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193-072
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. lc::}' ~ -'0?~ile Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED · [] Logs-of various kinds [] Other COMMENTS: Scanned by: Beverly~~ncent TO RE-SCAN Nathan Lowell Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si ( STATE OF ALASKA { ALASKAulL AND GAS CONSERVATION COMMISSION ': , WELL COMPLETION OR RECOMPLETION REPORT AND LOG,,}; NOV, '12004 No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged 181 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: CDR, CDN, HLDT, CNTG, TDTP, CET, CBT, GCT CASING, LINER AND CEMENTING RECORD S~TTI~~~I;PTHMb'ScTTIN~Ot;~1VPi' "Hgd~, ' , , : :,:Ttt)pl, îaO'fT(!)M '1;~TQP:?eOJTØM ' ' ": SfZS' ' "" " " , : ,QeMI£NTIN<;¡R¡:çÖRP , Surface 121' Surface 121' 24" 260 sx Arctic Set (Approx.) Surface 4599' Surface 3600' 12-1/4" 800sxPF'E', 480 sx 'G', Top Job: 105sxPF'C' Surface 7568' Surface 5733' 8-1/2"250 sx Class 'G' 7264' 8372' 5501' 6417' 6-1/8" 175 sx Class 'G' PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A PRODUCTION FOR Oll-BSl TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Oll-Bsl Press. 24-HoUR RATE CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~_ilk.~.~ø?tf1t¿þ(1- RBDMS pE~ ~~~ ,~ 6 10M ~ .,~::,"':~' " . i SCAN~a"'NO~ 2 4 0 I G I A L ! Jßlotf L;:~: 0 GINJ 0 WINJ 0 WDSPL 2. Operator Name: Conoco Phillips Alaska Inc. 3. Address: clo P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 570' SNL, 1762' EWL, SEC. 01, T11 N, R09E, UM Top of Productive Horizon: 5114' SNL, 2986' EWL, SEC. 01, T11N, R09E, UM Total Depth: 168' SNL, 3091' EWL, SEC. 12, T11N, R09E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 531432 y- 5974756 Zone- ASP4 TPI: x- 532677 y- 5970217 Zone- ASP4 Total Depth: x- 532784 y- 5969884 Zone- ASP4 18. Directional Survey 0 Yes 181 No 22. , CA$ING ,", SIZE.,' 16" 9-5/8" , IWT¡ee.R':F't,. 62.5# 47# 136# 26# 18# ,G~DE,: H-40 L-80 I J-55 L-80 L-80 7" 5" 23. Perforations oRen to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD , 26. Date First Production: Not on Production Date of Test Hours Tested 27. None Form 10-407 Revised 12/2003 Tual~GRECÓRD' , SIZE DEPTH SET (MD) 3-1/2", 9.3#, L-80 7185' 3-1/2",9.3# 19.2#, J-55 I L-80 7185' - 7681' , , , 'Ad [J"Æ~CTURE¡Ç~MEf\lT ,SQUEFZE"ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7870' Set Whipstock 7874' P&A wI 10 Bbls Class 'G' Cement followed by 15 Bbls Class 'G' Zero Other 5. Date Comp., Susp., or Aband. 8/6/2004 ¡ r-r 6. Date Spudded 06110/1993 7. Date T.D. Reached 06/21/1993 8. KB Elevation (ft): 106' 9. Plug Back Depth (MD+TVD) 7874 + 5982 10. Total Depth (MD+ TVD) 8375 + 6420 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 24~ TVD GAs-McF W A TER-Bsl GAs-McF WATER-Bsl CONTINUED ON REVERSE SIDE ~,tb. ; \Nell ClaS$: B 'Development, 0 Exploratory 0 Stratigraphic 0 Service 12. Permit to Drill Number 193-072 304-261 13. API Number 50- 029-22371-00-00 14. Well Name and Number: Kuparuk 1Y-24 15. Field I Pool(s): Kuparuk River I Kuparuk River Oil Pool Ft Ft 16. Property Designation: ADL 025646 17. Land Use Permit: 20. Thickness of Permafrost 1500' (Approx.) , 'AMQUNT ,IRÙÜ.ED PACKER SET (MD) 7193' CHOKE SIZE GAS-Oil RATIO Oil GRAVITY-API (CORR) G (,;" 28. (' GEOLOGIC MARKERS 29. (' FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None", Top Kuparuk K-1 7676' 5815' None Base Kuparuk 8130' 6204' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble -(.QM.ie. ij¡ ~ Title Technical Assistant Date! 1-/8 -D« Kuparuk 1Y-24 193-072 304-261 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Dan Kara, 564-5667 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. 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: True vertical thickness. 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: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ( Well: Field: API: Permit: 1Y-24A & 1Y-24AL 1 Kuparuk 50-029-22371-01-00/-60-00 204-125 & 204-126 Accept: 08/16/04 Spud: 08/17/04 Release: 08/28/04 Rig: Nordic #2 Accept: 10/01/04 Spud: 10/07/04 Release: 10/18/04 Rig: Nordic #2 PRE-RIG SIDETRACK WORK 07/31/04 DISPLACED TUBING WI HOT DIESEL; BRUSHED D NIPPLE. DRIFTED TUBING W 2.73" X 13' DRIFT TO 7885' RKB. 08/03/04 ATTEMPTED TO SET WHIPSTOCK IN 5" LINER. COULD NOT PASS WHIPSTOCK THROUGH 2.75" 'D' NPPLE. TRIED PUMPING DOWN ON TOOLS TO PASS THEM THROUGH NIPPLE. STILL UNABLE TO PASS. MAX OD OF TOOL IS 2.7" (OVER APPROXIMATELY 7' OF TOOL LENGTH), 08/04/04 BROACH THROUGH "D" NIPPLE WITH 2.745" BROACH @ 7211' RKB. 08/05/04 SET WHIPSTOCK IN 5" LINER AT 7870' (TOP OF WHIPSTOCK), RA TAG WAS SET AT 7875', TAGGED WHIPSTOCK TO CONFIRM SET. FIRST ATTEMPT TO SET WHIPSTOCK FAILED - WHIPSTOCK FELL TO BOTTOM. WHEN CORRELATING FIRST WHIPSTOCK, SAT DOWN EARLY AT 8002', OVER PULLED 700 LB AND CAME FREE. SUSPECT CASING DAMAGE FROM UNDERREAMING. WELL LEFT SHUT IN. / 08/06/04 CEMENT SQUEEZE. DISPLACED WELL TO SEAWATER. TAGGED TOP OF WHIPSTOCK AT 7870' AND v FLAGGED CT. FIRST SQUEEZE ATTEMPT PUMPED 10 BBLS OF 15.8# CLASS G CEMENT, BULLHEADED FIRST 7 BBLS AND THEN LAYED IN 3 BBLS. UNABLE TO OBTAIN SQUEEZE PRESSURE. BULLHEADED RESIDUAL CEMENT INTO FORMATION. SECOND SQUEEZE ATTEMPT PUMPED 15 BBLS OF 15.8# CLASS G CEMENT W / AGGREGATE, BULLHEADED 10 BBLS AND LAYED IN 5 BBLS ABOVE THE WHIPSTOCK AT 7870' RKB. UNABLE TO OBTAIN SQUEEZE PRESSURE. BULLHEADED TOP OF CEMENT DOWN TO 7804' RKB. LEFT CEMENT PLUG IN LINER. FREEZE PROTECTED TUBING WI DIESEL TO 2500'. 08/08/04 TAGGED CEMENT PLUG AT 7721' RKB, 83' HIGHER THAN CT CLEANOUT. PRESSURE TEST TUBING TO 1000 PSI, 20 MINUTE BLEED DOWN TO 900 PSI. 08/09/04 UNDERREAM CEMENT FROM 7692' RKB DOWN TO 7859' RKB, USING SLICK SEAWATER AND 1.5# BIOZAN GEL. FREEZE PROTECTED TUBING DOWN TO 2800' RKB W/ DIESEL. PRESSURE TESTED CEMENT PLUG TO 1500 PSI. NORDIC #2 MOVED ON FROM 08/16/04 TO 08/28/04 - OPERATIONS SHUTDOWN ( ( BP EXPLORATION QperatiønsSummary Report Page 1 t8I Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y -24 1 Y -24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Date From - To Hours Task Code NPT Phase Description of Operations 8/13/2004 18:00 - 20:00 2.00 MOB P PRE Conducted JJSM on moving off well and mob rig to 1Y Pad Back rig off of 1 C-08 Well 20:00 - 00:00 4.00 MOB P PRE Rig move 1 C-08 to 1 Y -24. Rig became stuck twice in less than 1/2 mile from 1 C-08 due to poor road conditions Digging out and matting up under wheels to get on rig mats. 8/14/2004 00:00 - 02:00 2.00 MOB N MISC PRE Have Kup Tool Ser start laying rig mats for road travel. Digging out in # 2 soft spot. Made 5 ft in 2 hrs and still unable to get rig upon rig mats Called for heavy equipment to assist in pulling rig out of ruts and on to rig mats. Note: the rig tires ruts are deeper than the road bed. 02:00 - 02:45 0.75 MOB N MISC PRE Wait on equipment to help pull rig onto rig mats 02:45 - 04:00 1.25 MOB N MISC PRE Using the rig, bed truck and blade pulled the rig up onto rig mats 04:00 - 07:30 3.50 MOB N MISC PRE Check rig equipment. Pull rig to end of rig mats 756 ft. PU wood, plywood and rig mats behind rig. 07:30 - 00:00 16.50 MOB N MISC PRE Using existing rig mats only (120+), lay the mats in front of rig. Drive forward to end then double up the same mats behind rig, Drive rig in reverse to the end of doubled mats. Relay the doubled mats out singularly in front of rig and drive forward again. Continue repeating the process. While laying out mats this morning rig crews kept busy changing out othe BOP rams to 2". Also stuffing box seals on injector and swapping to 2" blocks. Two more cycles before the KIC turnoff 8/15/2004 00:00 - 04:30 4.50 MOB N MISC PRE Moving rig on 1 C Pad access roda to KIC turn off. Cycling mats. Finished RU equipment for 2" coiled tubing 04:30 - 13:30 9.00 MOB N MISC PRE At KIC corner at 0430 hrs. Moving rig on mats across intersection towards KOC base camp. At the KOC corner at 1330 hrs. 13:30 - 18:30 5.00 MOB P PRE Continue rig move on Spine Road. (called AOGCe rep Jeff Jones and gave BOP notice for +/- 0200hrs) 1440hrs adjacent to KOC. Laying mats across pipeline crossings 18:30 - 00:00 5.50 MOB N MiSe PRE On location at 1830 hrs. Location soft, buried the back wheels, called for heavy equipment to assist in removing from sink hole. Pulled out of hole, became stuck again while pulling over well. Removed busted wood used Peaks Cat to level. Installed rig mats and Peaks winch cat pull the rig upon mats. Working at getting rig spotted over well. 8/16/2004 00:00 - 01 :00 1.00 MOB P PRE Moved rig over well and set down 01 :00 - 02:00 1.00 MOB P PRE WHP 475 psi, bleed down to zero. Removed Tree cap and NU BOP's Loaded coiled tubing in reel house. 