska 99510-0360 Kuparuk River Unit 2K-8 ARCO Alaska, inc. Permit No. 89-83 Sur. Loc. i2i'FSL, 94'FEL, Sec. 2, T10N, RSE, UM. Btmhole Loc. 1366'FSL, 1031'FEL, Sec. 3, T10N, RSE, Dear bit. Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required per, hitting determinations are made. To aid us in scheduling iield work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Co~ission may witness testing before drilling below the shoe of the conductor pipe. C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF ~dg CO~R~ISSION dlf Enclosure cc: Department of Fish & Game, Habinat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA: ,.,~L AND GAS CONSERVATION C_ ./1MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill~ Redrill --I lb. Type of well. Exploratory ,~ Stratigraphic Test .~ Development Oil Re-Entry - Deepenr-I Service __- Developement Gas ',- Single Zone - Multip!e Zone 2. Name of Operator ARCO Alaska~ inc. 3. Address P.0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 121 ' FSL,94' FEL,Sec. 2,T1 0N,R8E,UM At top of productive interval 1320'FSL, 800 ' FEL,Sec. 3,T1 0N,R8E,UM At total depth 5. Datum Elevation (DF or KB) :KB 154, PAD llS'GL feet 10. Field and Pool uparuk River Field uparuk River 0il Pool 1366'FSL,1031 ' FEL,Sec.3,T1 0N,R8E,UM 12. Distance to nearest ! 13. Distance to nearest well property line I 2K-7 Producer I t~. I w @ T_n feet ~ '/, ~ 7 n n, feet '16."1:o-!~e completed for deviated wells 6. Property Designation ADL 25589 ALK 2675 7. Unit or property Name Kuparuk River Unit 8. Well number 9. Approximate spud date 08/21/89 14. Number of acres in propert~ 2560 11. Type Bond (see 20 AAC 25.025) Statewide Number #U630610 Amount $200~000 15. Proposed depth(uDandTVDI 9371'MD 6423'TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 1,8. Casing program size Hole Casing 24" 1 6" 12-1/4" 9-5/8" feet Maximum hole angle 51 Specifications Coupling Weld BT¢ 0 Maximum surface 1 646 psig At total depth (TVD) 3 0 8 8 psig Settim )th Top Bottom Quantity of cement MD TVD (include stage data) 35 115' +200 # cf 35 2909' 700 sx AS III & 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 Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Kuparuk Length Size Cemented Measured depth True Vertical depth 20. Attachments Filing fee ~' Property plat [] BOP Sketch ~ Diverter Sketch ~, Drilling program ~ Drilling fluid program ~ Time vs depth plot ~ Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements 21. ! hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Area Drilling Engineer Date Commission Use Only .IWR/9 Permit Number I APl number I Approval date I See cover letter I I 08/03/8,9 I for other requirements Conditio'ns of approval Samples requ, ired ~ Yes .~No Mud log requir, ed L-] Yes /~ No Hydrogen sulfide.measures [] Yes ~No Directmnal survey required ,J~ Yes [] N(:~ Required working pressure for BOP~,,[]2M; ~ 3M; [] 5M; [] 10M; [] 15M Other: ~ ~ /" //'~ '/ ~ (/~ (/~~ by order of ~//~~i~ ApproVed by Commissioner the commission Date Form 10-401 Rev. 12-1-85 / Submit i,,~ trip'cate ARCO ALASKA. !ne. Ped 2K, Well Not 8 Pr'opoeed Kuparuk Field, North Slope. Aleeka 1000 2000 RrB ELEVAT[ONt 154' KOP TVD-500 TMD-500 DEP-O 3 9 BUILD 3 15 PER 100 FT ar B/ PERHAFROST TVD-1424 THD-1464 DEP-238 ~ T/ UONU SNDS TVD-1541 THD-1601 DEP-309 45 si EOCTVD-2000 THO-2225 DEP-Z28 T/ W SAK SNDS TVD-2146 THD-2461 DEP-913 n 3000 .,.i. o 4000 $000 B/ W SAK SNDS TVD-2709 THD-33Zt DEP-162Z 9 5/8" CSG PT TVD-2909 TIID-3694 DEP-1881 K-1 0 TVD-31 57 THD-4095 DEP-2196 K-5 TVD-4496 THD-6258 DEP-3895 AVERAGE ANGLE 51 DEO 46 HIN 6000 ?°°° .,1 0 T/ ZONE C TVD-6149 THD-8929 DEP-5993 T/ ZONE A TVD-6175 TIID-897*l DEP-6026 TARGET CNTR TVD=6237' THD-90?'t DEP-6105 B/ KUP SNDS TVD-6299 TIID-91ZI DEP-6184 TD (LOG PT) TVD-6423 THD-93Z1 DEP-634! 1000 I I I I 2000 3000 4000 5000 VERTICAL SECTION I 6000 I ZOO0 HORIZONTAL PROJECTION SCALE 1 IN. = 1000 FEET ARCO ALASKA. ! no · Pad 2K. Well No' 8 Propo.ed Kupar. uk Field. Nor'th Slope. Aleeko ?000 3000 - 2000 _ 1000 _ 0 _ 1000 _ 6000 5000 NORTH tdEST TD LOCATION' 13~' ISL. IC~1' FEI. SEC. 3. TI Oil. R~E 4Ooo I WEST-EAST 3000 I TARGET LOCAT!ON, 1320' FS1.. 8GO' FEL SEC. 3. TION. RSE N 78 DEC; 40 MI N W 61 05' (TO TARGET) 2O00 1000 , , 1000 I ~JRFACE LOCAT ! ON' 12.1' F'~I.. ~4' FEI. SEC. 2. TlOff. RS! 400 350 500 250 200 ! 50 ! O0 50 0 500 250 _ 2OO 150 _ 100 _ 50 . 100 :500 10 ~ 1300 / I / $0t:)/ ! ~' 900 · 500 500 / · $00 / 1 900 /'"2500 500' / 2300 500 · 5O0 / / /! 3'~°,~°o o / / 27'00_ 300 250 200 150 100 _ 5O 400 350 300 250 2OO 150 1 O0 $0 DRILLING FLUID PROGRAM (2K-8) Spud to 9-5/8" Drill out to surface casino weioht uD Density 8.8-9.0 8.7-9.2 PV 1 5-30 5-1 5 YP 20-40 8-12 Viscosity 70-80 35-40 Initial Gel 5-15 2-4 10 Minute Gel 1 5- 3 0 4 - 8 APl Filtrate 10-15 10-20 pH 9- 1 0 9.5-1 0.5 % Solids 10 +/- 4-7 Weight up tO TD 9.7 11-16 8-12 35-50 3-5 5-12 6 9.0-10.5 12-15 Drillino 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-8 is 2K-7. This well is 17' away at 700' 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. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. OEGAS$ -'.~' .... MUD CLEANER SHALE SHAKERS STIF STIR STIR TYPICAL MUD SYSTEM SCHEMATIC KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC l_ DESCRIPTION 1. 16' CONDUCTOR 2. FMC SLIP~3N WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16' 2000 PSI BALL VALVE8 4. 20' 2000 PSI DRILLING SPOOL W/10' OUTLETS 5. 10' HCR BALL VALVES WI10' DIVERTER LINES. A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTE~ VALVES CAN BE · REMOTELY ~ I ;n TO ACHIEVE DOWNWIND DIVERSION. 6. 20' 2000 PSI ANNULAR PREVENTER 4 ARCO ALASK~ INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC2S.03S(b) 2 MAINTENANCE & OPERATION 1. UPON INmAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THI::EXJGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. 00 NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG 4/26/88 -7 6 DIAGRNg #t 1~8' .5C130 PSI R~ BOP STAC~ ACC~T~ CAPACITY TE~I' I. O-EC)C ~ FILL AO3,M,LATCR RF, SERVOIR TO ~ LEVEL W]TH HYOP, N/.IC FLUID, 2. ~ THAT ACO. IU.ATCR ~ IS ~30C) PSI WITH I,~3C1 l:~I ~TREAM CF TI.~ I~GLLATOR. ~ T~Ii~ TI-EN (3.C~ ALL IJN/'I~ $~kU. TAflEt3..I~Y AJ~ RECCRD ll.E TIl~ AI~ P~ R~INING AFTE~ AIL UNITS AI~ ~ RITH ~NG ~ CFF. IS 45 ~E~ CLO5II~ TI~ AM) 1200 PSI REI~ININ~ 5 4 3 2 I:)--~/~' BCP STACK TEST I. FILL ~ STACK AI~ CI4:KE I~NIFCI. D WITH /kqCTIC DIESEL. 2. O-ECX THAT ~ LOCI( Cl3Y~ SCRL"I~ IN N~LLJ-F. AD A~E FLLLY R~TRAC~ ~.AT TEST PLUG IN W~TH RU~I~I~G JT ~ LI~E VALVES ADJACE]~ TO BCP STA(X. AU. o'r~E~ 4. PRESSLRE UP TO 250 PS] C3~EA.tE PR~LRE TO BLEED PRE~9,1aE TO 0 Pgl. LII'~ VALVES. CLOSE TCP PlI~ RA~ ~ HCR VALVF_5 CN Kill ~ O4(3(E LIMES. 6. TEST TO 250 PSI AI~) 3(ll) PSI ~ IN 5"lLrP 4. 7. CCNTIN,[ TESTING ALL VALVE~, LII~Eg, ~ CI-13(E$ WITH A 250 IXJI LOW ~ ;)0(X) PSI HIO'L llEgT AS IN 8. OPEN TC~ PlPtE ~ AI~ CLI~E BOTTI~ Pll:~ p, aj~ TEST BOTT~ PIPE: ~ TO ~ ~I ~ ~ ~I. ~I. ~~D ~ LI~ ~ F~ ~ ~I~ ~Ul~ ~T ~ V~ IN ~I~I~ ~ITI~ 12. ~ ~~I~ V~ ~Y. ~Y ~ ~I~ PI~ ~E~ V~ ~ I~l~ ~ ~ ~ ~I ~ ~ ~I. F~ SI~ ~ ~ TO ~I~I~ ~I~. ~Y ~~ F~I~Y ~~ ~ ~Iu~. ~, 100~400, ARCO Alaska, Inc. Post Office Box ^nchorage, Alaska 99510,.0360 Telephone 907 276 1215 December 12, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Conductor As-Built Location Plat - 2K Pad~2/ (Wells I - 24) Dear Mr. Chatteron' Enclosed is an as-built location plat for the any questions, please call me at 263-4618. Si ncerely, subject wells. If you have D. Martin Engineering Aide DM' hf Encl osure RECEIVED DEC 1 1988 Alaska Oil & (~as Cons. Commission Anchorage GRU13/010 ARCO Alaska, Inc. is a Subsidiary of AtlanlicRtchficldCr, mpany (3, ~ WELLS ~-12 ARE LOCATED ~N ~ SECTION 2 T. ~0 N.~ R. 8 E.~ ~ ~. UM~AT MERIDIAN. ~i WELLS 13-24 ARE LOCATED IN ~ ~,- J ~ ".T.S.' ~i,)lf,..y '., J ' UMIATSECTION I I, T. lO N., R. 8 E.,MERiDiAN. ~ '~' ~TH.~uRVLryIS TIO, X, SECTION a g)~! SECT,ON f D.S. 12 '--~ ~ If" ' ' ~ VICI ~IITY MAP I"= PROTRACTED Notes: ~e:~? I. COORDINATES ARE A.S.P. ZONE 4. i ?. ALL DISTANCES SHOWN ARE TRUE. SECTION II ~e~9 SECTION ,2 . i~zt 3. ELEVATIONS ARE B.P.M.S.L. zz=~'.s I 4. O.G. ELEVATIONS FROM CED- RIXX-$$11, re~4. RECEIVED ~ MONUMENTS PER LOUNSBU.~ S ^SSOClATES. --'-"~ DEC :]. '~: 1988 6. REFERENCE FIELD BOOK, L 88-40, p~. 55,56, ~' ~ 58,59, 65 8, 66. i Welll. ,y, ASp's , , Alas'la u ~ ~ ~m ~ ~ ~' {;oi,~, ~,, .......... . Dist. Dist. O.G. Pod ''~ I~. X .~ I~)~dlD~ LONGITUDE F.S.L. E E.L. Elev. Elev. I 5,938,600.18 i 498,310.17 j 70°14'36.519'' 150o00'49.1~'$" i 296' 94' 114.0 118.5 I 3 5,938,550.30 498,310.35 70° 14' 36.029" 150°00'49.128'' 246 113.8 i 4 5,938,525.46 498,310.06 70o14' 35.784" 150°00'49.136" 222' 113.8 5 5.938,500.19 498,3,0.,z 70o,4,35.53~" ,50°00'49.,s~'' 19~' i ,,3.B e 5.~e.,~5.,~ ,~e.~,o.~ ?oo,~.~s.~e~".' ,50o00'~s.,~"0. *z~' . I 7 5,938,450.36 498,310.3(; 70014,35.046" 150°0 49.127" 146' 113.8 8 5,938,425.30 498,310.18 70°1 34.799" 150°00'49.137'' 121' 113.8 I0 5,958,375.19 498 510 14. 70°!4'34.~06'' 150°00'49.15o 71' 113.9 ' * i,, I s.~.~so.~2 ,~.~,o.,~ ~oo,,'~,.oe," ,soooo',~.,~" ,~' ,,~.~ 12 5,938,325.20 498,310.17 70014' 33.815" 150o00'49.131" 21' 94' ! 113.9 118.5 , I FN.L. 13 5,938,235.31 i 498,310.37 70° 14' 32.930" 150°00'49.125" 69' 94' 113.7 118.5 14 5,958,210.14 ! 