02:00 - 06:00 4.00 RIGU P PRE NU BOP's and setting up yard. Recieved water and diesel fuel. Kup building tank farm. Kup grease crew servicing valves 06:00 - 09:30 3.50 BOPSUP P PRE PT BOPE Jeff Jones, AOGCC wavered witnessing BOP test on 1 Y -24 PT 400/4500 psi Rig up hardlines inside the coil reel. 09:30 - 14:30 5.00 RIGU P PRE Continue working with hardlines in reeel house. Install internal coil grapple and prep to stab to injector. Stab coil to injector. Shrink wrap end of coil. 14:30 - 19:00 4.50 RIGU P PRE Fill coil with used Flo-Pro. Reverse 1 coil volume at 3.3bpm Printed: 11/16/2004 2:57:54 PM ( Page 2 ~ BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y-24 1 Y -24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To Hours Task Code NPT Phase 8/16/2004 4.50 RIGU P PRE 14:30 - 19:00 19:00 - 20:04 1.07 STWHIP P WEXIT 20:04 - 22:00 1.931 STWHIP P WEXIT 22:00 - 23:32 1.53 STWHIP N DFAL WEXIT 23:32 - 00:00 0.47 STWHIP N DFAL WEXIT 8/17/2004 00:00 - 01 :15 1.25 STWHIP N DFAL WEXIT 01 : 15 - 01 :45 0.50 STWHIP N DFAL WEXIT 01 :45 - 03:15 1.50 STWHIP N DFAL WEXIT 03:15 - 03:30 0.25 STWHIP P WEXIT 03:30 - 03:37 0.12 STWHIP P WEXIT 03:37 - 03:42 0.08 STWHIP P WEXIT 03:42 - 04:24 0.70 STWHIP N SFAL WEXIT 04:24 - 04:41 0.28 STWHIP P WEXIT 04:41 - 06:20 1.65 STWHIP P WEXIT 06:20 - 09:42 3.37 STWHIP P WEXIT 09:42 - 11 :35 1.88 STWHIP P WEXIT 11 :35 - 13:04 1.48 STWHIP P WEXIT 13:04 - 14:50 1.77 DRILL P PROD1 14:50 - 16:05 1.25 DRILL P PROD1 16:05 - 16:25 0.33 DRILL P PROD1 16:25 - 16:55 0.50 DRILL P PROD1 Start: 8/1 0/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Description of Operations Cut-off 25' coil. Install SLB Kendal coil connector. Pull test CTC to 35k Mega eline and PT CTC to 4000 psi PU window milling BHA along with BHI CoilTrak system Checked tool RIH with Milling BHA. SSSV at 3900 psi, IA = 365 psi Taking diesel to tiger tank Vp = 296 bbl before displacing. Wt check 5600 ft 18k up, 5.6k down Working to find short in either tool or surface. Downhole POOH to trouble shoot short in downhole tool. Displacing diesel out of well while POOH Monitor well, unstab injector and trouble shoot tool and eline Checked line, short at UQC, power comms failure Re-heading UQC and changing out Power Comms module PU/MU Upper BHA Set conunter to 112.6 ft Note: 3.9 ft space out for pressure deployment RIH to 7720 ft, Tie-in using the GR marker at 7678 ft NPT 2200 hrs to 0300 hrs ' and log RA Marker down with HS TF Logging tie-in at 7678 ft (Corrected -2 ft) RIH and tagged TOC at 7873' PUW = 22.6k Retag Down wt = 9.2 k 7873 ft Break cir with mud down CT, Leak in reel house SD at 2500 psi Fix leak in reel hardline, hardline from swivel joint. PT lines to 4500 psi Start Cir again RIH to top of cement at 7873' Milling cement on top of WS with 100 psi motor work Cir up small amount gas Pp = 2889 psi at 1.46 bpm, BHP = 3178 psi ECD = 10.51 Tagged pinch point at 7878'. Mill ahead with 300psi MW 1.49bpm 3035psi 3660 bhp 10.37ecd. Good metal cuttings to surface. Appear to be drilling formation at 7882' Drill formation f/7882' 100psi MW 1.58bpm 3200 psi 3676bhp 1 0.43ecd. TOW @ 7878 ft BOW @ 7882 ft PTD @ 7892 ft Formation in sample POOH following pressure schedule Closed SSSV w/ 540 psi below Checked flow, OK, Change out BHA 2.8 Bend RIH, increased WHP to 550 psi to open SSSV Following TIH pressure schedule Log tie in pass down over GR charecter at 7678'. Make -2' correction. RIH, with tool face at 15R. Very slight weight bobble at bottom of window at 7882', but no problems really. Kick on pumps, free spin is 3270 psi at 1.8 bpm. Orient in open hole to 9OR. Tag bottom at 7891'. Begin drilling. Tool faces acting erratically, tool bouncing a bit. TF finally settled down after drilling a couple of ft. Hold TF at 75R, Drilling ahead at 1.82/1,84/3380 psi. ROP=60 fph. Pit volume=20 ,bbls and still doing mud swap. Printed: 11/16/2004 2:57:54 PM ( ( BP EXPLORATION Operations Summary Report Page 388 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y-24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Date From - To Hou rs Task Code NPT Phase Description of Operations I 8/17/2004 16:55 - 19:47 2.87\ DRILL P PROD1 7899', Drilling at 1.8/1.6/3200. Started losing returns 0.2 bpm. Healed up after 10 minutes. Life is good. Continue drilling 2.021 DRILL ahead in B shale. ROP 20-40 fph. 19:47 - 21 :48 P PROD1 Drilling 88R TF Vp = 381 bbl I Closed choke in to 50 psi WHP and BHP inc to 3210 psi, EDC = 10.4ppg 0=1.6/1.6 bpm at CTP 2900/2800 psi Drilling in B & A6 Shale Bleed IA down from 836 psi to 858 psi 21 :48 - 22:04 0.27 DRILL P PROD1 Wiper trip to Tie-in with pressure schedule to GR marker at 7695 ft 22:04 - 22:35 0.52 DRILL P PROD1 RIH logging GR marker at 7680 ft and RA Maker at 7895 ft . ft and added 1 ftO= 0.45bpm; WHP = 245 psi; BHP = 3197 psi EDC 10.79ppg. Stopped at 7707 ft asnd added 1'. RIH to 7890 ft and log RA Marker down with HS TF. RA Marker at 7879 ft TOW @ 7874 ft BOW @ 7881.5.00 ft RA Marker @ 7879 ft 22:35 - 22:48 0.221 DRILL P PROD1 RIH to finish wiper trip 22:48 - 00:00 1.20 ¡ DRILL P PROD1 Drilling 80R TF Vp = 388 bbl ( WHP = 50 psi and BHP inc to 3276 psi, EDC = 10.57ppg 0=1.5/1.5 bpm at CTP 2915/2800 psi Drilling in Base B1and Top A6 Reverse drilling break at 8056 ft Ankerite possiblility Drilled through. 8/18/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Drilling HS to 65R TF Vp = 380 bbl WHP = 50 psi and BHP inc to 3300 psi, EDC = 10.58ppg 0=1.5/1.5 bpm at CTP 3127 psi Landed with present build motor 01 :00 - 02:38 1.63 DRILL P PROD1 POOH following pressure schedule Shut in SSSV with 500 psi trapped below. Tagged up, RIH at 100 fpm/1.5 bpm to clean upper hole. Flow check at 155 ft OK POOH 02:38 - 04: 15 1.62 DRILL P PROD1 Change out BHA Motor Bend @ 1.1 deg Added 2 ft lubricator for pressure deploy 04:15 - 06:15 2.00 DRILL P PROD1 RIH Vp initially = 348 bbl Equalized WHP to 550 psi, open SSSV. 06:15 - 06:30 0.25 DRILL P PROD1 Log tie in pass over GR Marker. Correction=-5'. 06:30 - 10:05 1.75 DRILL P PROD1 RIH to TD. Free spin=3460 psi at 1.8 bpm. Drilling ahead at 1.8.1.8/3600 psi. 50 psi WHP. Annular press=3350 psi. Pit vol=373 bbls. IAP=600 psi, OAP=O psi. 08: 15 - 08:45 0.50 DRILL P PROD1 Wiper trip to shoe. Clean PU at 20 klbs. No problems up or down. Smoooooth. 08:45 - 10:05 1.33 DRILL P PROD1 Free spin 3400 psi at 1.8 bpm. Pit vol=371 bbls. IAP=747 psi, OAP=O psi. Resume drilling at 1.8/1.8/3550 psi. Inc at bit=86.5. New TVD target is 6018'-6020', 5' to 7' deeper than plan. ROP=105 fph. Bled down lAP. 10:05 - 1 0:50 0.75 DRILL P PROD1 Wiper trip to window. Set down at 8052 while RIH (Top of A6 Sand). Orient to 65R, and fell thru easily. 1 0:50 - 12:30 1.67 DRILL P PROD1 Resume drilling. Driling at 1.8/1.8/3516. Free spin 3400 psi. ROP=60 fph. Drilling down as per instructions. Getting shaly'er. Printed: 11/16/2004 2:57:54 PM ( ( BP EXPLORATION Operations Summary. Report Page 4 48Þ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y-24 1 Y -24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Date From - To Hours Task Code NPT Phase Description of Operations -- 8/18/2004 12:30 - 13:30 1.00 DRILL P PROD1 Wiper trip to tubing tail. Oriented to 45L, and slipped thru 8050' with no problems. 13:30 - 15:40 2.17 DRILL P PROD1 Resume drilling. Pit vol=363 bbls. IAP=165, OAP=O. 1.77/1.79/3580. Free spin=3350 psi. In shaley stuff. Drilling up to get out of it as per Geo. ROP=30 fph. GR=150 API counts. 15:40 - 16:00 0.33 DRILL P PROD1 Wiper trip to shoe. Clean PU off bottom at 22 klbs. 16:00 - 16:30 0.50 DRILL P PROD1 H2S and rig evacuation drill (table top) in rig ops cabin. Attendenace by all hands on location, +Udo Casse. H2S charecterestics, PPE, training requirements, alarms and a simulated evacuation were discussed. 