498,310. t6 70 °14' 3~.683" 150°00'49.131'' 94' 113.7 ~ 150°00'49.131" 119' i 15 ; 5,938,185.1z ! 498,310.16 70°14'32.437'' j 113.8 I i ii I i 16 ; 5,938,160.11 498,310.20 ' 70°14'32.191 150°00 49.130" ! 144' I ) 113.8 17 5,938, 135.21 498,510.18 70014' 31.946" 150o00'49.130'' I 169' 115.9 18 I 5,938, 110.19 498,310.29 70014' 31.700" 150°00'49.127" il 194' 114.0 19 : 5,938,085.20 498,310.27 70014' 31.454" 150o00'49.12:7'' i 219' 114.0 i ~! 5,938,035.1~ I 498,310.10 70°1 30.96 ~50°00'49.~30'' :>~9' 114.0 ~3 : 5,93?,985.3? 495~310.13 70o~4'30.47~'' : 150o00 40.130" 314,¢' 95' ~4.0 24 .5t937,950.29 498,310.08 70°14'30.225'' j 150°00'49.132" 34 95' I 113.9 i 118.5 oF. I HEREBY CERTIFY THAT ' AM __'~'~,.~_'~.." TO PRACTICE LAND SURVEYING IN THE~.~'~/ylOTH'~ %"~ 3TATE OF ALASKA AND THAI /H~b ~',ee,,e~ ................... PL. AT REPRESENTS A SURVEY MADE .=..~~ BY ME OR UNDER MY DIRECT SUPER - · F"'t'- ,..~ DRILL SITE 2 K VISION AND THAT ALL DIMENSIONS a'"J~ . G~P. AID .~.,... LS-6~9 .. ,· CONDUCTOR AS-BUILTS AND OTHER DETAILS ARE CORRECT ~:~:... I111 1 & J J ' j " Or.b),..M.o,l~jC,.~y.;~ jsht. I ~, i . i m u i J i i i i i ii i i i i , i , i Welll ASP's AlasI a Ull & 6;~s C;~,,,;,. ~;o~ T,;3'~:'~:; Dist Dist. O.G. Pod No. 'Y' 'X' L~'~I;'[~D~ LONGITUDE F.S.L. EE.L. Elev. Elev. I 5,938,600.18 498,310. I'~ 70° 14'36.519 " 150° 00'49.1~'$" 296' 94' 114.0 118.5 2 5,938,575.14 498,310.28 70° 14' 36.273" 150°00'49.130'' 271' 113.9 3 5,938,550.30 498,310.35 70° 14' 36.029" 150°00'49.128" 246' 113.8 4 5,938,525.46 498,310.06 70°14' 35.784" 150°00'49. 136" 22Z' 113.8 5 5,938,500.19 498,310.1Z 70° 14' 35.536" 150°00'49.134" 196' 113.8 6 5,938,475.14 498,310.33 70014'35.289" 150°00' 49.1~8'' 171' 115.8 7 5,938,450.36 498,310.3(; 70014' 35.046" 150°00'49.1~?'' 146' 113.8 4' 8 5,938,425.30 498,310.18 70° 14, 34.799" 150°00' 49.137'' 121' 113.8 9 5,938,400.30 498,309.98 70°1 34.553" 150°00'49.137" 96' ll3.8 I0 5,938,375.19 498,510.14. 70014'34.306'' 150o00'49.15,:3" 71' 113.9 I I 5~938,350.22 498,310.14 70°14' 34.061 " 150°00'49.133'' 46' 113.9 12 5,938,325.20 498,310.17 70°14' 33.815" 150°00'49.131" 21' 94' 113.9 118.5 I EN.L. 13 5,938,235.31 i 498,310.37 70° 14' 32.930" 150°00'49.125" 69' 94' 113.7 118.5 14 5,938,210.14 ! 498,310. t6 70 °14' 3~.683" 150°00'49.131'' 94' 113.7 ~ 150° 00'49.131'' 119' 15 5,938,185.12 ! 498,310.16 70°14' 32.437" i 113.8 16 5,938,160.11 498,310.20 70°14'32.191'' 150°00'49.130'' 144' ~ 113.8 17 5,938, 135.21 498,510.18 70014' 31.946" 150°00'49.130'' 169' 115.9 18 5,938,110.19 498,310.29 70°14'31.700" 150°00'49.127'' 194' 114.0 19 5,938,085.?_0 498,310.27 70014' 31.454" 150°00'49.127" 219' 114.o 21 5,938,035.16 I 498,510.16 70Ol4'30.96z" 150°00'49.150'' 269't 114.0 22 5,938,010.40 498,310.19 70°14' 30.718" 150° 00' 49. 129" 294' 94' I 14.0 ~ 23 5,937,985.3Z 498,310.13 70 °14' 30.471'' 150o 00'49. 130'' 319' 95' 114.0 ~' 24 .5 ~937,960.29 498,310.08 70o14'30.225" 150°00'49.132'' 344' 95' I 113.9 118.5 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2 thru 8) ' 2. 4. 5. 6. 7. 8. (8) ('9 ~hru 13) 10. ~,~. ~-~-$~ 11. (10 a~ 13) 12. 13. (4) Casg ~'~ ~!~, ......... ' ~-:~ '~ (14 thru 22) (]5) BOPE ~. ~.,':~:~' ,.~ ---- (23 thru 28) Company .,~~ Is the permit fee attached .......................................... Lease & Well No. YES NO Is well to" be located in a defined pool ............................. ~ Is well located proper distance from property line .................. ~ Is well located proper distance from other wells .................... ~,_ Is sufficient undedicated acreage available in this pool ............ ~ . ...... Is well to be deviated and is wellbore plat included ................ ~_ Is operator the only affected party ................................. Can permit be approved before fifteen-day wait ...................... ~s Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ .,, Will surface casing protect 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/~,f Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (29 thru 31)' rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. __ //_,,zz / INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE · Additional Remarks: O 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. ~~'~~~~~~ A~L&SKA COMPUTING CE:NTER · SCHLUMBERGER ....... · COMPANY NAME : ARCO ALASKA INC. WELL NAME : 2K ' 8 FIELD NAME : ~UPARUK ~O~OUGH : NORTH S:LOPE STATE : ALASKA API NUMBER : 50-103-20111-00 REFERENCE NO : 73~60 LIS TAPE VERIFICATION LISTING SCHLUM~.ERGER ALASKA COMPUTING CENTER 17-SEP-1989 12:14 P A G E: · ~,~ REEL HEADER ~**~ SERVICE NAME :EDIT DATE : 89/09Y17 ORIGIN : FLIC REEL NAME : T)460 CONTINU.~TION ~ : PREVIOUS REEL : COMMENT : ARCO ALR!SKA INC.,KUP&RUK,2K- 8,50-103-20t11-00 · ~,~ TAPE HEADER SERVICE NAME : EDIT DATE : ORIGIN : FIIC TAPE NAME : CDNTINUATIaN ,~ : ~ PREVIOUS TAPE : COMMENT : ARC~ ~LASKA INC.*KUPARUK,2K - 8,50-~03-20111-00 **** FILE HEADER ***~x FILE N~ME : EDIT .00! SERVi[CE : FLIC VERSION : 001A02 DATE : S9/09/17 MAX EEC SIZE : lOZ~ FILE T~PE : LO LAST FILE : SCHLUMBERGER WELL SERVICES COMPANY NAME: ARCO ALASKA INC. WELL: 2K - 8 FIELD: KUPARUK BOROUGH: NORTH SLOPE STATE: ALASKA ~PI NUMBER: 50-103-20111-00 LOCATION: 121' FSL & 9¢' FEL SECTION: Z TOWNSHIP: 1ON RANGE: 8E PERMANENT DATUM: MSL ELEVATION: O' ~LDG MEASURED FROM RKB 154' ABOVE PERMANENT DATUM LIS TAPE VERIFICATION LISTING SCHLUMBERGER ~LASKA COMPUTING CENTER 17-SEP-1989 12:14 PAGE: ELEVATIONS KB: 154' OF: 153' GL: 113' DATE LOGGED: RUN NUMBER: TD DRILLER: TO LOGGER: 30.-AUG-1989 ONE 9445' 94¢1' CASING 1: 9 5/8" L8 @ DRILLER DEPTH OF 3770' AND LOGGER OEPTH OF 3770' BIT SIZE 1: TYPE FLUID IN HOLE: WEIGHTED POLYMER DENSITY: 10.2 VISCOSITY: 40 PH: 9.5 FLUID :LOSS= 4 MUD RESISTIVITY: FILTRATE RESISTIVITY: MUD CAKE RESISTIVITY: 4.45 2 59 4.06 ~: 59 3.13 @ 59 TIME CIRCULATION ENDED: 18:00 AUGUST 30 TIME LOGGER ON 80TTOM: 02:53 AUGUST:31 MAXIMUM TEMP RECORDED: 143 LOGGING DISTRICT: LOGGING ENGINEER:' WITNESS: P~UOHDE BAY FRITrZKE/SCHWAR'TZ RDBERTSON/BOND/DEREK TOOL NUMBERS: SGC-JC 3109 NLM.-BC 132 DIC-DA 1006 IE~-BD 1448 :C NC-A 1238 PGS-HB 10.26 DIS-EC 1100 NLM-BC 1329 FIELD REMARKS: 1 1/2" STANOOmFS AND A 2' HOLE FINDER USED ON THE OIL. M6TRIX DENSITY = 2.65 G/CC., FLUID DENSITY = 1.0 G/CC. NEUTRON MATRIX : SAND, HOLE CORRECTION : CALIPER. DATE JOB STARTED: 6-SEP-Bg JOB REFERENCE NO: 73460 LOP/ANA: R. KRUWELL FILE - EDIT.O01 ARCO ALASKa INC. KUPARUK 2K - 8 50-103-20111-00 .'IS TAPE VERIFICATION LISTING ~CHLUMBERGER ALASKA COMPUTING CENTER 17-SEP-1989 1:2:14 PAGE: aMAIN PASS LOG OATA" DATA SAMPLED EVERY -.5000 FEET :DATA .INCLUDED- TOOL EXTENSION TOOL TYPE :US ED NAME D.It-D oDIL DUAL INDUCT'ION FOC .FOC FORMATION DENSITY C NT-A/O/H .CNL COMPENS ~T.ED NEUTRON GR .CS~ GAMMA TABLE TYPE : C~NS; TUNI VALiU DEF[ CN ARCO A:LASKA INC. COMPANY NAME FN KUPARUK FIELD NAME WN 2K - B WELL NAME APIN 50-1'03-20111-00 API SERIAL ~NUMBER FL 121' FSL [ 94' FEL FIELD LOCATION SECT 2 SECTION TOWN 1ON TOWNSHIP RANG BE RANGE COUN NORTH SLOPE COUNTY STAT ALASKA STATE OR PROVINCE NATI :USA NATION ENGI FRITZKE/SCHWARTZ ENGINEER'S NAME WITN RDBERTSON/BOND/DEREK WITNESS'S NAME SON 73460 SERVICE ORDER NUMBER PDAT MSL PERMANENT DATUM EPD FT O. LMF RKB LOG MEASURED FROM APO FT 154. EKB FT 154. EOF FT 153. EGL FT 113. TOD FT 9445. BLI FT 9432. BOTTOM LOG INTERVAL TLI FT 1000o TOP LOG INTERVAL TCS 13:00 AUGUST 30 TIME CIRCULATION STOPPED TLAB 02:53 AUGUST 31 TIME LOGGER AT BOTTOM LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER 17-SEP-1989 1Z:14 TABLE TYPE : CURV O ~F'I DEPT DEPTH CHANNEL NAME ILO IL-DEEP RESISTIVITY ILM IL-MEDIUM RESISTIVITY SFLU SFL UNAVERAGED SP SPONTANEOUS POTENTIAL GR GAMMA. RAY TENS TENSION RHOB BULK DENSITY DPHI DENSITY POROSITY DRHO DELTA AMD RFFD RAW FAR FDC COUNT RATE RNFD RAW NEAR FDC C~:UNT RATE FF~C FAR FOC COUNT RATE NFOC NEAR FDC COUNT RATE CALI CALIPER G~ GAMMA RAY TENS TENSION NPMI NEUTRON PO~OSI'TY TNPH THERMAL NEUTRON POROSITY TNRA CAL!8~ATEO THERMAL NEUTRON RATIO RTNR RAW THERMAL NEUTRON NPOR NEUTRON POROSITY OUTPUT FROM AN APPLICATION PROGRAM RCNT RCFT CNTC CFTC GR TENS GR TENS RAW CORRECTED NE,~R THERMAL'COUNTS RAW CORRECTED FAR THERMAL COUNTS CORRECTED NEAR THERMAL COUNTS CORRECTED FAR THERMAL COUNTS GAMMA RAY TENSION GAMMA RAY TENSION PAGE: DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 T3 120 4 66 1 5 66 6 73 ? 65 8 68 0.5 9 65 FT 11 66 8 LIS TAPE VERIFICATION LZSTING SCHLUMBERGER ALASKA COMPUTING CENTER 17-SEP-1989 12:14 PAGE: TYpE REPR CODE VALUE ! 2 68 13 66 0 14, 65 =T 15 66 68 1, 6 66 1 0 66 0 *~ SET TYPE - CHAN '~ NAME SERV ~UNIT SER'VICE APl API AP'I :APl FiLE NUmB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SANP ELEM CODE CHEX) DEPT FT 548366 O0 000 O0 0 I 1 1 4 68 0000000000 ILO OIL OHMM 549366 O0 000 '00 0 I 1 1 ,4 68 0000000000 ILM DI~L OHMM 548366 O0 000 O0 0 1 1 1 4 68 OOO0000000 SFLU OIL OHMM 548366 '00 000 O0 0 ! 1 I 4 68 O00000OO00 SP DIL MV 548366 O0 OOO O0 0 1 1 1 4 68 0000000000 GR OIL GAPt 548366 O0 000:00 0 1 1 1 4 68 0000000000 TENS OIL L8 548366 O0 OOO O0 0 1 I I 4 68 0000000000: RHOB FDC G/C3 548366 O0 000 O0 0 1 1 1 4 68 0000000000 DPHi FDC PU 548366, O0 000 O0 0 1 1 I 4 68 0000000000 DRHO FDC G/C3 548366 O0 000 O0 0 1 1 I 4 68 000000000'0 RFFD FDC CPS 548366 O0 000 O0 0 1 1 1 4 68 0000000000 RNFD FDC CPS 548366 O0 000 O0 0 I I I 4 68 0000000000 FFDC FDC 'CPS 548366 O0 000 O0 0 1 I 1 4 68 0000000000 NFDC FDC CPS 548366 O0 000 O0 0 1 I 1 4 68 0000000000 CALl FDC IN 548366 O0 0:00 O0 0 I I 1 4 68 OOO0000000 GR FDC GAPI 548366 O0 000 O0 0 I I I 4 68 00000:00000 TENS ~DC LB 548366 O0 000 O0 0 I 1 1 4 68 0000000000 NPHI CNL PU 548366 O0 DOD O0 0 1 t 1 4 68 0000000000 TNPH CNL PU 548366 O0 000 O0 0 ! 1 1 4 68 0000000000 TNRA CNL 548366 O0 000 O0 0 I I 1 4 68 0000000000 RTNR CNL 548366 O0 000 O0 0 1 1 I 4 68 0000000000 NPOR CNL PU 548366 O0 000 O0 0 1 1 1 4 68 0000000000 RCNT CNL CPS 548366 O0 000 O0 0 1 1 1 4 68 DO00000000 RCFT CNL CPS 548366 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNL CPS 548366 O0 000 O0 0 1 I 1 4 68 0000000000 CFTC CNL' CPS 548366 O0 000 O0 0 1 1 1 4 68 0000000000 GR CNL G~PI 548366 O0 000 O0 0 I 1 1 4 68 0000000000 TENS CNL LB 548366 OD 000 O0 0 1 1 ! 4 68 0000000000 GR CSG GAPI 548366 O0 DO0 O0 0 1 1 1 4 68 0000000000 TENS CSG LB 548366 O0 000 OD O 1 1 1 4 68 O0000OO000 DATA DEPT. 9443°000 ILD.DIL -999.ZE0 ILM.DIL -999.250 SFLU.DIL SP.DIL -999.250 GR.DIL -999.250 TENS.OIL -999.250 RHOB.FDC DPHI.FDC 61.599 DRH~.FDC -0.006 RFFD.FOC 4940.000 RNFD. FDC FFDCoFDC 3370.000 NFOC.FDC 980.500 CALI.FDC 1.986 GR.FOC -999.Z50 1.634 1713.000 96.125 LIS TAPE VERIFICATION LISTING :SCHLUMBERGER ALASKA COMPU'TtNG CENTER TEN$.FDC 36~0.000 NPHZ.CNL RTNR.CNL 3.'730 NPOR'CNL CNTC.CNL 2045.179 CFTC.CNL GR.CSG -999.250 TENS.'CSG DEPT. 9400. 000 SP.OIL -26.297 DPHI. FOC 32' 0 9:5 FFOC.FDC 1328.000 TENS. FDC 491-2.000 R TNR. CNL 3 . 730 CNTC.CNL 202.7. GR.CSG -999. 250 ILO. GR. D IL DR HO. FDC NFDC. FDC N PHI. C N L NPOR.CNL C FTC' C NL TENS .CSG DEPT. 9300.000 SP. DIL -29.219 DPHI.FDC 12.514 FFOC. FDC 53,2. 000 TENS. FDC 5020. 000 R'TNR.CNL 3- 964 CNTC. CNL 18.26.740 GR.CSG -999.. 250 ILO.OIL GR. O IL DRHO.FDC NFOC.FOC NPMI.CNL NPOR.CNL CF TC,,. CNL TENS.~CSG DEPT. 9200.000 SP.OIL -36.438, DPHI.FDC 9.847 FFDC.FOC 450.000 TENS. FOC 4964.00.0 R T N R. C N L 3 . 4 00 CNTC.CNL 2314.030 GR.CSG -999.250 I LDo OIL GR.DIL O R HO. F O C NFOC. FDC NP HI. CNL NP DR.;CNL C F T:C. C N:L TENS.CSG DEPT. 9100.000 SP.DIL -51.781 DPHI.FDC 20'.176 FFDC.FDC 670.500 TENS.FDC 4958.000 RTNR.CNL 2.786 CNTC.CNL 2642.723 GR.CSG -999.250 ILO.OIL GR.DIL ORHO.FDC NFDC.FOC NPHI.CNL NPOR.CNL CFTC.CNL TENS.CSG DEPT. 9000.000 I SP.DIL -44.344 DPHI.FDC 9.869 DR FFDC.~DC 463.500 NF TENS.FDC 4840.000 NP RTNR.CNL 3.619 NP CNTC.CNL 1972.530 CF GR.CSG -999.250 TE LO.OIL GR.DIL HO.FDC DC.FDC HI.CNL OR.CNL TC.CNL NS.CSG DEPT. 8900.000 I SP.DIL -33.656 DPHI.FDC 11.423 DR FFDC.FDC 419.250 NF TENS. FDC 4924.000 NP LD.DIL GR.DIL HO.FOC DC.FDC HI.CNL 17-SEP-1989 12:14 49.950 TNPH. CNL 41.219 ~CNT.CNL 600.830 GR.CNL -999.250 3.688 ILM.DZL 27.453 TENS.OIL 0.103 RFFO.FOC B81. 000 CALI.FOC 43.66? TNPH. CNL 37. 917 RCNT.CNL 631.'396 GR..CNL - 999.250 4.479 ILM.OIL 99.8:13 TENS.DIL :0.054 RFFD.FDC 63.5. 500 CALI.FOC 45.676 TNPH.CNL 42.598 R C N T. C NL 540 517 GR.CNL - 9'99.250 7.003 ILM.OIL 91.063 TENS.OIL 0.030 RFFD.FOC 584.500 CRLI.FDC 36. 007 TNPH'CNL 34.634 RCNT.CNL 781.430 GR. C N:L -999.250 22'215 ILM.OIL 53.313 TENS.OIL D.022 RFFD.FDC 649.000 CALI.FOC 27.616 TNPH.CNL 26.788 RCNT.CNL 1024.084 GR.CNL -999.250 2.872 ILM. DIL 127.500 TENS.OIL 0.042 RFFD.FOC 599.500 CALI.FDC 37.152 TNPHoCNL 36. 273 RCNT.CNL 601.591 GR.CNL -999.250 2.159 ILM. DIL 87.188 TENS.OIL -0.025 RFFD.FOC 498.000 CALI.FDC 51.057 TNPH.CNL 41.219 1997.564 96.125 3.78! 4352.000 1618.000 6.555 38.150 1990.773 96.125 4.577 4944.000 747.500 8o89S 40.548 1708.460 100.500 7.002 ,~984..000 670.500 8.. 766 34.024 2227.049 90.688 22.266 4944.000 997.500 9.133 27.875 2661.293 51.906 2.829 5068.000 644.500 9.664 38.389 2022.032 124.188 1.976 4628.000 605.500 9.320 44.647 TNRA'CN:L RCFT.CNL T'ENS.CNL SFLU. DIL RHOB. FDC RNFD. FDC GR. FDC T NRA. C NL RCFT.CNL T E N S.. CNL SFLU. OIL RHOB.FDC RNFO.FDC GRoFDC T N R A. C N L RCFT. CNL TENS.CNL :SFLU. DIL RHOB'FDC RNFO.FDC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL SFLU.OIL RHOS.FDC RNFD.FDC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL SFLU.DIL RHOB.FDC RNFD. FDC GR.FOC TNRA.CNL RCFT.CNL TENS.CNL SFLU. DIL RHOS.FDC RNFD.FDC GR.FDC TNRA.CNL P AG E: 3.461 527.887 3650.000 3.566 2.121 1480.000 96.125 3.392 560.772 4912-000 4.406 2.444 1133.000 100-500 3.667 476.684 5020.000 7.126 1052.000 90.688 3.1-28 6.65.422 .4964.000 16.243 2.317 1101,000 51.906 2.632 949.843 4968.000 2.928 2.487 1086.000 124.188 3.264 549.088 4840.000 1.488 2.462 882.500 108.813 3.996 .IS 'TAPE VERIFICATION LISTING ~CHLUMBERGER ALASKA COMPUTING CENTER RTNR.CNL 4.283 NPOR.CNL CNTC.CNL 1817.566 CFTC*CNL GR.CSG '-999,250 TENS.C.SG DEPT. 8800. 000 !LO. S P,. OIL -46.344 GA,. O IL DPHI.FDC [8.89! ORHD,FOC FFDC.FDC 624,500 NFDC.FDC TENS.. FDC .¢912. OOO N'PHI.CNL RTNR.CNL 4.386 NPQR.CNL CNTC.CNL 1692.879 CFTC.CN:L GR.CSG -999.250 TENS.CSG DE PT. 8700.0 00 ILO. SP. OIL -46.094 GR.DIL DPHI.FDC -999.Z50 DRHO.FOC F~DC,FDC -999.250 NFOC.FDC TENS..FDC '-999. 250 NPHI.CNL RTNR,.CNL -999.2 50 NPOR.CNL CNTC. CNL -999.250 CF T'C.CNL GR.CSG -999.250 TENS.CSG DE PT. 8600. 000 ILO. SP.DIL '-~3. 000 GR.DIL DP'HI,FDC -999.2.50 ORHO.FOC FFDC,FDC -999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -9'99.250 CFTC.CNL G....R. C S G -999.250 TENS.CSG DEPT. 8500.000 ILO.OIL SP.DIL -9.680 GR.DIL DPHI.FOC -999.250 DRHO.F~C FFOC.~DC -999.250 NFDCoFDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTCoCNL -999.250 CFTC.CNL GR.CSG -999. 250 TENS.CSG DEPT. 8400.000 ILO.OIL SP.DIL -41.250 GR.DIL DPHI.FDC -999.250 DRHO. FDC FFDC,FDC -999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG -999.250 TENS.CSG DEPT. 8300.000 ILO.OIL SP.DIL -44.406 GR.DIL DPHI.FDC -999.250 DRHO.FDC FFDC.FDC -999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL 17-SEP-1989 12:14 46o 845 RCNT.CN:L 497.71'7 GR.CNL - 9'99. 250 2. 385 ILM.DI:L 111.188 TENS.OIL O, 014 RFFD.FDC 627. 000 CALI. FOC 47° 2:3,5 TNPH. CNL 46,877 RCNT.CNL 460.13 $ G R .. C N L -999. Z50 1 6'9 9,919 108.813 2.~ 58 4 800. 000 87 0.. 0:00 9.305 45.104 1 59 6- 861 120,625 4.144 ILM'DIL 4.430 187. 500 TENS.OIL 5392.-000 -999.250 RFFD.FDC -999.Z50 -999,250 CALI.FOC -999,250 -99'9,250 TNPH.CNL -999,,250 - 999 ,..25 O R C N'T. C NL - 99 9 o Z 50 -999. 250 GR.CNL -999,° 250 -999,250 3.120 ILM.DIL 3.219 273. 250 TENS.OIL 5340.000 -999.250 RFFD.FOC '-999.Z50 '-999., 250 CALIoFOC -999,250 -999.250 TNPH.CNL -999.250 -99'9.250 RCNT.CNL -999.250 -999. 250 GR.CNL -999.Z50 -999.250 4.505 ILM.DIL 166. 875 TENS.DIL -999.250 RFFD.FOC -999.250 CALI.FOC -999°250 TNPH.CNL -999. ZSO RCNT.CNL -999.250 GR, CNL -999.250 ~.176 4960.000 -999. Z50 -999. 250 -999.250 -999.Z50 -999.250 3.996 ILM.DIL 4.018 108.938 TENS.OIL 4752.000 -999.25-0 RFFD.FDC -999.250 -999.250 CALI.FDC -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL -999.Z50 -999,250 GR.CNL -999.250 -999°250 3.967 ILM. DIL IZI.IBB TENS.DIL -999.250 RFFD. FDC -999.Z50 CALI. FDC -999.Z50 TNPH.CNL -~99.250 RCNT.CNL 3.990 5004.000 -999.250 -999.250 -999.250 -999.250 RCFT.CNL TENS.C:NL ; SFLU, DIL RHOB.FDC R'NF g. FDC G:R. FDC TNRA,.CNL RCFT..CNL TENS.CNL SFLU. DIL RHOB., FDC RNF D., FDC GR. FOC TNRA.CNL RCFT.CNL TENS.CNL SFLU.:DIL RHD~8 FDC RNFD.FDC GR.FDC TN~A,CNL RCFT.CNL TENS.CNL SFLUo RHOB. FDC RNFO.. FDC GR, FDC TNRA.CNL RCFT.CNL TENS .CNL SFLU.DIL RHDB.FDC RNFD.FDC GR.FDC TNRA.CNL RCFT.CNL TENS .CNL SFLU.DIL RHOB. FDC RNFD. FDC GR.FDC TNRA.CNL RCFT.CNL PAGE: 437.643 2.425 2.338 1093.~000 120.625 3.786 411.750 4912.000 5.062 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.913 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.293 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.593 -999-250 -999.250 -999.250 -999.250 -999.250 -999.250 4.711 -999.250 -999.250 -999.250 -999.250 -999.250 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER CNTC.CNL -999.250: CFTC.CNL GRoCSG -999.250 TENS.,CSG DEPT. 8200.000 ILO. OIL SP. DIL -48.719 GR. DPHI.FDC -999.250 DRHO. FOC FFDCoFDC -999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999'250 NPORoCNL CNTC.CNL -999.250 CFTC.CNL GR.CSG -999. 250 TENS.CSG O E P T. 8100.0 00 I L O. O I L SP.OIL -48.906 GR.DIL DPHI. FDC -999.2.50 ' ORHO'FDC FFDC,.FDC -9'99.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NFOR.CNL CNTC.CNL -999.250 CFTC.CNL GRoCSG -999.250 TENS.,CSG DEPT. 8000.000 ILO.OiL SP. OIL -~6.125 GR.DIL DPHI.FDC -999.250 DRHO.FDC FFDC.FDC -999.250 NFDC.FDC TENS.FDC -99'9.250 NPHI.CNL RTNR. CNL -999. 250 NPO'R.CNL CNTC..CNL -999.250 CFTC.CNL GR.CSG -999.250 TENS.CSG DEPT. 7900.000 ILO. DIL SPoOIL -50. 250 GR. OIL DPHI.FDC -999.250 DRHO.FOC FF'DC.FDC -999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPgR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG -999.250 TENS.CSG DEPT. 7800.000 ILD.DIL SP.DIL -56.500 GR.DIL DPHI.FDC -999.250 DRHO.FOC FFDC.FDC -999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG -999.250 TENS.CSG DEPT. 7700. 000 ILD.DIL SP.OIL -63.469 GR.DIL DPHI.FDC -999.250 DRHO.FDC FFDC.FDC -999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -9'99.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL 17-SEP-1989 12:I4 -999.250 GR.CNL -999.250 ¢.590 ILM.DiL t01.000 TENS.OIL -999.:250 RFFD.FOC -999.250 CALI.FDC -999.2$0 TNPH.CNL -999.250 RCNT.iCNL -999.250 GR.CNL -999.250 3.783 121.375 -999.250 - 999.250 -999.250 -'999. ,250 -999.250 -999.250 2'96! 