16:30 - 17:15 0.75 DRILL P PROD1 Continue wiper back into hole. No problems at 8052' with tool face at 15R. 17:15 - 19:00 1.75 DRILL P PROD1 Resume drilling lateral section. Hunting for sand. Now drilling straight down as per Geo. Drilling at 1.8/1.8/3470 psi. Pit vol=360 bbls. IAP=230 psi, OAP=O psi. 19:00 - 19:45 0.75 DRILL P PROD1 Drilling at 90 R TF to hold 6016 ft TVD. Stopped drilling at 8864 ft 10k down and no ROP, Possible Ankerite cementation in sand 19:45 - 21 :00 1.25 DRILL P PROD1 Wiper trip to 7890 ft RIH and tagged at 8685 ft Ledge possibility PUW = 23k RIH. 21 :00 - 22:00 1.00 DRILL P PROD1 Drilling 90 RTF Vp = 353 bbl, Q= 1.67/1.68bpm; Den = 8.71/8.75ppg, BHP 3408. Open choke t045 psi to reduce ECD and BHP. Drilling with negative WOB at surface and 3.4 WOB BHI, hard. broke into the beach At 8875 ft bring TF to 45 R to build to 88 to 89 deg hole angle. 22:00 - 22:30 0.50 DRILL P PROD1 Drilling ROP inc in the sand. TF at 60R BHP = 3404 = 10.9 ppg EDC ROP 90 to 100 fph Drilled 47 ft good sand Reduced WHP = 31 psi 22:30 - 00:00 1.50 DRILL P PROD1 Hit hard Ankerite wall, ROP dropped off at 8919 ft. Drilling with negative WOB / 2k BHI BHP = 3360 psi w/ 10.75 EDC Turned TF down to 150 R 8/19/2004 00:00 - 00:50 0.83 DRILL P PROD1 Hit the beach again, ROP PU to 86 fph using 90R TF NB at 88 deg 00:50 - 01 :05 0.25 DRILL P PROD1 Drilling in a thin sand layer at 6024 TVD. Presently drill in hard streak using 3.6klb BHI and -6700 Ib CT TF = 90 R trying to hole 88 89 deg hole angle. Q = 1.75/176 bpm at 3600 psi BHP = 3387 psi EDC = 10.85 ppg; WHP (full open choke) = 26 psi. 01 :05 - 02:00 0.92 DRILL P PROD1 Having trouble drilling, Wiper trip to TT 7681 ft Keeping ECD at 10. 7ppg and 3250 psi BH P Q = 1.5 bpm 02:00 - 02:05 0.08 DRILL P PROD1 Tie-in at RA marker at 7879'/7890 ft. No correction 02:05 - 03: 1 0 1.08 DRILL P PROD1 Wiper trip in the hole Tagged at 8680' PU RIH tagged at 8704 ft PUH, little tight Tagged at 8680 again. Reduced Qp to 0.75bpm and brought WHP up to 100 psi, BHP 3300 psi RIH tagged 8740',8760' 8743' Tagging hard streaks drilled with correct TF. Inc Qp to 1.4 bpm while RIH past 8800 ft No fluid loss on wiper trip 03:10 - 03:25 0.25 DRILL P PROD1 Presently drill in hard streak using 3.klb BHI and -5800 Ib CT Hard streaks are Ankerit which is Iron Carbonate cementation Printed: 11/16/2004 2:57:54 PM BP EXPLORATION Operations Summary Report Page 5 ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y-24 1Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Date From - To Hours Task Code NPT Phase Description of Operations 8/19/2004 03: 1 0 - 03:25 0.25 DRILL P PROD1 in the sand TF = 80 R trying to hold 88 to 89 deg hole angle. Q = 1.67/1.67 bpm at 3590 psi BHP = 3392 psi EDC = 10.85 ppg; WHP (full open choke) = 26 psi. 03:25 - 04:55 1.50 DRI LL P PROD1 Drilling at 90R & 90L TF in the beach again/ sweet spot. ROP 90 to 1 00 fph Q = 1.60/1.60bpm,WHP = 20 psi; BHP = 3419 psi, ECO = 1 0.9ppg. ROP controlled at 100 fph Found the sweet spot 04:55 - 06:00 1.08 DRILL P PROD1 Wiper trip to WS. Trip out good. 06:00 - 06:50 0.83 DRILL P PROD1 RIH, set down at 8680' with TF 90L. Oriented to 180 deg (Drilled tool face), and got thru. Set down at 8740 with tool face at 180 deg. PU, got thru. 06:50 - 08:10 1.33 DRILL P PROD1 Resume drilling. Free spin 3660 psi at 1.83 bpm. Drilling at 1.83/1.82/3800 psi. BHP=3500 psi. ECD 11.2 psi. Call for trucks for mud swap. Makeing 120 fph in sand. 08:10- 10:00 1.83 DRILL P PROD1 Wiper trip to shoe. Clean PU off bottom at 22klbs. Clean to shoe. Clean back in hole with 1 set down at 8770'. Orienter was at the drilled tool face of 180 deg. PU, dropped pump rate to 1.0 bpm, and eased thru it slowly. Did not see in on second attempt at it. Ledges appear to be cleaning up. On mud swap to new mud. 10:00 - 12:00 2.00 DRILL P PROD1 Resume drilling lateral section of hole. 1.8/1.8/3760 psi. BHP=3460 psi. Pit vol=337 bbls. IAP=375 psi, OAP=O psi. ROP=75 fph, TF=180. Drilling down to find sand. Doing mud swap to new mud. Pumping 8.7 ppg mud with 3% lubetx and 10 ppb of Kla-gard. 12:00 - 14:05 2.08 DRILL P PROD1 Wiper trip to shoe. Clean PU at 23 klbs. New mud around. Holding 50 psi on wellhead with new mud in hole. BHP=3370 psi. 270 psi overbalanced. Set down at 8714' when RIH. Dropped pumps to 1 bpm, and eased thru at 15 fpm, with no problems. 14:05 - 16:10 2.08 DRILL P PROD1 Resume drilling. Free spin 3200 psi at 1.77 bpm. Drilling ahead at 90L tool face. ROP=100 fpm. TF=85L. String wt=21 00 Ibs. WHP=50 psi. BHP=3380 psi. 16:10- 17:00 0.83 DRILL P PROD1 Make wiper trip to shoe. Clean PU off bottom at 23 klbs. Tripped early to give the geo time to formulate a plan forward. 17:00 - 17:10 0.17 DRILL P PROD1 Log tie in pass. 0 correction needed. 17:10 - 18:30 1.33 DRILL P PROD1 Continue back in hole. Using low Qp in trouble areas Geolgist wants to climb up to 96 deg. Pull tight at 9475 ft while working orientor 18:30 - 19:20 0.83 DRILL P PROD1 Drilling at 15L to 15 RTF to build hole angle to 96 deg Q=1.81/182 bpm BHP = 3320 psi at 10.61ppg, WHP = 26 psi ROP = 110 fph Drilling sand. Orientor acted slow all day, 50 hrs operating 19:20 - 19:50 0.50 DRILL P PROD1 Drilling at 15 RTF to build hole angle to 96 deg Found another hard spot Q=1.81/182 bpm BHP = 3366 psi at 10.76ppg, WHP = 50 psi ROP = <2 fph. Recieved new plan from Geo 19:50 - 20:00 0.17 DRILL P PROD1 PUH to orient TF angle at bit 97 deg. Took 10 minutes to move Printed: 11/16/2004 2:57:54 PM ( ( Page 6" BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1 Y-24 1 Y -24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 8/19/2004 8/20/2004 From - To Hours Task Code NPT I Phase I I 19:50 - 20:00 0.17 DRILL P PROD1 20:00 - 22:40 2.67 DRILL N DFAL PROD1 22:40 - 23:15 0.58 DRILL N DFAL PROD1 23:15 - 00:00 0.75 DRILL N DFAL PROD1 00:00 - 00:30 0.50 DRILL N DFAL PROD1 00:30 - 01:15 0.75 DRILL N DFAL PROD1 01:15-02:15 1.00 DRILL N DFAL PROD1 02:15 - 03:45 1.50 DRILL N DFAL PROD1 03:45 - 03:55 0.17 DRILL N DFAL PROD1 03:55 - 05:00 1.08 DRILL N DFAL PROD1 05:00 - 06:00 1.00 DRILL P PROD1 06:00 - 08:30 2.50 DRILL P PROD1 08:30 - 11 :15 2.75 DRILL P PROD1 11:15 -12:50 1.58 DRILL P PROD1 12:50 - 13:50 PROD1 1.00 DRILL P 13:50 - 14:45 0.92 DRILL P PROD1 14:45 - 16:45 2.00 DRILL N DPRB PROD1 16:45 - 17:45 17:45 - 18:16 1.00 DRILL P 0.52 DRILL C PROD1 PROD1 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Description of Operations 10 deg, orientor is weak. POOH to change out orientor and motor POOH, open EDC at 7823 ft, POOH following pressure schedule Q= 2.47 BPM. Cycled CT top 500 ft to finish cleanup. Monitor well, unstab, change BHI CoilTrak and motor. RR . PDC bit #2 RIH at 0.5 bpm, equalized pressure above SSSV, open at 527 psi P=3850 psi on SSSV panel RIH, at 2800 ft the DPS went erratic, trouble shoot software at surface. Numbers incorrect POOH to change out PDS sub Changed out tool RIH as per pressure schedule Tie-in at RA marker (corrected -5 ft) RIH Q= 1.6 bpm, EDC = 10,51ppg. Tagged at 8926 ft Ankerite stringer. PU reduced Qp to 0.9 bpm, went through RIH. Set down 9222 ft adjusted TF to 140L .from 180TF RIH Drilling from 9580 ft (hard) Q= 1.66/1.65bpm at 2955 1 3305psi. WOB = 0.75klbf CTW = -1.8k Red WHP from 50 to 40psi. Circulated trace oil and gas cut mud to surface. Diverted to soilds tank, increased EDC to 11.22 ppg and circulated well. Cir 6 bbl to cutting box. Drilling ahead. Free spin 3550 psi at 1.8 bpm. WHP=60 psi. BHP=3470 psi. Pit vol=351 bbls. IAP=256 psi. OAP=O psi. ROP=65 fph. Drilling in shale. INC=94 deg. Trying to drill up and get back into good sand. Increasing lubtex concentration to 5% in active system. Back in good sand. Last ROP was 160 fph. String weigt=-700 to -8000 Ibs, Make wiper trip to shoe. Clean PU off bottom at 24 klbs. Continuing to add lubetex to mud, ordered Flo-Iube to bring concentration up 1% additionally. Total mud lubricants not to exceed 6%. Motor work and drag on wiper trip up from 8725'-8625'. Set down on way back in hole at 8644',8708', 8745',9530'. Got thru each depth by dropping pump rate, and RIH at 15 fpm. Resume drilling directionally. Free spin=3500 psi at 1,8 bpm. Begin drilling at 