117.313 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.135 149.125 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.660 135.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999°250 3.915 132.625 -999.250 -999.250 -999.250 -999.250 -999.250 ILM.OIL TENS.OIL RFFD. F DC C AL I. FDC TNPH. CNL RC NT. CNL GR.CNL ILM.DIL TE NS. D IL RFFD.FOC CALI. FDC T N P H. CNL RCNT.CNL GR.CNL ILM. DIL TENS.OIL RFFD. FOC C AL I. FOC TNPH.CNL RCNT.CNL GR. CNL ILM.DIL TENS.DIL ~,FFD. FOC CALI.FDC TNPH. CNL RCNT.CNL GR.CNL ILM.DIL TENSoDIL RFFD.FDC CALI.FOC TNPH.CNL RCNT.CNL GR.CNL -999.250 4. 522 4 920.000 -999.250 -999.250 -999.250 -999.250 -999°250 3.839 4668.000 -999'250 -999.250 '-999.250 · -99 9. Z 50 -999.250 3. 018 ¢980.O0O -99 9.250 -999'250 -999. 250 - 999. Z 50 -999.250 4. ! 95 -999.250 -999.250 -999.250 -999.250 -999.250 3.640 4472.000 -999.250 -999.250 -999.250 -999.250 -999.250 4.162 4240.000 -999.250 -999.250 -999.250 -999.250 -999.250 TENS.CNL S F t U. D I L R HO B. FOC RNFD. FDC GR.FDC T.NRA.CNL RCFT. CNL TENS.CNL S FL U. D I L RHO,B.FDC RNFO. FDC G R o FDC TNRAoCNL R C F T. C N L TENS.CNL SFLU. OIL RHDE.FDC RN:FD. FDC GR.FOC TNRA.CNL RCFT.CNL TENS.CNL S~LU. OIL RHOS.FDC RNFDoFDC GR.FOC TNRA.CNL RCFT.CNL TEN$oCNL SFLU.DIL RHOB'FDC RNFDoFOC GR.FDC TNR~oCNL RCFT.CNL TENS.CNL SFLU.DIL RHOE.FDC RNFD. FDC GR.FDC TNRA.CNL RCFToCNL TENS.CNL PAGE: -999.250 4.463 -:999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.410 -999'250 -9'99-250 -999.250 -999.250 -999.250 -999.250 2.614 -999'250 -999.250 -999.250 -999.250 -999.250 -999.250 3.933 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.560 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.115 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .IS TAPE VERIFI:CATION LISTING SCHLUMBERGER ALASK~ COMPUTING CENTER GR.CSG -999.250 TENS.CSG DEPT. 7600.000 ILO.OIL SP.OIL -66-6,88 GR.DIL DPHIoFDC -999.250 ORHO,FOC FFDC.FDC -999.250 NFDCoFDC TENS. FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CN!L CNTC.CNL -999.250 CFTC.CNL GR.CSG -999.250 TENSoCSG DEPT. 7500.000 ILD.DIL SPo DIL -7¢. 750 GR.DIL DPHI.FDC -999'250 DRHO.FDC FFDC.FDC -999.250 NFDC.FDC TENS. FDC -999. 250 NPHI. CNL RTNR.. CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.C'S~ -999.250 'TENS.CSG DEPT. 7400. 000 ILO.OIL SP. DIL -74.625 GR..OIL DPHI.FDC -999.250 DRHO.FDC FFDC.FDC -999o 250 NFDC.FDC TENS.FDC -999. 250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999. 250 CFTC.CNL GR.CSG -999-250 'TENS.CSG DEPT. 7300. 000 ILO.OIL SP. DIL -101. 000 GR.DIL DPHI.FDC -999.2.50 ORHO..FOC FFDC.FDC -999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG -999. 250 TENS.CSG DEPT. 7200. 000 ILD.DI~L SP.DIL -80.000 GR.DIL OPHI.FDC -999.250 DRHO.FOC F~DC.CDC -gg9. 250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG -999.250 TENS.CSG DEPT. 7100.000 ILO.OIL SP.DIL -77.375 GR.DIL DPHI.FDC -999.250 DRHO.FDC F~DC.~DC -999.250 NFOC.FOC TENS.FOC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG -999.250 TENS.CSG 17-SEP-t989 12:14 -999.250 4.009 ILM.DIL 4.000 126'688 TENS.OiL 4140.000 -999. 250 RFFD.,FDC -999.250 -999..250 CALI.FOC -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL -999.250 - 99 g. 2 S 0 G R, C N L - g 9 9. Z 5 0 -999.250 4.020 I L M. D I L 4.027 137.750 TENS.DIt 422B.000 -999.250 RFFD. FDC -999.250 -999.250 CALI.FDC -999.250 -999.250 TNPH. CNL -999.250 -999.250 RCNT'CNL ,-999.250 -999. 250 GR. CNL -999.250 -999. 250 3.904 ILM. DIL 127. 875 TENS.DIL -999°250 RFFD.FDC -999o 250 ' CALI.FDC -999.250 TNPH. CNL -999.250 RCNT.CNL -999.250 GR.CNL - '999.250 3.938 40z, O.O00 .-999. 250 - 99 9.o 250 -999.250 -999.250 -999.250 4.179 ILN.DIL 4.295 88. 188 TENS.OIL 4080.000 -999.250 RFFD.FDC -999.250 -999o250 CALI.FDC -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 GR.CNL -999.250 -999.2.50 3.287 ILM.DIL 3.32B 98. 313 TENS.OIL 4244.000 -999.250 RFFD.FDC -999.250 -999.250 CALI.FOC -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL --999.250 -999. 250 GR.CNL -999. 250 -999.250 3.463 ILM.DIL 80.938 TENS.DIL -999.250 RFFD.FDC -999.250 CALI.FOC -999.250 TNPH.CNL -999.250 RCNT.CNL -999.250 GR.CNL -999.250 3.463 4164.000 -999.250 -999.250 -999.250 -999.250 -g99.250 SFLU.DIL RHO5. FDC RNFD. FDC ~ GR. FDC TNRA oCNL RCF'T'CNL TENS.CNL S FLU. OIL RHOB.. FDC RNFD. FDC GR. FDC TN RA o CNL RCFT. CNL TENS.CN.L SFLUoDZL Rtl08o FDC RNFD. FDC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL SFLU.DIL RHOB. FDC RNFO.. FDC GR.. FDC TNRA.CNL RCFT.CNL TENS.CNL SFLU.OIL RHOB.FDC RNFD.FDC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL SFLU.DIL RHOB. FDC RNFD.FDC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL PAGE: 3.506 -999'250 -999.250 -999.250 -9'99.250 -999.250 -999.250 3.938 -999.250 -999'250 -999.250 -999.250 -999'250 -999.250 3.713 -999.250 -999.250 -999.250 -999.250 -999'250 -999.250 5.423 -999.250 -999.250 -999. 250 -999.250 -999. 250 -999.250 3.088 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.123 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS 'TAPE VERIFICATION L:STING SCHLUMBERGER ALASKA. COMPUTING CENTER DEPT.. 7000.000 ILO.OIL SP.DIL -73.000 GR.DZL DPHI.FDC -999'250 ORHO.FDC FFDC°FDC -999.250 NFOCoFD:C TENS.FDC -'999.25,0 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG -999.250 TENS.CSG 6900.0 00 I L D. D I L OIL -83.500 GR.OIL DPHI.FDC -999.250 ORHO.FDC FFDC.FDC -999.250 NFDC..FDC TENS.FDC -999.250 NPHI.CNL R'TNR. CNL -999.250 NPOR.CNL CNTC.CNL -999.Z50 CFTC.CNL GR..CSG -999-250 TENS.CSG DEPT. 6800.000 ILO. OIL SP. OIL -83.188 GR.DIL DPHI.FOC -999'Z50 DRHO.FDC FFOC.FDC -999.250 NFDC.FOC TENS..CDC -999.250 NPMI.CNL RTNR'CNL -999.250 NPOR.CNL CNTC. CNL -999. 250 ' CFTC.CNL GR.CSG -999.250 TENS.CSG DEPT. 6700.000 ILO. OIL SP..DIL -81.000 GR.DIL DPHI.FDC -999..250 ORHO.FDC FFOC.FOC -999.250 NFDC.'FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTCoCNL GR.CSG -999.250 TENS.CSG DEPT. 6600.000 ILO.OIL SP..OIL -76.938 GR.DIL DPHI.FDC -999.250 DRHO. FDC FFDC.FDC -999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG -999.250 TENS.CSG DEPT. 6500.000 ILO.OIL SP.DIL -72.313 GR.DIL DPHI.FDC -999.250 DRHO.FDC FFDC.FDC -999.250 NFDC.FDC TENS.FOC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG -999.250 TENS.CSG 17-SEP-1989 12:14 3.'¢48 ILM.DIL 3.31~ 108.875 TENS'DIL 3894.000 -999.250 ~ RFFD.FDC -999'250 -999°250 CALI.FOC -999°250 -999.250 TNPH.CNL -999.250 - 9'99.25 O R C N'T. C NL - 999. Z 50 -999. 250 GR.CNL -999,.250 -999.250 4.197 ILM. DIL 4.108 129.125 TENS'OIL 3684.000 -999.250 RF'FD..FDC -999.250 -999.250 CALI'FOC -999.250 -999°250 TNPH.CNL -999.250 - 999.250 R C NT.. C NL - 99 9. Z 50 -999.250 GR.CNL -999.250 -999,° 250 4.170 tLM.OIL 150.750 T E N S · D ! L -999.250 RFFD.FDC -999. 250 CALI. FOC -999.250 TNPH.CNL -999.250 RCNT.CNL - 999.250 G R. C NL -999.250 4.130 3814.000 -999.250 -999.250 -999./50 -99 9.250 -999. 250 3.465 ILM. OIL 3.:563 150.500 TENS.OIL 385¢.000 -999.250 RFFDoFDC -999.250 -999°250 CALI.FDC -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 GR.CNL -999. 250 -999.250 3.880 ILM.OIL 3.889 215.250 TENS.OIL 3824.000 -999.250 RFFD.FDC -999.250 -999.250 CALI.FDC -999.250 -999.250 TNPH. CNL -999.250 -999.Z50 RCNT.CNL -999.250 -999. 250 GR.CNL -999.250 -999.250 2.41~ ILM.OIL 2.501 153.750 TENS.DIL 3874.000 -999.250 RFFD.FDC -999.250 -999. ZEO CALI.FDC -999.Z50 -999.250 TNPM.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 GR.CNL -999.250 -999.Z50 S FLU,. OIL RHOS. FDC RNFD. Foe GR.FDC TNRA.CNL RCFT:.CNL 'TENS. CNL SFLU.DIL RHOB. FDC RNFD. FOC G R. FDC TNR~'CNL RCFT.CNL TENS.CNL $ FLU. OIL RHOB. FOC RNFg. FDC GR. FDC TNRA.CNL RCFT.CNL T E NS. CNL SFLU.DJL RHOB.FDC RNFD. FOC GRoFOC TNR~.CNL RCFT.CNL T~NS.CNL SFLU.DIL RHOB.FDC RNFD. FDC GR.FOC TNRA.CNL RCFT.CNL TENS.CNL SFLU. DIL RHOB. FDC RNFO.FDC GR.FDC TNRA .CNL RCFT.CNL TENS.CNL PAGE: 10 3.297 -999.:250 -999.250 -999.250 ,-999.250 -999.250 -9'99.250 4.084 -999' 250 -999.250 -999.250 ~-999. 250 -999' Z 50 -999.250 4.01! -999.250 -999.25'0 -999.250 --999.250 -999.250 -999.250 3.428 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.037 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.496 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ~IS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING D E P T. 64 00.000 SP. OIL -75.813 DPHI.F~)C -999. 250 FFDC.FDC -999.250 TENS.FOC -999.250 RTNR'CNL -999. 250 CNTC.CNL -999. 250 GR.CS~ -999.250 DEPT. 6300. 000 SP.DIL -75.125 OPHI. FDC -999.250 FFOC.FOC -999. 250 TENS. FOC -999. 250 RTN~. CNL -999.250 CNTC.CNL -999.2 50 GR.CSt -999.250 DEPT. 6200.000 SP. OIL -86.938 DPMI.FDC -999.250 FFDC.FOC -999,250 TENS.FDC -999.250 RTNR.CNL -999. 250 :CNTC.CNL -999.250 GR.CSG -999.250 DEPT. 6100.000 SP.DIL -80. 188 DPHI.FDC -999.250 FFDC.FDC -999.250 TENS.FDC -999.Z50 RTNR.CNL -999.250 CNTC.CNL -999.250 GR.CSG -999.250 DEPT. 6000.000 SP.DIL -82.688 DPHI.FDC -999.250 FFDC.FDC -999.250 TENS. FDC -999.250 RTNR.CNL -999.250 CNTC.CNL -999.250 GR.CSG -999.250 DEPT. 5900.000 SP.OIL -84.250 OOHI. FDC --999. 250 F=DC.FDC -999.250 TENS.FDC -999.250 RTNR. CNL -999.2 50 CNTC.CNL -999.250 GR.CSG -999.250 CENTER ILD.DIL G R. D I L ORHO.FOC NF DC. FDC NPHI.CNL NP OR. C NL C F T C' C N L TENSoCSG I L D. O I L GR .OIL ORHO.FDC NF O:C. F DC NPHI.CNL NP OR.. C NL CFTC.CNL TENS.CSG ILO.OIL G R. O I L OR H O. F DC NFDC. FDC N P H I. C N L NPOR .CNL CFTC.CNL TENS.CSG I LO.OIL GR. D I1 DRHO.FDC NFOC. FDC NPHI.CN1 NPOR.CNL CFTC .CNL TENS.CSG ILD.DIL GR.DIL DRHO.FDC NFDC.FDC NPHI .CNL NPOR.CNL CFTC.CNL TENS.CSG ILO.OIL GR.DIL DRHO.FOC NFOC.FOC NPHI. CNL NPOR.CNL CFTC.CNL TENS.CSG 17-SEP'-1989 12:14 2.297 iLM. OIL 2.239 104.813 TENS.OIL 3880.000 -999.250 RFFD.FDC -999.250 -999. 250 CALI. FDC -999.250 -999.250 TNPH.CNL -999.250 -999. 250 RCN'T.CNL -999.250 -999.250 GR.CNL -999.250 -999°,250 3. 036 ILM'DIL 3.408 81.625 TENS'OIL 3980.000 -999.25:0 RFFD.FDC -999.250 -999.250 CALl.* FOC -999.250 -999.250 T:NPH.CNL -999.250 -999.250 RCNT.CNL -999.250 -999. 250 GR.CNL -999. -999.250 · 2.571 ILM'OIL 2.489 98.813 TENS.OIL 3734.000 -999.250 RFFD.FDC -999.250 -999.250 CALI..FDC -999.250 -999°250 TNPH.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.25:0 GR.CNL -99 9.25'0 -999.250 3.369 ILM.DIL 3.353 111.875 TENS.OIL 3840.000 -999.250 RFFD.FOC -999.250 -999.250 CALI.FOC -999.250 -999.250 TNPH.CNL -999.250 -'999.250 RCNT.CNL -999.250 -999.250 GR.CNL -999. 250 -999.250 3.154 ILMoDIL 3.100 91. 500 TENS.OIL 3560.000 -999.250 RFFD.FDC -999.250 -999.250 CALI.FOC -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL -999.250 -999. 250 GR.CNL -999.250 -999.250 3.611 ILM. OIL 3.547 120.313 TENS.OIL 3600.000 -999.250 RFFD.FDC -999.250 -999.250 CALI.FOC -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 GR.CNL -999o 250 -999.250 SFLU. OIL RHOB:'FDC RNFD.FDC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL SFLU.OIL RHOSi. FDC RNFO.FDC GR.FDC TNRA..CNL RCFT.CNL T~NS.CNL SFLU.DIL RHOB:. FDC RNFD.FDC GR.FDC TNRA .CNL RCFT.CNL TENS.CNL SFLU.OIL RHDiBoFDC RNFO.FDC GR.FOC TNRA.CNL RCFToCNL TENS.CNL SFLU.OIL RHOB.FDC RNFO. FDC GR.FDC TNRA.CNL RCFT.CNL TENSoCNL SFLU.DIL RHOB. FDC RNFO.FDC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL PAGE: 11 2.469 -999.250 -999.250 -999. 250 -999.250 -999.250 -999. 250 4.765 -999.250 -9'99.25:0 -999.250 -999.250 -999.250 -999.250' 2.102 -999.250 -999.250 -99'9'.250 ,-99:9.250 -999.250 -999.250 3. 240 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.859 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.498 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ~,LASKA COMPUTING CENTER DEPT. 5800.000 ILO.OIL SP. Oil -84. 563 GR.OIL DPH:I.FDC -999.2 50 DRHO. FDC FFDC.FDC -999,250 NFOC. FDC TENS.~DC -999.250 NPHI.CNL RTNR.CNL -999' 250 NPOR.CNL C NT C. C NE -999.250 C F T C. C N L GR.CSG -999.250 TENS.CSG DEPT. 5700.000 ILDoDIL SP. DIL .-84.063 GR.DIL DPHI.FDC -999.250 ORHO'FDC FFDCoFDC -9'99. 250 NFOC.FOC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG -999.250 TENS.CSG DEPT. 5600. 000 ILO' SP. DI~L -83. 875 GR.OIL DPHI.FDC -999.250 DRHO.FDC FFOC.FDC -999.250 NFDC.FDC TENS. FOe -999.250 NPHI.CNL R'TNR.CNL -999,250 NPOR.CNL CNTC.CNL -999.2:50 CFTC.CNL GR.CSG -999.250 TENS.'CSG DEPT. 5500. 000 ILO.OIL SP.OIL -$4. 375 GR.DIL DPHI. FDC -999.250 DRHOoFOC FFDC.FDC -999.250 NFDC.FDC TENS.FOC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG -999.250 TENS.CSG DEPT. 5400.0 O0 ILO. OIL SP.DIL -83.938 GR.DIL DPHI.FDC -999.250 DRHQ.FDC FFDC.FDC -999,250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG -999.250 TENS.CSG DEPT. 5300.000 ILD.DIL SP.DIL -102.125 GR.DIL DPHI.FDC -999.250 DRHD.FDC F~DC.FDC -999.250 NFDC.FOC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999..250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG -999.250 TENS.CSG 17-SEP-1989 12:14 2.760 IL:M.OIL 120.81:3 TENS.DIL -999.250 RFFO.FOC -999.250 CALI.FDC -999.250 TNPH.'CNL -999.250 RCNT.CNL -999.250 GR.CNL -999.250 2. 895 ILM.OIL I01. 563 TENS.OIL -99'9.250 RFFD.FOC -999'~250 CALI.FDC -999.250 TNPH.CNL - '9'99.250 R C NT. C N L -999.250 GR.CNL -999. 250 2. 675 3874.000 -999.250 -999.250 -999.250 -999.250 · -999.250 2. 829 3¢60.000 -999.250 -999.250 -999. 250 -999. 250 .-999.250 3.613 ILM'DIL 3.593 92-938 TENS'OIL 3400.000 -999.250 RFFD.FOC -999.250 -999.250 CALI.FOC .-999.250 -999.250 TNPH.CNL -999.250 -'999. :250 RCNT..CNL -999.250 - 999o 2. 50 GR.C NL -999.250 -999.250 3.477 ILM. DIL 102.125 TENS.DIL -999.250 RFFD.FOC -999. 250 CALI.FOC -999.250 TNPH.CNL -999.250 RCNT.CNL -999.250 GR.CNL -999.250 3.258 ILM.DIL 82.438 TENS.OIL -999.250 RFFD.FDC -999.250 CALIoFDC -999.250 TNPH.CNL -999.250 RCNT.CNL -999.250 GR.CNL -999. 250 3. 382 3420.000 -999.250 -999.250 -999.250 -999.250 -999,.250 3.183 3360.000 -999.250 -999.250 -999.250 -999.250 -999.250 3.055 ILM. DIL 2.995 104. 125 TENS.OIL 3430.000 -999.250 RFFD.FDC -999.250 -999.250 CALI.FDC -999.250 -999,250 TNPH.CNL -999,250 -999.250 RCNT.CNL -999.250 -999. 250 GR.CNL -999. 250 -999.250 SFLU. DIL RHOB.FDC RNFg. FOC GR..FDC TNRA.CNL RCFT.CNL TENS.CNL SFLU. OIL RHOB.FDC RNFO.FOC GR.FDC T NRA o CNL RCFT.CNL T E N S. CNL SFLU.DIL RHOB'FDC R NFO. FD C GR.FDC TNRA.CNL RCFT.CNL T E N S. C NL S FLU. OIL R H 0 B. FO C RNFD.FDC GR. FDC TNRA .CNL RCFT.CNL T E N S. C N L SFLU.DIL RHOBoFDC RNFDoFDC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL SFLU. DIL RHOB.FDC RNFD.FDC GR.FOC TNRA.CNL RCFT.CNL TENS.CNL PAGE: '12 2. 343 -999.250 -999.250 -999. 250 - 999.2:50 -999.250 -999.250 2. 603 -999 '250 -999.250 -999.250 -999.250 -999.250 -999.250 3.603 -999.250 -999-250 -999-250 -999°;250 -999.250 -999.250 3.018' -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.877 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.833 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .IS TAPE YERIFI'CATIDN LISTING ~CHLUMBERGER ALASKA COMPUTING CENTER DEPT. 5200.000 ILO. OIL S P. O I :L - 94- 375 G R. O I L DPHI.FDC -999°250 DRHO.FDC FFDC.FDC -999.250 NFDC.FDC TENS.FDC -999. 250 NPHI.CNL RTNR.CNL -999.250 NF OR.CNL :CNTC..CNL -999.250 CF'TC.CNL GRoCSG -999.250 TENS.CSG DEPT. 5100.000 ILO'OIL SPoOIL -94.063 GR'DIL DPHI.FDC -999.250 DRHO'FDC FFOC.FDC '-999.250 NFDC.FDC TENS.FDC -999. 250 NPHI.CNL R T N R. C N L -999 ' 250 NP OR. C N L CNTC.CNL -999.250, CFTC.CNL GR.CSG -999. 250 TENS.CSG DEPT. 5000.000 ILO.OIl SP. OII -98. 875 GR..OIL DPHI.FDC -999.Z50 ORHO. FOC FFOC.FDC -999.250 NFDC.FOC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG -999.250 TENS.CSG DEPT. 4900.000 iLO.OIL SP. BIL -91.875 GR.DIL DPHI.FDC -999.250 ORHO.FDC FFDC.FDC -999. 250 NFDC.FDC TENS.FDC -999.Z~0 NPHI.CNL RTNR.CNL -999.250 NPOR.,CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG -999.250 TENS.CSG DEPT. 4800. OOO ILO.OIL SP.OIL -94.375 GR.DIL DPHI.FDC -999.250 ORHO.FDC FFDC.FDC -999.250 NFDC.FOC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR. CSG -999.250 TENS.CSG DEPT. 4700.000 ILO.OIL SP. DIL -111.625 GR.DIL DPHI. FDC -999.2 50 DRHC. FDC FFDC.FDC -999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG -999.250 TENS.CSG 17-SEP-1989 12:14 3.235 ILM..DIL 107.625 TENS.OIL -999.250 RFFD.FOC -999. IS0 CALI.FDC -999.250 TNPH.CNL -999. 250 RCNT.CNL -999. 250 GR-CNL -9 9 9.25 0 3. :537 ILM.OIL 118.938 TENS'DIL -999.250 RFFD.FDC -999.250 CALI.FDC -999.250 TNPH.CNL -999.250 RCNT.CNL -999.250 GR.CNL -999. 250 4.049 ILM.DIL 118.063 TENS.OIL -999.250 RFFD.FDC -999.250 CALI.:FOC -999.250 TNPH.CNL - 999.250 R:C NT. C NL -999.250 GR.CNL -999. ZSO 3.165 3184.000 -999.250 -999.250 -999.250 -999.250 - 99 9.25,0 3. 363 3330.000 -999. 250 -999. 250 -999.250 -999' 250 -99 g. 250 3.983 3140.000 -9'99.250 -999.250 - 999:. 250 -999.2.50 -999.250 3.~77 ILM.DIL 3.772 85.375 TENS.OIL 3154.000 -999.250 RFFD.FDC -999.Z50 -999.Z50 CALI.FOC -999.250 -999.250 TNP;H. CNL -999.250 -999,,,250 RCNT.CNL --999.250 -999. 250 GR. CNL -999. Z50 -999. 250 4.084 ILM.DIL 3.865 107.063 TENS.OIL 3064.000 -999.250 RFFD.FDC -999.250 -999.Z50 CALI.FDC -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 GR.CNL -999.250 -999.250 2.825 ILM.DIL 2.693 99. 813 TENS.OIL 3010.000 -999.Z50 RFFD.FOC -999.250 -999.250 CALI.FDC -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL -999. Z50 -999.Z50 GR.CNL -999.2.50 -999.Z50 SFLU.DIL RHOB. FDC RNFD. FOC GRoFDC TNRA.CNL RCFT.CNL TENS.CNL S FL U. O I L RH05. PDC RNFO. FDC GR. FDC TNRA.CNL RCFT.CNL TENS. CN:L SFLU. OIL RHOB. FDC RNFD' FDC GR.FDC TNRA.CNL RCFT. CN:L TENS .CNL SFLU. DIL RNFD.FOC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL SFLU. DIL RHOB. FDC RNFD. FDC GR.FDC TNR~.CNL RCFT.CNL TENS.CNL SFLU.OIL RHOB.FDC RNFD. FDC GR.FDC TNRA.CNL RCFToCNL TENS.CNL PAGE: :13 2.916 -999.290 -999.250 -999.250 -999.250 -999.250 -999.2.50 3.39¢ -999.25~0 -999-250 -999.250 -999.250 -999.250 -999.250 3.949 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.869 -999.250 -999.250 -999.250 -999'250 -999'250 -999.250 3.592 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.293 -999.250 -999.250 -999.250 -999.250 -999.250 -9g9.250 LIS TAPE VER:IF!CATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER DEPT. SP.. OIL DPHI-FDC FFDC.FDC TENS. FDC RTNR. CNL C N T C. C N L GR,CSG DEPT. SP. DIL OPHI.FDC FFDC.F'DC TEN S. FDC E T N R. C N L CNTC.CNL GR,.CSG DEPT. SP,.DIL DP'HI. FDC FFDC.FDC TENS. FDC RTNR-CNL C NTC. CNL GR,CSG DEPT. SP. DIL DPHI.FDC FFDC.FOC TENS.FOC RTNR. CNL CNTC.CNL GR,CSS DEPT.. SP.OIL DPHI.FDC FFDC.FDC TENS.FDC RTNR.CNL CNTC.CNL GR.CSG DEPT. SP.DIL DPHI.FDC FFDC.FDC TENS.FDC RTNR.CNL CNTC.CNL GR.CSG 4600.000 ILO.OIL -100.8751 GR.OIL -999.250 ORHO.FOC -999.250 NFDC.FDC -999. 