1.8/1.8/3611 psi. ROP=105 fph. Lubetex is in system. TD well. Make last wiper trip to shoe. Clean PU off bottom at 24,5001bs. Ream from 8730' to 8650'. Had overpulls, motor work, and packing off. Finally got thru ok, we will ream this more on next trip down thru it. Got a call from town. The plan is to extend the well. Continue trip to window. Continue trip into hole. Clean thru 8050'. Ratty 8630-8750'. Set down at 8780. Ream/Backream shales from 8750'-8630'. Getting motor work, and packing off. Having to work it slowly to keep from getting stuck. It seemed to improve a bit on each slow pass thru. Finally opened EDC, and washed up thru it at 2.4 bpm. Seemed to finally clean up, Continue RIH to finish wiper and begin drilling the extension. Begin drilling extended footage. Drilled to 9828' gas cut mud to Printed: 11/16/2004 2:57:54 PM ( ( BP EXPLORATION Operations Summary Report Page 7- Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y -24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Date From - To Hours Task Code NPT Phase Description of Operations ---- ---- 8/20/2004 17:45 - 18:16 0.52 DRILL C PROD1 ¡surface, PUH and bypass to cutting box 18: 16 - 18:35 0.32 DRILL C PROD1 I Work CT and cir gas cut mud out and clean up Cir out 25 bbl to cutting tank i Maintaining 3446 psi BHP at 11.03EDC WH=62 psi. Density 8.7/7.1 ppg RIH at 15 fpm, EDC @ 11ppg 18:35 - 21 :00 2.42 DRILL C PROD1 Drilling TF 60R, WOB = .5k/2.57k Qp = 1.81bpm BHP = 3428psi at 11.01 ppg EDC Density still dropping, dpwn to 7.83 ppg. Ordered mud swap. Drilling hard spot at 9829 ft. PU and restart, still hard Unable to drill. Drilled 7ft in 1.75 hrs 21 :00 - 21 :55 0.92 DRILL C PROD1 Broke through hard streak at 9845 ft. ROP PU to 100 fph WH = 100 psi, BHP = 3474psi @ EDC of 11.16. Density @ MM is 7.8ppg WOB 2.2klbf CTW = -75001b TD well drilling in shale and can only change 1 ft TVD. 21 :55 - 22:30 0,58 DRILL C PROD1 Work CT and make ready to swap to Density 8.7/ 7.6ppg. Started mud swap at 2156 hrs:Maintaining 3481 psi PUW = 24k, clean J.N. Clark, MI Mud Engineer while going in his mud lab, the door shut and cut off end of middle finger. Treated at rig and drove him to Kup Medical Facuility for treatment Alerted Kup personnel 22:30 - 00:00 1.50 DRILL C PROD1 Wiper trip with new mud around, Out density at 8.6 and climbing BHP = 3524psi, red WHP to 100 psi. Pulled tight at 8720 ft to 8620 f.t Had to work up to 40k in spots Density = 8.7/8.7ppg, BHP / EDC = 3497psi/11.20ppg Pulled clean above 8620 ft Finish mud swap and inc K-Gard to 10ppb and LT to 5% MI Clark, MI mud engineer, will rest at KIC tonight and be transported to Anchorage tomorrow. 8/21/2004 00:00 - 01 :35 1.58 DRILL N DPRB PROD1 Cir in liner while finishing taking on new mud. Adding K-Gard and L T BHP = 3344psi at 11.07 ppg Vp = 391 bbl. KGard at 10ppb 01 :35 - 03:00 1.42 DRILL N DPRB PROD1 RIH to cleanout for liner Q = 1 bpm. Clean between 8550 ft to 8850 ft Tagged at 9620 ft PU red Qp to 0.3 and went through. Tagged at 9880 ft (shale) Working to get to bottom. Unable to get below hard shale at 9880 ft Shale wrap around 03:00 - 04:45 1.75 DRILL N DPRB PROD1 PUH wiper trip Density = 8.7/ 6.5ppg, BHP = 3477psi at 11.16 ppg. Gas/oil to surface from bottoms up while maintaining 3590 psi BHP, divert to cutting box. Circulated out. Increased BHP to 3600 psi. Pulled up to 40k 4 times pulling from 8650 to 8600 ft Q = 0.5 bpm BHP at 3700 psi. PUH 04:45 - 04:55 0.17 DRILL P PROD1 Tie at RA marker (Corrected +2 ft) 04:55 - 06:45 1.83 DRILL P PROD1 RIH to confim TD for liner Q= 1.0 to 0.5 bpm, maintaining 3600 psi BHP 06:45 - 09:15 2.50 DRILL C PROD1 POOH, laying in new mud with 5% lubetex, 1% flolube, and 10 ppb of Kla-gard in open hole. No problems observed on trip OOH. Holding 350 psi on wellhead. POOH using revised pressure schedule of 350 psi in horizontal, and 890 psi at surface, Printed: 11/16/2004 2:57:54 PM ) ") 8åge8- Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y -24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Date From - To Hours Task Code NPT Phase Description of Operations 8/21/2004 09:15 - 09:30 0.25 DRILL C PROD1 BHA at 1600', shut SSSV. PUH to surface and tag up. 09:30 - 09:55 0.42 DRILL C PROD1 Tag up at surface, perform no flow check. No flow observed after 1/2 hour. 09:55 - 10:45 0.83 DRILL C PROD1 Lay down BHA #5. Bit recovered graded 1,2 chipped cutter on gauge section. 10:45 - 12:00 1.25 DRILL C PROD1 Safety mini stand down. Rig crews conduct safety inspection of rig components while an accident investigation is conducted into the injury that occured to the MI mud engineer last evening. 12:00 - 12:45 0.75 DRILL C PROD1 Discuss accident that occured on night tour. Report status of mud engineer J.N. Clark. Hold PJSM for running liner. Hazards reviewed in detail, and mitigations to hazards covered. All rig hands, MWD, DD, BP in attendance. 12:45 - 13:35 0.83 CASE C RUNPRD Pick up Baker eq. to rig floor for running liner, including inner work string. 13:35 - 15:15 1.67 CASE C RUNPRD Makeup 2-3/8" liner string #1 for lateral A. This is the first of 2 liner string run in the "A" lateral. 15:15 - 16:30 1.25 CASE C RUNPRD Make up 1" CS hydril inner work string inside 2-3/8" liner. 16:30 - 17:45 1.25 CASE C RUNPRD Run 24 joint of CSH. Pick up landing joint. RIH thru a-Ring sub and tag up on top of guide shoe. Calculate space out. Lay down landing joint. PU spaceout pups and deployment SLV. PU Baker BHA 17:45 - 20:00 2.25 CASE C RUNPRD RIH with liner and BHI CoilTrac Maintaining modified Pressure schedule 20:00 - 20:40 0.67 CASE C RUNPRD Tie-in at GR markers at 6840 ft and 6920 ft. (Corrected -7 ft) BHP = 3145 psi. Estimated BHP from shut in data (CT stopped) = 3430 psi = EMW of 1 0.8ppf at 6100 ft TVD 20:40 - 21:10 0.50 CASE C RUNPRD RIH. Tagged at 8658', No P inc, SD pump, PU SW = 28k 21:10 - 21 :30 0.33 CASE X DPRB RUNPRD Trying to work through A5 shale at 8658 ft, Hard tag. Tried several times unable to pass. 21 :30 - 00:00 2.50 CASE X DPRB RUNPRD POOH, maintaining pressure schedule. Shut SSSV trapping 900 psi 8/22/2004 00:00 - 01 :00 1.00 CASE X DPRB RUNPRD OOH. Make ready to pull CSH inner string. Closed 2-3/8" combi, pull tested,OK, LD Deployment sleeve and 3-1" PJ 01 :00 - 01 :25 0.42 CASE X DPRB RUNPRD POOH standing back CSH 01 :25 - 02:15 0.83 CASE X DPRB RUNPRD POOH standing back 2-3/8" liner. Bottom shoe and PJ full of shale, splinted hard shale 02:15 - 03:15 1.00 CASE X DPRB RUNPRD PU FCO drilling BHA RR HTC BC bit with 1.1 deg Motor and CoilTrac 03:15 - 04:45 1,50 CASE X DPRB RUNPRD RIH with Drilling BHA for FCO. Stopped at 7695 ft 04:45 - 04:50 0.08 CONDHLX DPRB RUNPRD Tie-in at GR marker before going in window (-5ft) 04:50 - 05:15 0.42 CONDHL X DPRB RUNPRD RIH tagged at 8653 ft with motor work, PU = 23k 05:15 - 05:35 0.33 CONDHLX DPRB RUNPRD Inc Qp to 1.50 bpm and adjusted SHP to 3600 psi Vp = 370 bbl, 05:35 - 05:50 0.25 CONDHLX DPRB RUNPRD W/R to bottom, Washed through area at 1.5 bpm, no problem Took wt at 8691 ft fell through Orient TF, drilled at 180 deg at 8700 ft WR down to 8850 ft, clean after 8700 ft 05:50 - 06:00 0.17 CONDHLX DPRB RUNPRD Sack ream from 8850 ft to 8600 ft. Maintaining 3640 psi BHP 06:00 - 06:55 0.92 CONDHLX DPRB RUNPRD Hole conditions in shale are poor, Continue to ream. Couldn't run in past 8650'. Holding the TF as drilled toolface. Don't want to sidetrack here, Try RIH at 0.3 bpm, 0.5 bpm, 0.7 bpm, 1.5 bpm, 1.8 bpm. Continue working, and getting motor work Printed: 11/16/2004 2:57:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) Page 9 ~ BP EXPLORATION Operations Summary Report 1 Y-24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT Phase 8/22/2004 06:00 - 06:55 0.92 CONDHLX DPRB RUNPRD 06:55 - 07:15 0.33 CONDHLX DPRB RUNPRD 07:15 - 09:15 09:15 - 09:45 09:45 - 10:45 10:45 -11:35 11 :35 - 12:05 12:05 - 15:00 15:00 - 15:50 2.00 CONDHLX DPRB RUNPRD 0.50 CONDHL X DPRB RUNPRD 1.00 CONDHLX DPRB RUNPRD 0.83 CONDHLX 0.50 CONDHLX DPRB RUNPRD DPRB RUNPRD 2.92 CONDHLX DPRB RUNPRD 0.83 CONDHLX DPRB RUNPRD 15:50 - 19:30 3.67 CONDHLX DPRB RUNPRD 19:30 - 21 :30 I 2.00 CONDHLX DPRB RUNPRD Start: 8/1 0/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud. Date: 6/10/1993 End: 8/28/2004 Description of Operations at each set down. Ease in at 40 fph, 1.8 bpm. Maintaining 3600+ psi during all pump rates by adjusting surface choke. Drill down to 8660'. Tried RIH with pumps down at 180 deg out of drilled TF (11 OR), and also at high side orientation. Could not get thru. Return to Drilled TF (70L), and continue trying to work down thru shale. Consult town engineer. Trying to red rill hole holding same toolface. Trying to keep ROP higher than when hole originally drilled. Finally made it thru 5' bridge at 8660'. Continue reaming in hole. Set down at 8713'. Heavy pickups and motor work. finally got up hole to 8640'. RIH, set down at 8650'. Drop pump rate to 0.7 bpm, able to RIH slowly. Finally got all the way thru shale to 8800'. Whew! Continue to ream down and backream up thru shale. It seems to be getting slightly better each time. We can at least get up and down thru it now, but are getting some motor work both ways. Overpulls are not as bad. Catch a bottoms up sample for geologist. continue reaming from 8600'-8800'. Geologist caught a bottoms up sample from reaming in 8630-8750 interval. He reports that the cuttings look identical to the cuttings from when the original A5 interval was drilled. Continue to ream hole clean. Shale zone appears to have cleaned up. Very little cuttings over shaker. Able to run thru zone with a minimum of motor work or overpulls. Continue to ream for 1 additional hour to get it whistle slick. Make a total of 5 clean up and down round trips thru shale. No motor work or overpulls on last 5 round trips. It won't get any cleaner than this. Continue RIH. Tagged up at 9550'. No cuttings on shaker More problems in this shale. Ream/Backream. Motor work at 9590,9610,9613. Work interval 9625'-9400'. Momentarily stuck on first up pass. Managed to get free and continue reaming. Motor work and overpulls on up reaming pass. Started getting cuttings again. Looks like we are drilling from the cuttings coming over the shaker. Ream up and down 9625'-9400' to condition shale. Bad at first with motor work and overpulls, but getting better on each pass up and down. Ream up and down. Lots of cuttings, and some packing off on up reaming trips. RIH, got down to 9890' easily. Pump 20 bbl high vis sweep, and chase it up hole. Catch a sample for geologist when sweep returns to surface. Got more cuttings out when sweep got to surface. Geo reports cuttings sample showed the cuttings to be from the A5 shale that is open from 8650'-8775'. Ream shale at 9625'-9400' one last time prior to POOH. Pump another 20 bbl high vis sweep. POOH Pulled 43k at 8692 ft "bit stuck", reduced Qp closed in well. pulled free at 8615 ft Open choke, 300 psi WHP. PUH to 8550 ft. Talked to town. "Sidetrack" POOH for OH sidetrack. DD set KOP at 8540 ft with 24deg DLS Conducted PJSM with crews on way forward Plan approved by town with some TVD changes/targets along Printed: 11/16/2004 2:57:54 PM ) -~) Page 108 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/22/2004 8/23/2004 1 Y -24 1Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To Hours Task Code NPT Phase 19:30 - 21 :30 2.00 CONDHLX DPRB RUNPRD 21 :30 - 22:50 1.33 DRILL C PROD1 22:50 - 00:00 1.17 DRILL C PROD1 00:00 - 00:05 0.08 STKOH C PROD1 00:05 - 00: 15 0.17 STKOH C PROD1 00: 15 - 00:50 0.58 STKOH C PROD1 00:50 - 01 :20 0.50 STKOH C PROD1 01 :20 - 01 :55 0.58 STKOH C PROD1 01 :55 - 03:05 1.17 STKOH C PROD1 03:05 - 04: 10 1.08 STKOH C PROD1 04:10 - 04:40 0.50 STKOH C PROD1 04:40 - 05:15 0.58 STKOH C PROD1 05:15 - 06:00 0.75 STKOH C PROD1 06:00 - 09:30 3.50 STKOH C PROD1 09:30 - 11 :00 1.50 STKOH C PROD1 11 :00 - 12:00 1.00 STKOH C PROD1 12:00 - 13:00 1.00 STKOH C PROD1 13:00 - 13:15 0.25 STKOH C PROD1 13:15 - 13:20 0.08 STKOH C PROD1 13:20 - 15:30 2.17 STKOH X DPRB PROD1 15:30 - 16:30 1.00 STKOH X DPRB PROD1 16:30 - 18:35 18:35 - 18:50 2.08 STKOH X 0.25 STKOH X DPRB PROD1 DPRB PROD1 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Description of Operations the way PU BHI CoilTrac with 1.5 deg motor, scribe and test tool. Ordered 450 bbl 9.6ppg with 5% L T and 10 ppg KGard mud RIH, equalized pressure, open EDC RIH to 7690 ft for tie-in Tie-in at GR at 7678 ft. (Corrected -7 ft) Close EDC, RIH through window. Set down in high DLS sections at 7990 ft and 8066 ft. PU and went through. Orient TF 180deg. Adjusted BHP to 3600 psi, EDC = 11.7ppg WHP =300 psi. OH ST trough at 40 fph from 8520 ft to 8540 ft Q= 1.5/1.55 bpm EDC = 11.7ppg . Vpi = 354 bbl PUW = 23k PUH to 8520 and ream trough again at 40 fph Start sidetrack at 1 fph BHP = 3626 psi EDC = 11.61 ppg, WHP = 313 psi, Density = 8.7/8.7ppg Start sidetrack at 2 fph Getting WOB, "Soft sand". Drilled at 1 00 fph in original hole through this section, BHP = 3626 psi EDC = 11.61 ppg, WHP = 303 psi, Density = 8.7/8.7ppg Started to push at 10 to 20 fph At 8547 ft getting .4k on bit, believe were're ST Vp =353, WHP = 304 psi/BHP= 3628 psi at 11.62 ppg EDC Sidetracked, WOB increasing and looking for the first good ST survey. Turning TF 133L at 8553 ft. Not sidetracked at 8577 ft NB angle showing climb, old hole PUH to 8520 ft and work the trough again. Start second sidetrack. Trough hole from 8480'-8540' at 20 fph. TF=180 deg. Making fluid swap to 9.6 ppg mud. Cleaning pits. Holding 3600 psi BHP while making mud swap. Trough down at 36 fph from 8480'-8540'. TF=180 deg. Well swapped to new fluid. Pit vol=359 bbls. Still taking on mud to pits. Begin time drilling at 8540' at 0.1 '/6 minutes. Free spin=4030 psi at 1.52 bpm. Pit vol=382 bbls, IAP=350 psi, OAP=O psi. WOB = -0.28 Begin time drilling at 2 fph. Free spin=3980 psi. Pit Vol=381 bbls. IAP=372 psi, OAP=O psi. WOB = -0.27 Begin time drilling at 3 fph. WOB = -0.2. Not seeing any WOB at all. Don't think that we are getting a sidetrack started. Consult with town. Increase ROP to 12 fph to see if we start to get WOB, No change in weight on bit. No lip started. Pull OOH to adjust motor AKO to 2,6 deg. Tag up with BHA #8. Check R60 sidetracking bit. Looked perfect, no obvious wear. Graded 1,1. Lay down motor (75 hours). Pick up new motor, and rerun same bit. Motor adjusted to 2.6 deg. RIH with BHA #9. R60ST bit, 2.6 deg motor. Tie-In at GR marker at 7678 ft ELMD( -5 ft Correction). Close Printed: 11/16/2004 2:57:54 PM ') ) BP EXPLORATION Operations Summary Report Page 11 418 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y -24 1 Y -24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Date From - To Hours Task Code NPT Phase Description of Operations 8/23/2004 18:35 - 18:50 0.25 STKOH X DPRB PROD1 EDC 18:50 - 19:45 0.92 STKOH X DPRB PROD1 Set down at 8059 ft PU Tried several TF, Drilled at 2.8 bend orginallyat 60R TF. Poked around with 2.6 deg in all 4 quantants. Mainly set TF from HS to 90 R an unable to get below 8060 ft, Tool offset looks correct from well geometry. 19:45 - 21 :20 1.58 STKOH X DPRB PROD1 PUH above window, open EDC, POOH adjusting BHP as per schedule. 21 :20 - 22:25 1.08 STKOH X DPRB PROD1 OOH, checked flow, R-60 3 broken gauge inserts. PU STR 324 PHC and set motor to 2.3 deg 22:25 - 00:00 1.58 STKOH X DPRB PROD1 RIH, open EDC, equalize pressue at 500 psi. 8/24/2004 00:00 - 00:05 0.08 STKOH X DPRB PROD1 RIH 00:05 - 00:25 0.33 STKOH X DPRB PROD1 Tie-in at GR maker at 7678 ft, Corrected -5 ft. Close EDC 00:25 - 00:45 0.33 STKOH X DPRB PROD1 RIH "We did it, ran past 8049 ft and 8059 ft. RIH 00:45 - 00:50 0.08 STKOH X DPRB PROD1 Stopped at 8500 ft, inc Qp to 1.7 bpm. Open choke 100%, BHA Set TF at 140R 00:50 - 02: 15 1.42 STKOH C PROD1 Starting trough with 2.3 motor & STR 324 at 8500 ft at 30 fph TF = 136R Q= 1.56/1.57 bpm CP = 3831 psi BHP = 3875 psi ECD = 11.81 ppg, Choke 100%, No WOB seen on 1 st run 02: 15 - 03:50 1.58 STKOH C PROD1 Starting trough 2nd time at 8500 ft at 30 fph TF = 136R Q= 1,56/1.57 bpm CTP = 3825 psi BHP = 3877 psi. ECD = 11.81ppg, Choke 100% 03:50 - 05:00 1.17 STKOH C PROD1 Time drill at 8540 ft @ 1 Omin/0.1 ft Q= 1.55/1.56 bpm CTP = 3823 psi BHP = 3879 psi. ECD = 11.78ppg, Choke 100%, Reviewing other ST ops in the hole. Presented revised ST to Geo and they approved. Orginal well was drill 8317 ft HS to 8347 ft 05:00 - 05: 15 0.25 STKOH C PROD1 PUH to 8300 ft to start ST trough 05: 15 - 06:00 0.75 STKOH C PROD1 Orient TF to 180deg, Drilling trough from 8300 ft to 8330 ft at 30 fph Q= 1.56/1.57 bpm CTP = 3825 psi BHP = 3877 psi. ECD = 11.81 ppg, Choke 100% Seeing inc in Qp 30 to 40 psi on 1st pass. 06:00 - 06:20 0.33 STKOH C PROD1 Continuing to trough from 8300'-8330' at 30 fph. WOB = -0.2 klbs. Pit vol=370 bbls. IAP=304 psi, OAP=O psi. BHP=3670 psi. 06:20 - 07:50 1.50 STKOH C PROD1 PU 30' to 8300', begin second down trough at 30 fph. 07:50 - 09:20 1.50 STKOH C PROD1 PU to 8295', begin down trough at 30 fph. 09:20 - 09:50 0.50 STKOH C PROD1 Stop coil and drill stationary at 8330' for 112 hour. 09:50 - 11 :00 1.17 STKOH C PROD1 Begin time drilling at 1.0'/hr for 1 hour. 11 :00 - 12:50 1.83 STKOH C PROD1 Looked like we may have been stacking weight (Not sliding). PU and RIH to the same spot. Begin time drilling at 2,0 fph. 12:50 - 13:45 0.92 STKOH C PROD1 Begin time drilling at 3.0 fph. 13:45 - 14:05 0.33 STKOH C PROD1 PU and ream down to 8336'. 