250 NPHI.. CNL '-999'250 NPOR.CNL - 999.250 C F T :C. C N L -999.250 TENS.CSG ~500.000 ILO. OIL -102.500 GR.DIL -999. 250 DRHD. FDC -999. :250 NFDC..FDC -999.250 NPHI.CNL -999.2 50 NPgR.CNL -999,250 CFTC.CNL -999.250 TENS°CSG 4400.0 O0 ILO.OIL -99.813 GR.DIL -999.250 DRHO.FDC -999.250 NFOC.FDC -999.250 NPHi.CNL -999.2S0 NPOR.CNL -999.2S0 CFTC.CNL -999.250 'TENS.CSG 4300.000 ILO.OIL -I00.625 GR.DIL -999.2 50 DRHO. FDC -999. 250 NFOC. FDC -999.250 NPHI.CNL -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 TENS.CSG 4200.000 ILO.OIL · -96.938 GR.DIL -999.250 DRHO.FOC -999.250 NFDC.FDC -999.250 NPHI.CNL -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 TENS.CSG ~100.000 ILD.DIL -105.500 GR.DIL -999.250 DRHO.FDC -999.250 NFDC.FDC -999. 250 NPHI.CNL -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 TENS.CSG 17-SEP-1989 12.' 14 3.434 ILM'DIL 3-228 101.500 TENS.OIL 3660.000 -999'250 RFFD. FDC -999.250 -999.250 CALI.FOC -999.250 -999. 250 TNPH.CNL -999.250 -999. Z50 RCNToCNL -999.250 -999.250 GR.CNL -999.250 -999.250 4.051 ILM. DIL 105.438 TENS.DIL -999.250 RFFD. FDC -999. 250 CALI.FDC -999.250 TNPHoCNL - 999.250 RC NT. C NL -999.250 GR,CNL -999.250 3.062 IL:M. 95.43,8 TENS'OiL -999.250 RFFD. FOC -999.250 CALI.FDC -999.250 TNPH. CNL -999. 250 RCNT.CNL -999.250 GR.CNL '-999..250 · 3.788 354 O. 000 -999.250 -999.250 -999.250 - 999- 250 -999.250 2.87~ 34! O. O00 - 99 9.250 -999.250 -999.250 -999.250 -999.250 5.630 ILM.OIL 6.052 47.250 TENS.DIL 3824.000 -99'9. 250 RFFD.FDC -999.250 -999.250 CALI.FDC -999.250 -999.250 TNPH.CNL -999,250 -999.250 RCNT.CNL -999.250 -999.250 GR.CNL -999.250 -999.250 3.¢63 ILM.DIL 105.500 TENS.OIL -999.250 RFFD.FDC -999.250 CALI.FDC -999.250 TNPH. CNL -999. 250 RCNT.C NL -999.250 GR.CNL -999.250 3.089 369~.000 -999.250 -999.250 -999.250 -999.250 -999.250 4.853 ILM.OIL 4.590 93.68B TENS.OIL 3390.000 -999.250 RFFD.FDC -999.250 -999.250 CALI.FOC -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL -999.250 -999. 250 GR.CNL -999.250 -999.250 SFLU.DIL RHO3'FDC RNFD.FDC GR. FDC T N R A. C N L RCFT.CNL TENS.CNL SFLU.DIL RH05, FDC RNFD. :FDC GR. FDC TNRA.CNL R CF T- CNL T E NS. CNL SFLU. OIL RHOB. FDC R N F O. FD C GR.FDC TNRA.CNL RCFT. CNL T E NS. C NL SFLU.DIL RHOB'FBC RNFD.FDC GR.FDC TNRA.CNL RCFT.CNL TENS .CNL SFLU.DIL RHOB.FDC RNFOo FDC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL SFLU.DIL RHOB.FDC RNFD. FDC GR.FDC TNR~.CNL RCFT.CNL TENS.CNL PAGE: 2.916 -999.250 -999.250 -999..250 -999.250 -999.250 -999.250 3.363 -999'250 -999.250 -999.250 -999.25:0 -999.250 -999.250 2. 353 -999-250 -999. 250 -999.250 -999-250 -999' 250 -999.250 90.945 -999.250 -999-250 -999.250 -999.250 -999.250 -999.250 2.712 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ~.201 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS 'TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER DEPT. 4000.000 ILO.OIL SP. DIt -105.625 GR.OII DPHI.FDC -999.250 ORHO'FDC FFDC.FDC -999.2.50 NFOC.FOC TENS.FDC -999.250 NPHi.CNL RTNR. CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTCoCNL GR.. CSG -999. 250 TENS.CSG DEPT. 3900..000 ILO.OIL SP. OII -103.625 GR.DII DPHI.FDC -999.250 DRHO.FDC FFDC. FDC -999. 250 NFDC.FDC TENSoFDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNI. -999.250 CFTC.CNL GR.CSG -999..250 TENSoCSG DEPT. 3800.000 SP.DII. -I04.625 DPHI. FDC -999.250 FFDC.FDC -999.250 TENS. FDC -999. 250 ETNR. CNL -999' 250 CNTC.CNL -999. 250 GR.CSG 96.750 DEPT. 3700-000 SP.DIL -76.000 DPHI.FOC -999.250 FFOC. FDC -999. 250 TENS.FDC -999.250 RTNR.CNL -999.2 50 CNTC.CNL -999. 250 GR.CSG 65.063 DEPT. 3600.000 SP. DIL -9 9=9.250 DPHI.FDC -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 RTNR.CNL -999.250 CNTC.CNL -999.250 GRoCSG 50.781 ILD. OIL GR. OIL OR HO. FDC NFOC.FOC NPHI.CNL NP 0 R. C NL C F T C. :C NL TENS.CSG ILD. OIL GR.DIL DRHO.FDC NFOC.FOC NPHI.CNL NPOR.CNL CFTC.CNL TENS.CSG ILD.DIL GR.DIL DRHO.FDC NFDC.FDC NPHI.CNL NPOR.CNL CFTC.CNL TENS.CSG DEPT. 3500.000 ILD.DIL SP. OIL -999.250 GR.DIL DPHI.FOC -999.250 DRMO.FDC FFDC.FDC -999.250 NFOC.FOC TENS.~DC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.2.50 CFTC.CNL GR.CSG 69.750 TENS.CSG I7.-SEP-19:89 12:14 4.560 ILM. DIL 4. 176 95.813 TENS.DIL )300.000 -999.250 RFFD.FDC -999.250 -999.250 CALI.FDC -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT'CNL -999.250 - 999.250 GR.C N'L -999.2'50 -999.250 4.024 ILM.DIL 96.000 TENS'DI;L -999.250 RFFD.FOC ,-999.250 CALI.FOC - 9 '99 o 250 T N P H. C N L -999. ,250 'i RCNT.CNL - 999.250 G R. C NL -999.250 3. 692 365 O. 000 -999. 250 -999.250 -999.250 - 999. 250 -999.250 5.500 ILM.OIL ~o893 98.625 ~TENS'DIL 3.834.000 -999.250 RFFD.FDC -999.250 -999.250 CALI.FDC -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL -999'250 - 999. 250 GR.iC NL - 99 9. 250 3440. 000 10.663 ILM. DIL 2000.000 59.188 TENS.DIL 331-¢. 000 -999.250 RFFD.FDC -999.250 -999.250 CALI.FOC -999.250 -999.250 TNPH.CNL -999.250 -999... 250 RCNT.CNL -999.250 -999.250 GR.CNL -999.250 2364.000 -999,.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 RFFD.FDC -999.250 -999.250 CALI.FOC -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 GR.CNL -999.250 2154.000 -999.250 ILM. DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 RFFD.FDC -999.250 -999.250 CALI.FDC -999.250 -999.250 'TNPH. CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 GR.CNL -999.250 2220.000 S FL U. OIL RH08. FDC RNFO' FDC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL SFLU. DIL RHOB.FOC RNFO. FOC GR.FOC TNRA.CNL RCFT.CNL T E N S. C N L SFLU.DIL RHOB.FDC RNFD.FDC GR.FDC TNRA-CNL RCFT.CNL TENS.CNL SFLU.DIL RHOB.FDC RNFD. FDC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL SFLU.DIL RHOS. FDC RNFD. FDC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL SFLU.DIL RHOB.FDC RNFD.FDC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL .PAGE: 15 3.560 -999.250 -999'250 -999.250 -999..250 -999.250 -'999-250 3.590 -999.250 -999.250 -999-250 -999.250 -999.250 -'999.250 4.450 -999.250 -999-250 -~999.250 -999.250 -999.250 -999.250 10 o 39O -999.2 50 -9'99. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS TAPE VERIFICATION LISTING SCHLUMBERGER aLASK~ COMPUTING CENTER DEPT. i 3400.000 ILO.OIL SP. OIL -999.2 50 OR.OIL DPflI.FDC -999.250 DRHD.FDC FFDC.FDC -999..250 NFDC.FDC TENSoFDC -999.250 NPHI.CNL RTNR.CNL -999.250 N:POR..CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG 58.78! TENS.CSG DEPT. 3300.000 ILO.OIL SP. OIl ,-999.250 GR.DI1 DPHI. FDC -999.250 DRHO.FOC FFOC.FDC -999.250 NFOC.FDC TENS.. FOC -999. 250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR. CSG 62.8/,6 TENS.CSG DEPT. 3200. 000 ILO.OIL SP.OIL -999.2 50 GR.OIL DPHI.FDC -999.250 DRHO'FDC FFOC.FDC -999.250 NFDC.FOC TENS.FDC -999. 250 NPHI.CNL R'TNR.CNL -999.250 NPOR.CNL CNTC.:CNL -999. 250 CFITC. CNL GR.CSG ~6.000 TF. NS.CSG DEPT. 3100.000 ILO.OIL SP. OIl. -999.2 50 GR.DIL DPHI.FDC -999.250 DRHO. FOC FFDC.FDC -999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTCoCNL -999.250 CFTC.CNL GR.CSG $3.'18B TENS.CSG DEPT. 3000. 000 ILO.OIL SP. DIL -999.250 GR.DIL DPHI.FDC -999.250 DRHO.FDC FFDCoFDC -999. 250 NFDC. FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG 59.969 TENS.CSG DEPTo 2900.000 ILD.DIL SP. OIL -999.250 GR.DIL DPHI.FDC -999.250 DRHO. FOC FFDCoFDC -999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG 53.656 TEN'S.CSG 17-SEP-1989 12:1~ '-999.250 ILM.OIL -999.250 -999.250 TENS.OIL -999.2'50 -999.250 RFFD.FOC -999.250 -999.250 CALI.FOC -999.250 -999.250 TNPHoCNL '-999.250 -999.250 RCN'T.CNL -999°250 -999.250 GR.CNL -999.250 2274.000 -999.250 ILM'DIL -999.250 --999.250 TENS.DIL --999.250 -999.250 RFFD.FDC -999'250 -999.250 CALI.FO'C -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 GRoCNL -999.250 2204.000 -999.250 ILM.OIL -999.250 -999.250 TENS-OIL -999.250 -999.250 RFFD.FOC -999.250 -999. 250 CALI.FOC -999. 250 -999°250 TNPH.CNL -999.250 -999. 250 RCNT.CNL -999.250 -999.250 GR.CNL -999.250 2050' 000 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 RF~O. FOC -999.250 -999.250 CALI.FOC -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL .-999.250 -999. 250 GR.CNL -999.250 2064.000 -999.250 ILM.DIL -999.250 -999°250 TENS.DIL -999.250 -999.250 RFFO. FDC -999.250 -999.250 CALI.FDC -999.250 -999.250 ?NPH.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 GR.CNL -999.250 2005.000 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 RFFD. FDC -999.250 -999.250 CaLI.FO£ -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 GR.CNL -999.250 2054.000 SFLU'DIL RHOB..FDC RNFO.'FDC GR.FDC TNRA.CNL iRCFT.CNL TENSoCNL SFLU.DIL RHOS.FOC RNFO.oFDC GR.FOC TNRAoCNL RCFT.CNL TENS.CNL SFLU. OIL RHO~.FDC RNFO. FDC GR.FOC TNRA..CNL RCFT..CNL TENS.CNL S~LU.DIL RHOO.FDC RNFD.FDC GR. FDC TNRA.CNL RCFT. CNL TENS.CNL SFLU.DIL RHOB.FDC RNFD. FDC GR.FDC TNRa.CNL RCFT.CNL TENS.CNL SFLU.DIL RHOB. FDC RNFD. FDC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL PAGE: 16 -999.250 -999.250 -999.250 -999.250 -9 g 9.250 -999.2,50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2'50 -999.250 -999.250 -999.250 -999. 250 -999.250 -999'250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER DEPT. 2800. 000 ILO. OIL SP.DII -999.Z50 GR.DIL DPHI.FDC -999. 