14:05 - 16:05 2,00 STKOH C PROD1 Time drill at 3.0 fph for an additional 3'. Still no sign of taking weight. 16:05 - 16:45 0.67 STKOH C PROD1 PU and ream back down to 8341'. 16:45 - 17:45 1.00 STKOH C PROD1 Time drill at 3.0 fph for an additional 3'. Near bit inclinometer will pass KO point of 8330' during this 3' interval. Still no sign of WOB. 17:45 - 18:30 0.75 STKOH X DPRB PROD1 Ream/backream trough area at 180 TF and slow ream down to 8344' and hope there is a ledge 18:30 - 19:30 1.00 STKOH X DPRB PROD1 Drill ahead at 5'/hr 1.55/3980/180R wi no diff or wt, DHP 3680, Printed: 11/16/2004 2:57:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ) ) Page 12118 BP EXPLORATION Operations Summary Report 1 Y -24 1 Y -24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To Hours Task Code NPT Phase 8/24/2004 18:30 - 19:30 19:30 - 20:00 20:00 - 20: 15 20:15 - 21:00 21 :00 - 22:45 8/25/2004 22:45 - 23:30 23:30 - 00:00 00:00 - 03:00 03:00 - 04:00 04:00 - 05:35 05:35 - 06:00 06:00 - 06:30 06:30 - 07:45 07:45 - 09:00 09:00 - 11 :30 11:30-12:15 12:15 - 12:30 12:30 - 13:30 13:30 - 15:00 15:00 - 15:30 15:30 - 15:40 15:40 - 18:20 18:20 - 18:50 1.00 STKOH X 0.50 STKOH X 0.25 STKOH X 0.75 STKOH X 1.75 STKOH X 0.75 STKOH X 0.50 STKOH X 3.00 STKOH X 1.00 STKOH X 1.58 STKOH X 0.42 STKOH X 0.50 STKOH X 1.25 STKOH X 1.25 STKOH X 2.50 STKOH X 0.75 STKOH X 0.25 STKOH X 1.00 STKOH X 1.50 STKOH X 0,50 STKOH X 0.17 STKOH X 2.67 STKOH X 0.50 STKOH X DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DPRB PROD1 DPRB PROD1 Start: 8/1 0/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Description of Operations ECD 11.8 and watch NB incl show no change Incr penetration rate to 30'/hr and still no diff or wt incr and no change in inclination Discuss and will set aluminum WS Wiper to 8550' was clean Wiper to window. 8050' was clean, but had MW and 5k overpull at 8000'. Continue wiper to window, clean. Wiper in hole to 8100' and had MW and wt loss at 8062'. Wiper back to window and had minor MW at 7995', continue wiper to window, clean Open EDC, POOH following revised pressure schedule 1.6/3600. Overpull at GLM #5. Close SSSV LD BHI BHA. Cut off CTC Reverse slack RU and cut 50' CT, Rehead. PT 30k. Install CTC. PT 3500 psi MU WI! 2-1/2" aluminum WS. MU BHI BHA RIH w/ BHA #11following pressure schedule. Open open SSSV wi 500 psi Log tie-in down from 7690', corr -7' RIH. Set down at 8056'. Work BHA several times. Apply up to 1500# down wt. No overpull at pick up. Vary running speed. Unable to get past "ledge". Discuss options with team. Position TOW at 8000'. Close EDC. Pressure coil to 4900 psi several times. No shear observed. Circulating at 1.3 bpm, where rate should be near zero before setting tool shears. Repeat several times. RIH to 8030'. WS not taking any weight. POOH to inspect setting tool and other BHA components. Call for 2nd setting tool & WS assembly to be delivered. Close SSSV. Continue to POOH to surface. At surface. Get off well. Unstab coil. WS not recovered. Setting tool appears to have stroked properly. Setting rod end and sleeve show no sign of damage. Discuss options with town team et al. 2nd WS assembly ready to go. MU 2nd Weatherford aluminum billet assembly. Verify tool has weep hole and not ball seat. Stab coil. Get on well. RIH to SSSV. Pressure well to 450 psi. Open SSSV. No change in WHP. Continue in hole as per pressure schedule, Circ at 1,5 bpm /3550 psi with ECD open, Log gr tie in from 7690'. Subtract 7' correction. Stop with top of billet at 7975', Close EDC. Hold 350-400 psi WHP. Pressure coil slowly to 4800 psi. Shut-in. Pressure dropped off sharply after 10-20 seconds. Appears tool stroked. Set down 3K# surface wt, 6k BHI wob. WS taking weight. POOH. Open EDC. Maintain WHP as per schedule. Hang up in tbg tail at 7681'. Work pipe. Pull through. Continue to POOH. Hang up in nipple at 7171', Pull through at 20K over (39k#). Continue to POH. Close SSSV and check for flow during crew change LD BHI BHA. LD WS setting assy (no abnormalities) Printed: 11/16/2004 2:57:54 PM ) ") BP EXPLORATION Operations Summary Report . 13'" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y-24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Date From - To Hours Task Code NPT Phase Description of Operations 8/25/2004 18:50 - 19:25 0.58 STKOH X DPRB PROD1 MU kickoff assy 19:25 - 20:40 1.25 STKOH X DPRB PROD1 RIH wi BHA #13 (2.1 deglused STR 324 from prior run). Open SSSV to 500 psi. RIH following modified pressure schedule while circ thru EDC 0.3 bpm 20:40 - 21 :20 0.67 STKOH X DPRB PROD1 Tag up at 7178' CTD (assume 2.812" W-1landing nipple, or Baker PBR or FHL packer in same area) at 95'/min. Use orientor to try to get by while rotating 360 deg wlo success. Close EDC and try cycling pump wi It wt at different orientations wlo success. Try all other tricks and set down at the same spot every time. Discuss 21 :20 - 22:45 1.42 STKOH X DPRB PROD1 POOH following pressure schedule thru open EDC 1.4 bpm. Close SSSV 22:45 - 23:35 0.83 STKOH X DPRB PROD1 Chk bit and had no chipped cutters, but one small sliver of metal. All four PDC backups on taper were 'shiney' (like aluminum) Adjust motor to 0.6 deg and MU 2.74" used window mill and SR 23:35 - 00:00 0.42 STKOH X DPRB PROD1 RIH wi BHA #14. Open SSSV to 500 psi. RIH following pressure schedule while circ thru mill at 0.4 bpm 8/26/2004 00:00 - 00:50 0.83 STKOH X DPRB PROD1 Continue RIH at normal speed until set down at 7178'. Try three more attempts at high speed after rotating TF 90 deg each attempt and set down full wt at the same place. Assume this is the top of 2nd WS based on events from previous day at 1540 hrs and elect not to drill it at this time 00:50 - 02:20 1,50 STKOH X DPRB PROD1 Log CCL up from 7178' to 6000' at 30'/min while discuss. Log GR down from 6540' to 6630' Discussions determine that the best course of action is to perform diagnostics with slickline 02:20 - 03:45 1.42 STKOH X DPRB PROD1 POOH following pressure schedule while circ thru open EDC at 1.3/3400. Close SSSV 03:45 - 04:30 0.75 STKOH X DPRB PROD1 Set injector on legs. LD milling BHA. No new marks or aluminum on mill 04:30 - 06:30 2.00 STKOH X DPRB PROD1 WO slickline unit (no 24 hr crews) Est AOL at 0615 hrs 06:30 - 06:50 0.33 STKOH X DPRB PROD1 Hold PJSM with Halliburton & CTD crews in dog house. Discuss safety issues, safe area, rig up, and general job procedures. 06:50 - 09:30 2.67 FISH X DPRB PROD1 RU Halliburton slickline unit. Bring lubricator into pipe shed. BOPS up slide to rig floor. RU lubricator & LIB tool string. Press test to 1500 psi. Ok. Open well. Pressure WHP to 500 psi. Open SSSV. 09:30 - 10:45 1.25 FISH X DPRB PROD1 RIH with2.25" od LIB. Tag fish at 7172' SLM. POOH. 10:45 - 11 :00 0.25 FISH X DPRB PROD1 Inspect LIB, Looks like it sat down on a 2.25" id "ring". This would correspond with outer shroud on top of WS. 11 :00 - 12:45 1.75 FISH X DPRB PROD1 RIH with 1,5" od, centralized LIB. Hold 500 psi WHP. Tag fish at 7172'. POOH. Shut in well with 500 psi. Get off well. 12:45 - 13:00 0.25 FISH X DPRB PROD1 Inspect LIB. Not conclusive. Looks like we sat down on a small irregular piece of junk (1/4" x 1/4"), possibly sitting on top of fish neck. 13:00 - 14:45 1.75 FISH X DPRB PROD1 Get on well. Pressure lubricator to 500 psi. Open swab & master. RIH with 2.49" ad LIB. Tag fish at 7172'. POH. Shut in well wI 500 psi. Get off well. 14:45 - 15:15 0.50 FISH X DPRB PROD1 Inspect LIB. Same junk markers near center of LIB. No indication of billet fish neck. Printed: 11/16/2004 2:57:54 PM ) ') BP EXPLORATION Operations Summary Report Page 14'" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y -24 1 Y -24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Date From - To Ho u rs Task Code NPT Phase Description of Operations 8/26/2004 15:15 - 17:00 1.75 FISH X DPRB PROD1 Get on well. Pressure up to 500 psi. RIH with pump bailer. Bail & POH. Hold 500 psi WHP. Get off well. 17:00 - 17:30 0.50 FISH X DPRB PROD1 Two small aluminum chips & one small metal chip recovered. Discuss options with town. 17:30 - 18:00 0.50 FISH X DPRB PROD1 RD Halliburton slickline unit. 18:00 - 19:10 1.17 FISH X WAIT PROD1 WO WI! tattle tale assy 19:10 - 19:45 0.58 FISH X DPRB PROD1 MU WI! tattle tale tool on BHI BHA 19:45 - 20:55 1.17 FISH X DPRB PROD1 RIH wi BHA #15 folowing pressure schedule, circ thru EDC 0.8/2430. Open SSSV to 500 psi 20:55 - 21 :15 0.33 FISH X DPRB PROD1 7100' 18.5k Close EDC RIH 15'/min 5.6k 1.58/3800 to first wt loss at 7176' and gained 160 psi and lost 5k wt by 7177.4', PUH 17.6k, clean. Ease back down and see press incr at 7176.2' and stack 7k surface, 6.5k BHI. Stack 11 k surface, 6.8k wob to 7179.7'. No additional press incr, no movement. PUH 17.6k, clean. Open EDC 21 :15 - 23:00 1.75 FISH X DPRB PROD1 POOH following pressure schedule. Close SSSV 23:00 - 00:00 1.00 FISH X DPRB PROD1 LD tattle tale assy. No fresh obvious marks anywhere and tattle tales were still intact. However, at the start of the inside bevel there was a faint wearlset down mark on all 4 edges. WF caliper FN on backup WS and verify tool is correct size. Discuss. Will run this tool again on a motor-appears we needed to be a little more aggressive 8/27/2004 00:00 - 00:30 0.50 FISH X WAIT PROD1 WO XO from tool to motor 00:30 - 01 :00 0.50 FISH X DPRB PROD1 MU OH WS tattle tale assy on BHI straight motor and BHA 01 :00 - 02:35 1.58 FISH X DPRB PROD1 RIH wi BHA #16 following pressure schedule while circ thru EDC at 0.4/2100. Open SSSV with 500 psi 02:35 - 03:20 0.75 FISH X DPRB PROD1 Tag at 7178' at normal running speed twice and stack full wt. PUH 18k, close EDC. Start pump 0.5/2000 and ease down to first MW at 7176.1' and park. Diff increased 200 psi over 5 min and stabilized. PUH 18k, clean. Ease back down to first MW at 7176.0' and diff increased 200 psi. Gradually slack off and had 2k wobat 7176.4' wI 250 psi diff, 3.4k wob at 7176.8' wi 330 psi diff. Stack full wt and had 400 diff at 7178.0' and assume motor may be stalled at this low flow rate. Elect to not washover further with this assy 03:20 - 04:50 1.50 FISH X DPRB PROD1 POOH following pressure schedule while circ thru EDC 1.4/3200. Close SSSV 04:50 - 05:15 0.42 FISH X DPRB PROD1 LD tattle tale assy. Tattle tales still intact. Had worn concentric inner and outer rings on end of nozzle assy 05:15 - 05:45 0.50 FISH X DPRB PROD1 MU BTT 6' burnover shoe assy on BHI straight motor 05:45 - 07:30 1.75 FISH X DPRB PROD1 RIH wi BHA #17 following pressure schedule while circ thru EDC 0.5/2020. Open SSSV to 500 psi. Dry tag fish at 7175'. 07:30 - 08:30 1.00 FISH X DPRB PROD1 Miil over fish, 3640 psi fs @ 1.48 bpm. Mill from 7175.2' to 7178.5'. 400-500 psi mtr work. WOB: 1.0-,20K#. No stalls. Easy milling, Lots of aluminum back over shakers, 08:30 - 09:30 1.00 FISH X DPRB PROD1 CBU until aluminum cuttings clean up, Shut in well. Open ECD. 09:30 - 11 :00 1.50 FISH X DPRB PROD1 POOH with wash shoe assembly. Maintain WHP as per schedule to keep +1- 11.5 ppg on formation. Close SSSV. Continue to surface, 11 :00 - 11 :30 0.50 FISH X DPRB PROD1 Get off well. Unstab coil. LD BHA. Inspect shoe. 11 :30 - 12:30 1.00 FISH X DPRB PROD1 Wait on tattle tale tool to be modified. 12:30 - 12:45 0.25 FISH X DPRB PROD1 Hold rig evacuation drill. All hands report to Tech Limit shack. Printed: 11/16/2004 2:57:54 PM ) ) Page 15"- BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y -24 1 Y -24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To Hours Task Code NPT Phase ~- 8/27/2004 12:45 - 13:30 0.75 FISH X DPRB PROD1 13:30 - 15:30 2.00 FISH X DPRB PROD1 15:30 - 16:00 0.50 FISH X DPRB PROD1 16:00 - 17:30 1.50 FISH X DPRB PROD1 17:30 - 18:15 0.75 FISH X DPRB PROD1 18:15 - 18:30 0.25 WHSUR P OTHCMP 18:30 - 19:15 0.75 WHSUR P OTHCMP 19:15-20:30 1.25 WHSUR P OTHCMP 20:30 - 22:45 2.25 WHSUR N FLUD OTHCMP 22:45 - 23:30 0.75 WHSUR P OTHCMP 23:30 - 00:00 0.50 WHSUR P OTHCMP 8/28/2004 00:00 - 01 :45 1.75 WHSUR P OTHCMP 01 :45 - 02:00 0.25 WHSUR P OTHCMP 02:00 - 03:15 1.25 WHSUR P OTHCMP 03:15 - 05:15 2.00 WHSUR P OTHCMP 05:15 - 07:00 1.75 BOPSUPP WHDTRE 07:00 - 09:00 2.00 DEMOB P POST 03:00 - 05:00 2.00 MOB P PRE 05:00 - 10:00 PRE 9/30/2004 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Description of Operations MU modified tattle tale on straight motor. Stab coil. Get on well. RIH with BHA. Maintain WHP as per schedule. Set down 3K# on fish at 7178' with tattle tale tool, pumps off. PU. Close EDC. Circ at 1.0 bpm. Set down on fish again rotating with motor, 3K#. PU. Open EDC. POOH with tattle tale tool. Maintain WHP as per schedule. At surface. Get off well. Unstab coil. Inspect tattle tale-no new marks, TT's still intact. Appears as if FN is larger than I D of tool so assume FN must be damaged Discuss. Receive orders to end operations Fish is 2-1/2" WI! OH WS 13.4' OA length (w/ slips). TOF is at 7178' CTD which is near W-1 nipple and PBR/Packer area. Top 3' of aluminum WS has been burned down to 2.1" OD. Assume WS slips are set in PBR/Packer area Safety mtg re: plan ahead MU nozzle assy BHA Order vac trucks and fluids RIH following pressure schedule while circ thru nozzle at 0.6 bpm. Open SSSV with 500 psi Tag TOF at 7177.7' and circ 1.75/3900 while WO seawater and empty vac trucks to offload mud. Begin offloading trucks hauling rig mats Displace mud with seawater from 7178' POOH following revised pressure schedule while fin displ to seawater Fin POOH to 2000'. Swap to diesel and circ diesel to surface, close SSSV w/ 630 psi. Close tree valves MIRU DS N2 Safety mtg re: N2 PT DS @ 4000. Displ CT w/ N2 and bleed off Safety mtg re: pull CT back LD nozzle assy. Remove BHI head. Cut off CTC. Dress stub and intall internal grapple and PT. Pull CT to reel and secure. Lower onto lowboy. Reel was removed for weight ND BOPE. NU tree cap. Test same. Continue to clean pits. Move upright & cuttings tanks. Lay mats on pad. Move camp to 1 D pad. Release rig at 0900 hrs. RREL from 1F-18 at 0300 hrs Move rig to entrance of 1 F Pad on prelayed mats conditions still soft eventhough it is snow' â there is 2" on the ground) Wait for around 200 ri s to be layed on 1 F access road, Will move f over all, then backup on doubled mats and re single layer ahead of rig for the 2.9 miles of road since only one way in/out. Using same procedure as rig was moved Pad Moving 1 F pad toward Spine Road. Continue move Spine Road intersection. Continue moving using rig on 1 F pad access road. Continue moving on access road. 'mately 1/3 mile from Spine intersection at 1800 hrs. Printed: 11/16/2004 2:57:54 PM ) ") Well: Field: API: Permit: 1Y-24A & 1Y-24AL 1 Kuparuk 50-029-22371-01-00 / -60-00 204-125 & 204-126 Accept: 08/16/04 Spud: 08/17/04 Release: 08/28/04 Rig: Nordic #2 Accept: 10/01/04 Spud: 10/07/04 Release: 10/18/04 Rig: Nordic #2 NORDIC #2 MOVED ON FROM 08/16/04 TO 08/28/04 - OPERATIONS SHUTDOWN 09/03/04 TAGGED TOP OF FISH AT 7184' DRILLERS DEPTH. THE TOP IS FOUR FEET BELOW THE TOP OF THE PBR. HAD TO OPEN SSSV BY PRESSURING UP ON TUBING TO 750 PSI. WELL FLUID PACKED WITH DIESEL TO 1980' ELMD AND SEAWATER BELOW. WELL LEFT SHUT IN. 09/11/04 WASHED OVER FISH AT 7150.2' CTMD APPROX. 5", (ONE BRASS TATTLE TALE BROKEN OFF). 18 STALLS TOTAL, ON LAST STALL WITNESSED AN 8,000# OVERPULL. REDRESSED HYDRAULIC OVERSHOT FOR SHORT CATCH. INJECTOR HEAD PROBLEMS STOPPED US FROM CONTINUING TODAY. 09/12/04 LOCATED TOP OF FISH AT 7153.8' CTMD. LATCHED FISH AND BEGAN JARRING OPERATIONS. JAR LICK COUNT AT 52. 