250 ORHO. FDC FFDC.FOC -999.25.0 NFDC.FOC TENS.FDC -999.250 NPHI.CNL RTNR. CNL -999. 250 NPOR.CNL CNTC. CNL -999.2:50 CFTC.CNL GR.CSG 66.063 TENS.CSG DEPT. 2700' 000 ILO. OIL SP.OIL -999. Z50 GR.DIL DPHI.FDC -999.250 DRHO. FDC FFDC.FDC -999.250 NFDC.FOC TENS.FDC -999.250 NPHI.CNL RTNR. CNL -999 ZSO NPOR.CNL CNTC.CNL -999. 250 CFTCoCNL GR.CSG 42.219 TENS.CSG DEPT.. 2600.000 ILO.OIL SP.DIL -999. 250 OR.OIL DPHI. FDC -999.250 DRHf~.FDC FFDC.FDC -999.250 NFDC.FDC TENS. FDC -999.250 NPH~.CNL R'TNR.CNL -999. ~5.'0 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG 4~.594 'TENS.CSG DEPT. 2500. 000 ILO.OIL SP. OIL -999. 250 G'R. OIL DPHI.FDC -999.250 DRHO.FOC FFOC.FDC -999.250 NFDC.FOC TENS.FDC -999.Z50 NPHI.CNL RTNR.CNL -9'99.250 NPDR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG 56.781 TENS.CSG DEPT. 2400.000 ILO.OIL SP.DIL -9 99.250 GR. OIL DPHI.FDC -999.250 DRHO.FDC FFDC.FDC -999.250 NFOC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GRoCSG 50.625 TENS.CSG DEPT. Z300.O00 ILD.~IL SP.DIL -999.250 GE.OIL DPHI.FDC -999.250 DRHO.FDC FFDC.FDC -999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG 44.469 TENS.CSG 17-SEP-1989 12:14 -999. Z50 ILM.DI:L -999.250 TENS.'DIL -999"-250 RFFD.FOC -999.Z50 CAL'I.FDC -999.250 TNPH.CNL -999.250 RCNT.CNL -999.Z50 GR.CNiL 1895.000 -999.250 -999.250 - 999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 ILM.OIL -999.250 -999.250 TENS.OIL -999.250 -999.Z50 RFFD.. FOC -999.Z50 - 999 :. 25 O C A'L I. F D C - 999.250 -999.250 TNPH. CNL -999.250 -999.250 RCNT. CNL -999.250 -999.Z50 GR.CNL -999.250 .1895. 000 -999.250 ILM.OIL -999"-250 -999.250 'TENS.OIL -999.250 -999.250 RFFD.FDC -999. Z50 -999'250 CALI.FDC -~'~99. ~50 TNPH. CNL -999.Z 50 -999.250 RCNT.CNL -999.250 -999. 250 GR.CNL -999.250 :1.905.000 -999.250 ILM.DIL -999"-250 TENS.OIL -999.250 RFFD,.FDC -999.250 CALI.FDC -999..250 TNPH.~CNL -999.250 RCNT.CNL -999. 250 GR.CNL 1785.000 -999.250 -999.250 -999'250 -999.250 -999.250 -999.250 -999.250 -999.Z50 ILM.DIL -999.250 -999.Z50 TENS.OIL -999.250 -999.250 RFFD.FDC -999.250 -999. Z50 CALI.FDC -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL -999.,250 -999. Z50 GR.CNL -999. 250 1745.000 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 RFFD.FDC -999.250 -999.250 CALI.FOC -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL -999.Z50 - ~99. ZSO GR.CNL -99 9. 250 1790.000 SFLU.DI:L RHOB' FDC RNFD. FDC GR. FDC TNRA.CNL RCFT.CNL TENS.CNL SF:LU.OIL RHOS.FDC RNFD.FDC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL SFLU.DIL RH08. FOC RNFO. FDC G~.. FDC TNRA.CNL R CF T. CNL TENS.CNL SFLU. OIL RHOB.FDC R NFO.. FD C GR.FDC TNRA.CNL RCFT.CNL TENS.CNL SFLU.DIL RHOB.FDC RNFD. FDC GR.FOC TNRA.CNL RCFT.CNL TENS.CNL SFLU.DIL RHOB.FDC RNFD.FDC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL PAGE: 17 -999.250 -999'250 -999'250 -999.250 - 999 - g S 0 -999.250 -999.250 -999-250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999'250 -999.Z50 -999.250 -999.250 -99'9.250 -999.250 -999.250 -999.250 -999.250 -999.25~0 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -gggo250 -ggg.250 LIS TAPE VERIFICATION I. ISTING SCMLUMBERGER ALASK-A COMPUTING CENTER DEPT. 2200. 000 ILD.OIL SP.DIL -999. 250 GR.DIL DPHI. FDC -999.250 DRHO.FDC FFDC.FDC -ggg..ZEO NFDC.FDC TENS-FDC -99'9.250 NPHI.CNL RTNR. CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CF'TC.CNL · GR.CSG 28.797 TENS.CSG DEPT. 2100. 000 ILO.OIL. SP. DII -999.250 GR.DIL DPHI.FDC -999.250 ORHO.FDC F F O C,o F D C - 9 g 9 . Z 50 N F DC. F 0 C TENS.FDC -999.250 N:PHZ.CNL RTNR. CNL -999.25.0 NPOR.CNL CNTC.CNL -999-250 CFTC.CNL GR.CSG 37. 969 TENS.CSG DEPT. 2000. 000 ILO. OIL SP.DIL -999. 250 GR. OIL DPHI,' FDC -999.250 DRHOoFDC FFDC.FDC -999.250 NFDC.FDC TENS.FDC -999. 250 NPHI.. CNL RTNR. CNL -999.250 NPOR'CNL CNTC. CNL -999.250 CF'TC.CNL GR.CSG 47.78[ TENS.CSG DEPT. lgO0. 000 ILO.OIL SP.DIL -999. 250 GR.DIL DPHI. FDC -999.250 ORHO.FOC FFOC.FDC -999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPORoCNL CNTC.CNL -999.250 CFTC.CNL GR.CSG 34.750 TENS.CSG DEPT. 1800.000 ILO.OIL SP.DIL -ggg.zEO GR.DIL DPHI.FDC -999.250 DRHO.FDC FFDC.FDC -999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPDR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG 56.625 TENS.CSG DEPT. 1700.000 ILO.OIL SP.DIL -999.250 GR.DIL DPHI.FDC -999.250 DRHO.FDC FFDC.FDC -999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG 35.813 TENS.CSG '17-SEP-1989 12:14 999. 250 ILM.OIL 999.250 TENS.OIL 999. 250 RFFD.FDC 999. Z50 C,~ lI. FDC 999.250 TNPH.CNL 999.250 RCNT.CNL 999. 250 GR.CNL 660.000 -999.250 -999.250 -9'99.250 -999.250 -999.250 -999.250 -999.250 999.250 ILM. DIL -999.,250 999.250 TENS.DIL -999.250 999.250 RFFD.FDC -999.250 999.250 CALI.FDC -999.250 999,.250 TNPH.CNL -999.250 999.250 RCNT.CNL -999.250 999. 250 GR.CNL -999.;~50 999.250 ILM. DIt -999.250 999. 250 TENS.OIL -999.250 999.250 RFFD.FDC -999o250 999. 250 CALI.FOC -999.250 999o 250 TNPH.CNL -999.250 999.250 RCNT'CNL -999.250 999. 250 .GR.CNL -999..250 670.000 ~99.250 ILM.OIL -999.250 999.250 TENS.OIL -999.250 999. 250 RFFD.FDC -999.250 999. 250 CALI.FDC -ggg. 250 999.250 T~NPH.CNL -999.250 999.250 RCNT.CNL -999.250 999. 250 GR.CNL -999.250 720.000 999.250 ILM.DIL -999.250 999.250 TENS.OIL -999.250 999.250 RFFD.FDC -999.250 999.250 CALI.FDC -999.250 999.250 TNPH. CNL -999.250 999.250 RCNT.CNL -999.250 999. 250 GR.CNL -999.250 650.000 999.250 ILM.DIL -999.250 ggg.zEO TENS.OIL -999.250 999.250 RFFD.FDC -999.250 999.250 CALI.FDC -999.250 999.250 TN~H.CNL -999.250 999.250 RCNT.CNL -999.250 999. 250 GR. CNL --999o 250 550.000 SFLU.DIL RHOB.FDC RNFD.FDC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL SFLU.DIL RHOB.FDC RNFD. FDC G R. FDC 'TNRA:.CNL RCFT. CNL TENS- CNL SFLU.DIL RHO~.FDC RNFD. FDC GR' FDC TNRA.CNL RCFT.CNL TENS. CNL SFLU..DIL RHOB.FDC R,NFD. FOC GR. FDC TNRA .CNL RCFT.CNL TENS.CNL SFLU.DIL RHOB. FDC RNFO.FDC GR. FDC TNRA.CNL RCFT.CNL TENS.CNL SFLU.DIL RHOB.FDC RNFD.FDC GR.FDC TNRA.CNL RCFT.CNL TENS.CNL PAGE: 18 -999.250 -999.250 -999.250 -999.250' -999.250 -999'250 -999.250 -999.250 -999.250 -999'250 -999.250 -999.250 -999.250 -999'250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -g99.250 LIS TAPE VERIFICATION LISTING :SCHLUMBERGER ALASKA COMPUTING CENTER O E P T. 1600.000 ! :L D. O Z L SP'OIL -999. 250 §R. DIL DPHI.FDC -999.250 DRHO. FDC FFOC.FDC -999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG 2.9.89I TENSoCSG D'EPT. 1,500. 000 ILO.OIL SP.DIL -999.250 GE.OIL DPHI.FDC -999.250 DRHO.FDC FFDC.FDC -999.250 NFDC.FDC TENS. FDC --999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG 37.406 TENS.CSG DEPT. 1400.000 ILO' OIL SP.OIL -999. 250 GR.DIL DPHI.FDC -999.250 DRHO, FOC FFDC.FDC -999.250 NFDC. FDC TENS.FDC -9'99.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG 4'1.125 TENS.CSG DEPT. 1300.000 ILO.OIL SP.DIL -999.250 GR.DIL DPHI.FDC -999'250 DRHO.FOC FFDC.FDC -999.250 NFOC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG 29.422 TENS.CSG DEPT. 1200. 000 ILO.OIL SP.OIL -999. 250 GR. OIL DPHI.FDC -999.250 DRHO.FDC FFDC.FOC -999.Z50 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG 21.B59 TENS.CSG DEPT. 1100.000 ILO.OIL SP.DIL -999.250 GR.DIL DPHI.FDC -999.250 DRHO.FDC FFDC.FDC -999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG 33.656 TENS.CSG 17-SEP-!gBg 12:1¢ -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 RFFD. FDC -999.250 -999.250 CALI,'FDC -999.250 - 99 g. 250 T N P H. C N'L - 99 9. Z 50 '-999. 250 RCNT.CNL -999.250 -999.250 GR.CNL -999.250 16BO. O00 -999.250 ILM'DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 RFFD. FDC -999.250 -999.250 CALI.FDC --999.250 -99g.250 T'NPH.CNL -999.250 -999.250 RCNT.CNL -999.250 '-999. 250 GR. CNL -999.250 1520.000 -999.250 ILM'DIL -999.250 TENS.OIL -999.250 RFFD.FDC -999.250 CALI.FOC -999.250 TNPH. CNL -999.250 RCNT.CNL -999. 250 GR.CNL 1545.000 -999.250 -99 9. 250 -999.250 -999.250 -999. -999'250 ILM, DIL -999.250 -999..250 TENS.OIL -999.250 -999. 250 RFFD.FOC -999.250 -999.250 CALI.FOC -999..250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL -999.250 -999. 250 GR.CNL -999.250 1~55o000 -999°250 ILM. DIL -999.250 -999.250 TENS.OIL -999.250 -999°250 RFFD.FDC -999°250 -999.250 CALI.FDC -999.250 -999.250 TNPH.CNI -999.250 -999.250 RCNT.CNL --999.250 -999. 250 GR.CNL -99 9. 250 1410.000 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999. 250 RFFD.FDC -999.250 -999.250 CALI.FOC -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCNT.CNL -999.250 -999. 250 GR.CNL -999. 250 lz~O0. 000 S FL U- OIL RHO).FDC RNFO. FDC GR. FDC T NRA o CNL RCFT.CNL TENS. CNL SFLU. DIL RH:B. FDC RNFD.FDC GR. FDC T NRA.. C NL RCFT. CNL TENS.CNL SFLU. DIL RHDSoFDC RNFO. FDC GR.FOC TNRAoCNL RCFT.CNL TENS.CNL SFLU. DIL RHOB.FDC RNFD.FDC GR.FDC TNRAoCNL RCFT.CNL TENS.CNL SFLU.OIL RHOB.FOC RNFD.FOC GR.FOC TNRA.CNL RCFT.CNL TENS.CNL SFLU.DIL RHOB.FDC RNFD.FDC GR.FOC TNRA.CNL RCFT.CNL TENS.CNL PAGE: -9'99.250 -ggg. 250 -999. 250 --999.2 50 -999.250 -999.250 -999.250 -999.250 -;999.250 -:999.250 -999.250 -999-250 -999.250 -999.250 -'999.250 -999.250 -999-250 -99'9.250 -999.250 -99'9.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS TAPE YERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER DEPTo ! 000.000 ILO.OIL SP. OIL -999.250 GR. OIL DPHI.FDC -999. 250 DRHO. FDC FFDC.FDC -999.~250 NFDC' FDC TENS.FDC -999.250 NPHI.CNL RTNR.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG 41.719 TENS'C. SG DEPT. 900. 000 ILO.OIL SP. OI1 -999.250 GR.OIL DPHI.FOC -999-250 ORHO.FDC FFDC.FDC -99'9. ZSO NFDC'FDC TENS.FDC -999.250 NPHi.CNL R'TNR.CNL -999.250 NPOR. CNL CNTC.CNL -999.250 CFTC.CNL GR.CSG ¢7.469 TENS.CSG DEPT. 859.500 ILO.OIL SP- Oil -999.250 GR..OIL DPHI. FOC -9'99. 250 DRHO.FDC FFDC.FDC -99'9.250 NFOC.FDC TENS. FDC -999.2$0 NPHI.CNL RTNR:.CNL -999.250 NPOR.CNL CNTC.CNL -999.Z50 CFTC.CNL GR'.CSG 35.844 TENS.CSG ENO OF DATA :t,*** F I1 E FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER :¢*** : EDIT .001 : FLIC : 001A02 : 89/09/17 : LO **** FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE HEADER ,:1:** : EDIT .002 : FLIC : 001A02 : 89/09/17 : lOZ¢ : LO 17-SEP-1989 12:14 -999.250 ILM.DIL -999.250 -'99'9. 250 TENS.OIL -999..250 -999.:250 RFFO.FDC -'399. 250 -999. :Z50 CALI.FOC -999°250 -999. 250 TNPH.CNL -999. Z50 -999.250 RCNT.CNL -999.250 -999.250 GR.CNL -999.250 1200.000 -999.250 ILM,DIL -999.250 -999.250 TENSoDIL -999.250 -999.250 ~RFF'DoFDC -999.250 -999.250 CALI.FDC --999.250 -999.250 TNPH.CNL -999.250 - 999. Z 50 R:C N T. C NL - 99 9. ;Z 50 - 999.250 G R. C N L - 999.250 1200.000 -999.250 ILM.DIL -999.250 -999. 250 TENS.OIL -999..Z50 -999.250 RFFD. FDC -999.250 -999.250 CALI.FOC -999..Z50 -999. ,250 TNPH.CNL --999. 250 '-999-250 RCNToCNL -999.250 -999. 250 GR.CNL -999. 250 1205.000 S FLU. gI L RHOB.FDC RNFD. FDC GR. FDC T NRA. CNL R CF T. CNL TENS. CNL S F L U. D ! L RHOB. FDC RNFD. FDC GR.. FDC T NRA. CNL R C F T. CNL TENSoCNL SFLU.DI~L RHOS. FDC RNFO.FDC GR.FDC TNRA.CNL iRCFT.CNL TENS.CNL PAGE: 20 -999.250 -999.250 -9:99.250 999.250 -999.250 -999.250: -999.250 -'999' 250 -999. 250 ,-999.2!50 -999.2:50 -9 99 ,. 250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 LIS TAPE VER,~FICA'TION LISTING SCHLUMBERGER ALASKA :COMPUTING CENTER 17-SEP-1989 12:14 PAGE: ¸21 FILE - EDIToO02 ARCO ALASKA INC. KUPARUK 50-103-20111-00 "HI RESOLUTION REPEAT PASS ~1" DATA SAMPLED EVERY -.1000 FEET DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME FDC .FOH CNT-A/O/H .CNH FORMATION DENSITY COMPENSATED NEUTRON TABLE T'YPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. COMPANY NAME FN KUPARUK , FIELD NAME WN 2K - B WELL NAME APIN 50-103-20111-00 API SERIAL NUMBER FL lZ1~ FSL ~ g4~ ~EL FIELD LOCATION SECT 2 SECTION TOWN '10N TOWNSHIP RANG BE RANGE COUN N rJ.R TH SLOPE COUNTY STAT ALASKA STATE OR P~OVINCE NATI USA NATION ENG! FRITZKE/SCHWARTZ ENGINEER~S NAME WITN RDBERTSON/BOND/DEREK WITNESS~s NAME SON 73460 SERVICE ORDER NUMBER PDAT MSL PERMANENT DATUM EPD FT 0. LMF RKB LOG MEASURED FROM APO FT 154. EKB FT 154. EOF FT 153. EEL FT 1 13 TOD FT LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASK-A COMPUTING CENTER 17-SEP-19B9 12:14 ~TABLE TYPE : C=URV DEFI DEPT DEPTH CHANNEL NAME RHOB BULK DENSITY DPMI DENSITY POROSITY DRHO DELTA ~HO RFFO RAW FAR FDC COUNT RATE RNFD RAW NEAR FDC =COUNT RATE FFDC FAR FDC COUNT RATE NFDC NEAR FDC C. OUNT RATE C:~LI CALIPER GR GAMMA RAY TENS TENSION NPHI NEUTRON POROSITY TNPH THERMAL NEUTRON POROSITY TNR~ CALISR~TED THERMAL NEUTRON RATIO RTNR NPOR RCNT RCFT 'CNTC CFTC TENS RAW THERMAL NEUTRON RATIO NEUTRON POROSITY OUTPUT FROM AN APPLICATION PROGRAM RAW CORRECTED NEAR THERMRL COUNTS RAW CORRECTED FAR THERMAL COUNTS CORRECTED NEAR THERMAL COUNTS CORRECTED FAR THERMAL CaUNTS GAMMA RAY TENSION PAGE: 22 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB *~ TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 B 68 o.ogg 9 65 FT 11 66 11 1Z 68 13 66 0 14 65 .CT 15 ,66 68 16 66 1 0 66 I LIS 'TAr~E YERIF!C6TION LISTING SCHLUMBERGER aLASKA COMPUTING CENTER t7-SEP-1989 12:14 PAGE: 23 · , SET TYPE - CHAN ,~ NAME SERV UNIT SERVICE API API API API FILE N IO' ORDER # LOG TYPE CLASS MOO NUMB: S DEPT FT RHOB FDH G/C3 DPHI FDH PU DRHO FOH G/C3 RFFO FDH CPS RNFO FDH CPS FFDC FOH CPS NFDC FOH CPS CALI FOH IN GR FDH GAPI TENS FDM L8 NPHI CNH PU TNPH CNM PU TNRA CNM RTNR CNH NPOR CNM PU RCNT CNH CPS RCFT CNH CPS CNTC CNH C PS CFTC CNM CPS GR CNH GAPI TENS CNH LB · .,.,,,..,,, o,.m, oD m,,,..,, e,,m, .,.... ,,.~ -,~ ..,.., ~,....m UMB NUMB SIZE REPR PROCESS AMP ELEM CODE (HEX) 548366 O0 000 O0 0 Z t 548366 O0 000 O0 0 2 1 548366 O0 000 '00 0 Z 1 548366 O0 000 O0 0 2 t 548366 O0 000 O0 0 2 1 548366 O0 000 O0 0 2 1 548966 O0 000 O0 0 2 548366 O0 DO0 O0 0 2 l 548366 O0 000 O0 0 2 1 548366 O0 DO0 O0 0 2 1 548366 O0 000 O0 0 2 1 548366 ~00 000 00 0 2 1 548366 O0 000 O0 0 2 548366 O0 000 O0 0 Z I 548366 O0 000 O0 0 2 1 5483 66 00 000 00 0 2 1 548'3.66 O0 000 O0 0 2 1 548366 O0 000 O0 0 2 1 548356 O0 000 O0 0 2 1 548366 O0 000 00 0 2 1 548366 O0 000 O0 0 2 1 548366 O0 000 O0 0 2 1 1 4 68 O000000OO0 1 4 68 0000000000 1 4 68 0000000000 1 4 68 00000:00000 1 4 68 0000000000 1 4 68 000000000:0 1 4 68 0000000000 1 4 68 0000000'00:0 I 4 68 O00000000O I 4 68 0000000:000 I 4 68 O~OO:O000000 I 4 68 O00000OO00 I 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 I 4 68 000:0000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 '0000000000 I 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 ** O A'T A ** DEPT. RFFDoFDH CALI.FDH TNPH.CNH RCNT.CNH GR.CNH DEPT. RFFD.FDH CALI.FDH TNPH. CNH RCNT.CNH GR.CNH DEPT. RFFO. FDH CALI.CDH TNPH.CNH RCNT.CNH GR.CNH 9461.400 RHOB.FDH 1.531 6176.000 RNFD.FDH 1754.000 3.965 GR.FDH 107.188 39.899 TNRA.CNH 3.379 1952.065 RC;T..CNH 528.698 107.188 TENS.CNH 2934.000 9400.000 RHOB.FDH 1.750 3924.000 RN~D.FDH 1662.500 5.519 GR.FDH 107.703 37.803 TNRA.CNH 3.342 2038.000 RCFT.CNH 538.7'50 107.703 TENS.CNH 4708.000 9300.000 RHOB.FDH 2.459 851.000 RNFD.FDH 1163.906 8. 912 GR. FDH 98.188 41.592 TNRA.CNH 3..453 1764.000 RCFT.CNH 504.000 98.158 TENS.CNH 4878.500 DPHI.FOH -999.250 DRHO. FDH FFOC. FDH 4212.000 NFDC.FDH TENS.FDH 2934.000 NPHI.CNH RTNR.CNH 3.642 NPOR.CNH CNTCoCNH 1998.595 CFTC.CNH DPHI.FDH 65.099 DRHO.FDH FFDC.FDH 2656.000 NFDC.FOM TENS.FDH 4708.000 NPHI.CNH RTNR.CNH 3.705 NPDR.CNH CNTC.CNH 2008.909 CFTC.CNH OPHI.FDH 12.243 DRHO. FDH FFDC.FDH 537.906 NFCC.FDH TENS.FDH 4878.500 NPHI.CNH RTNR.CNH 3.909 NPOR.CNH CNTC.CNH 1852.125 CFTC.CNH -0.018 1004.000 4.6.265 39.899 601.753 0.015 960.000 43.878 37.277 629.875 0.074 653.125 41.742 41.187 537.563 LIS TAPE YERiFICATION LISTING $'CHLUMBERSER .ALASKA COMPUTING CENTER DEPT. 9200.000 RHSB.FDH RFFD.FDH 686.750 RNFD.FDH C~LI.FDH B.805 GR.FDH TNPH.CNH .33.880 TNRA.CNN RCNT.CNH 2253.000 RCFT.CNH GR. CNH 84.906 TENS.CNH DEPT. 9100.000 RHDB.FDH RFFD. FDH 942.000 RNFD.FDH CALI. FDH 9. 156 GR.FDH TNPH. CNH 29. 510 TNRA.CNH RCNT.CNH 2572.000 RCFT.CNH GR.CNH 5.3.203. TENS.CNH DEPT.. 9000.000 RHOB.FDH RFFO.FDH 662.25!0 RNFD..FDH CALI.FDH 9.758 GR.FDH TNPH.CNH 38.504 'TNRA.CNH RCNT.CNH 1840.000 R~CFT.CNH GR.CNH 126.992 TENS.CNH DEPT. $900. 000 RHOB.FDH RFFO. FOH 996'750 RNFD.FOH CALI. FDH 9.36! GR.FDH TNPH.CNH 45.227 TNRA.CNH RCNT.CNH 17t6.000 RCFT.CNH GR.CNH 117.813 TENS..CNH DEPT. 8800.000 RHOB.FDH RFFD. FDH 873.000 RNFD.FOH CALI.FDH 9.266 GR.FDH TNPH.CNH 47.961 TNRA.CNH RCNT. CNfl 1699.000 RCFT.CNH GR.CNH 119.750 TENS.CNH DEPTo 879&.607 RHgB.FOH RFFD.FOH -999.250 RNFD.FDH CALI.FDH -999.250 GR.FDH TNPH.CNH -999.250 TNRA.CNH RCNT.CNH -999.250 RCFT.CNH GR.CNH -999.250 TENS.CNH END DF DATA t7-SEP-1989 12:14 2.494 DiPHI.FOH 933.000 FFDC'FDH' 84.906 TENS.FDH 3.051 RTNR.CNH 690. Z50 CNTC.CNH 4886.500 2.335 OPHI.FDH 1144. Z50 FFOC.FDH 53.203 TENS.FOH 2.695 RTNR.CNH 927.000 ~CN'TC.C~NH '4928.250 2.481 DPHI.FDH 1043.500 ,'FFOC. FDH 126.992 TENS.FDH 3.324 RTNR.CNH 512.063 CNTC.CNH 4848.063 2.335 DPHI'FDH 1189.7'50 FFDC.FDH 117.813 'TENS.FOH 4..008 RTNR.CNH 432.875 CNTC.CNH 4847.875 2.342 DPHI-FDH 1055.000 FFDC.FDH 119.750 TENS.FOH 3.819 RTNR.CNH 412.500 CNTC.CNH 4728.750 -999.250 OPHI.FDH -999.250 FFDC.FDH -999.250 TENS.FDH -999.250 RTNR.CNH -999.Z50 CNTC. CNH -999.250 1.553 456.500 4 88 6.. 5 O0 2.820 23'18.250 20.920 64. 3.375 .4928.250 2.703 2682.688 9. 890 462.906 4848.063 3. 734 1928. 688 -21.390 677,.000 4847.875 3'84.4 1735.688 19.671 628.188 4728.750 4.406 1747.375 13.559 -999.250 -999.250 -999.250 -999.250 DRHO.FDH NFDC. FDH NPHI. CNH NP OR. CNH CFTC.CNH DRHO.FOH NFDC.FDH NPHI'CNH NPOR.CNH CFTC.C!NH DRHO.FDH 'NFDC.FDH NPHI.CNH NPOR.CNH ~CFTC.CNH ORHO.FDH NFDC.FDH NPHI.CNH NP:R.CNH CFTC.CNH DRHO.FDH NFDC.FDH NPHI.CNH NPOR.CNH CFTC.CNH DRHO.FDH NFDC.FDH NPHI.CNH NPaR.CNH CFTC.CNH PAGE: 24 0.042 5979469 34.536 33.218 784'781, 0.022 641.625 28.519 28.699 997.875 0.035 594.125 35.101 38.552 586.141 0 .. 043 672 · 063 51.233 4.6.475 470.500 0.019 633.750 47.894 48.987 453.688 -999.250 -999.250 -999.250 -999.250 -999.250 ,IS T:APE VERIFICATION LISTING CHLUM~ERGER ALASKA COMPUTING CENTER I?.-SEP-lg89 1Z:1~ PAGE: ***~: F IL E TR ~ IL E R 4*** FILE NAME : EDIT .OOZ SERVICE : FLOC VERSION : 001A02 MAX AEC SIZE : [024. FILE T¥'PE : LO LAST FIlE : **** TAPE TRAILE~i **** SERVICE NAME : EDIT DATE : 89109/17 ORIGIN : FlIC TAPE NAME : ?3460 CONTtNU,~TIDN # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC',KUPARUK,ZK - 8,5'0-103-Z0111-00 ***~ REEL TRAILER SERVICE NAME : EDIT DATE : 89/09/17 ORIGIN : FLIC REEL NAME :' 73,4.60 CON'TINUATION ~ : PREVIOUS REEL : COMMENT : ~RCO ALASKA IN'C',KUPARUK,ZK - 8,50-103-20111-00