5 EACH AT 24K, 5 EACH AT 28K, 10 EACH AT 32K, 23 EACH AT 36K. 10 DOWN LICKS AT- 5K, TOTAL MOVEMENT = 20' ON BOTH MAN-DIGITAL COUNTERS. ATTEMPTED SEVERAL TIMES TO DISCONNECT. 09/13/04 RAN CCL AND TAGGED TOP OF FISH AT 7171' - DEPTH OF THE W-1 LANDING NIPPLE. 09/16/04 LATCHED INTO PRE-BAITED FISH AT 7171' (ELMD) 7147' CTMD WITH QT1200 HIGH STRENGTH CT, 85 CYCLES OVER THE GOOSE NECK, 75 AT MAXIMUM WEIGHT (60,000#), PULLED 25-30,000# OVER STRING WEIGHT WITH JARRING ACTION. 40-45,000# OVER STRING WEIGHT STRAIGHT PULL. NO MOVEMENT OF FISH. TAGGED AT 7148' CTD. 09/23/04 TAGGED FISH AT 7172' RKB. MEASURED BHP AT 7167' RKB: 2784 PSI. LOCKED OUT TRDP AT 1793' RKB, NEEDS SECOND PUNCH. ATTEMPTED INJECTIVITY TEST, TUBING HELD 1000 PSI WITH VERY SLOW BLEED OFF. (IN PROGRESS.) 09/24/04 PULLED DV AT 7126' RKB. PERFORMED SECOND PUNCH ON TRDP AT 1793' RKB, CLOSURE TEST FAILED, TRDP LOCKED OUT. 09/26/04 SET WEATHERFORD WRP IN 3.5" TUBING AT 7155' IN FIRST FULL JOINT ABOVE TOP OF FISH. BLED DOWN TUBING AFTER SETTING WRP FROM 600 PSI TO 300 PSI. PLUG APPEARS TO BE HOLDING. TAGGED TOP OF FISH AT 7170'. 09/29/04 PRESSURE TESTED WRP TO 1500 PSI (HELD GOOD). LOADED WELL WI 248 BBLS OF 10.5# BRINE (KWF), PUMPING DOWN THE TUBING TAKING RETURNS FROM IA TO THE FACILITY. OBTAINED SAMPLES OF KWF FROM BOTH THE TUBING AND lA, BLED SAME TO 0 PSI. ) ') Page 16- BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y-24 1 Y -24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/1 0/2004 Rig Release: 8/28/2004 Rig Number: 2 Date From - To Hours Task Code NPT Phase -.---.-----.-------"--- 10/1/2004 i 00:00 - 06:00 6.00 MOB P PRE I 106:00 - 15:00 9.00 MOB P PRE I í \15:00-17:20 2.33 MOB P PRE 17:20 - 20:00 2.67 MOB P PRE 20:00 - 20:20 0.33 MOB P PRE 20:20 - 21 :00 0.67 MOB P PRE 21 :00 - 00:00 3.00 RIGU P PRE 10/2/2004 00:00 - 01 :50 1.83 RIGU P PRE 101 :50 - 02:00 0.17 BOPSUPP PRE 02:00 - 03:05 1.08 BOPSUP P PRE 03:05 - 03:15 0.17 BOPSUPP PRE 03: 15 - 04:00 0.75 BOPSURP PRE 04:00 - 05:15 1.25 BOPSUP P PRE 05:15 - 07:00 1.75 BOPSUPP PRE 07:00 - 12:30 5.50 BOPSUP P PRE 12:30 - 13:00 0.50 BOPSUP P PRE 13:00 - 16:00 3.00 BOPSUP. N SFAl PRE 16:00 - 17:00 1.00 BOPSUP N SFAL PRE 17:00 - 23:00 I 6.00 BOPSUP P PRE 23:00 - 00:00 1.00 WHSUR P DECOMP 10/3/2004 00:00 - 02:00 2.00 WHSUR N DECOMP 02:00 - 03:00 1.00 WHSUR P DECOMP 03:00 - 03: 15 0,25 WHSUR P DECOMP 03: 15 - 03:35 0,33 PUll P DECOMP 03:35 - 05:00 1.42 PUll P DECOMP 05:00 - 06:00 1.00 PUll P DECOMP 06:00 - 07:00 1.00 PUll P DECOMP 07:00 - 15:00 8.00 PUll P DECOMP 15:00 - 18:00 3.00 PUll P DECOMP Spud Date: 6/10/1993 End: 8/28/2004 Description of Operations ---.--.------ Continue with rig move on 1 F access road and arrive at the Spine road at 0600 hrs. WO crew change and morning shift traffic before laying mats on Spine and resuming move. Also PU extra mats and take to 1 Y Pad and begin setting mats on the Pad Enter Spine and make a quick 3 mile move to 1 Y Pad Park on access road to back Pad while continue to lay mats on back Pad up to well. Pick up mats on Spine and shuttle to Pad. Install 7-1/6" double gate to bottom of TOT stack. PJSM prior to moving over well. Move last 100 yds and move onto well. Accept rig at 2100 hrs. Rig up out buildings. Set-in upright and Tiger tanks. R/U to circulate well with 10.5ppg brine. Continue RU. Offload 290 bbls 10.5ppg brine. PT circulation lines to 3500 psi. Open well, no pressure. Circulate bottoms up at 4bpm. Monitor well for flow. Dead. RD circulation lines. Make up and set BPV, Test to 1 000 psi from below. NO Production tree and load out for inspection and redressing. Fin MU stack and get measurements for test jt. Swap lower rams to put 3-1/2" in top set and 4. in bottom set. NU BOPE. NU riser, replace boot in riser Tubing and accessories AOl APC fin berm and set tanks load out rig mats. Move camp from front Pad and park in normal spot Function test rams. Fill stack and body test. leaked thru blanking plug and IA ended up w/ 400 psi Begin loading pipeshed w/3-1/2" tubing Bleed off press. WO FMC. Remove test jt. Try a few tricks. Pull blanking plug-nothing obvious WO FMC to get parts and/or another blanking plug. Changed out ball and worked Fin load 3-1/2" tubing in pipeshed BOPE test. 250/4500psi Witness waived by AOGCC Pull FMC blanking plug, Pull BPV. Had problem with jointed puller lining up properly. PIU 4" elevators and landing joint. MU circulating line. PJSM review plan forward for pulling hanger to rig floor. Block wt = 8k, String wt in 10.5ppg brine 62k. Pull to 70k and continue wt increase, Seals released at 105k. Pull hanger to floor level. Fluid level +/-10' below wellhead. Circulate at 4bpm w/ full returns, Same time clear floor and R/U Camco spooler equipment. RD circulation equipment. lD landing jt and breakout 4. hanger. Prep to lD 4. tbg. load completion jewelry in pipeshed LD 4898' 4. 11 # J-55 DSS-HTC(AB) R2 tubing w/ Camco 4. TRDP SSSV and pups, Merla GlM #5 wI pups. Recovered 25 of 32 reported SS bands RU and standback 35 stds 3-1/2" 9.3# J-55 EUE8Rd R2. Find that collars are pitted fairly good (on low side). WO Kuparuk Printed: 11/1612004 2:57:54 PM ) ) BP EXPLORATION Operations Summary Report Page 17~ Legal Well Name: 1 Y-24 Common Well Name: 1 Y -24 Spud Date: 6/10/1993 Event Name: REENTER+COMPLETE Start: 8/10/2004 End: 8/28/2004 Contractor Name: NORDIC CALISTA Rig Release: 8/28/2004 Rig Name: NORDIC 2 Rig Number: 2 From - To Hours Task Code NPT Phase Description of Operations -- ------ 10/3/2004 15:00 - 18:00 3.00 PULL P DECOMP RWO specialist. Evaluate and decide to replace collars when RBIH. Fin stand back 3-1/2" J-55. Total of 70 jts. Remaining is 1 single and PBR's seal assembly to breakdown. 18:00 - 18:10 0.17 PULL P DECOMP PJSM with new crews. Review hazards and plan forward. 18:10 - 18:25 0.25 PULL P DECOMP Start to make break on the last full joint and PBR seal assembly. (Seal assembly contains stuck Weatherford OHWS and tbg jt contains a Weatherford RBP) Crews noticed this connection was wet and also possibly held trapped pressure. This was reviewed in the PJSM. Crews wrapped the connection with Herculite and absorb while the pressure was bleeding down. Useing the Eckel tongs one more round was backed out of the connection and the connection parted due to the remaining trapped pressure. No injuries were incurred. Thick 1 oily fluid sprayed on the front of the 3 rig hands working the I area. Safety glasses prevented any fluids entering the eyes. I 18:25 - 21 :00 2.581 PULL N DECOMP Called HSE field advisor and town engineer. Cleaned up the rig hands and the rig floor. Paided special attention to face areas to be sure all residual fluids were completely washed off with soap and water. No adverse affects to righands. 21 :00 - 21 :30 0.50 CASE P DECOMP PJSM with all hands. Reviewed trapped presure incident, the I plan forward and running order for new 3-1/2" completion string. 21 :30 - 00:00 2.50 CASE P DECOMP Run 3-1/2" completion string. Useing 70jts of the pulled 3-1/2" J-55 tbg and replacing the collars on each one. Remaining 3-1/2" tbg is new L-80, 10/4/2004 00:00 - 04:20 4.33 CASE P DECOMP Continue running 3-1/2" completion string. Changeing out collars on first 70jts of re-run tbg. 04:20 - 08:30 4.17 CASE P DECOMP MU new 3-1/2" 9.3# L-80 EUE8Rd R2 tubing and GLM's from I pipe rack 08:30 - 09:40 I 1.17 CASE P DECOMP Install SWS (Camco 3-1/2" TRM-4E) safety valve. Change out I Camco spooler. Install control line and PT 09:40 - 12:10 I 2,50 CASE P DECOMP MU 3-1/2" 9.3# L-80 EUE8Rd R2 with control line installing SS bands on every other joint Sent seal assy and one full jt (wI WRP) to WII. Used borescope and saw WS anchor in seal assy confirming that no junk from OH WS was left in well 12:10 -13:15 1.08 CASE P DECOMP PU extra jt and see textbook entry into PBR. Determine spaceout pups and none needed. Close annular, PT IA to 550 psi and hold for 5 min to verify seals holding. Bleed off press. Swap to pump down tubing, PUH 52k to put seals above PBR 13:15 - 14:00 0.75 CASE P DECOMP Pump 16.7 bbls corrosion inhibitor FRW132 mixed in 10.5# brine and displace w/1 0.5# brine to leave in the IA above PBR 14:00-16:15 2.25 CASE P DECOMP MU last jt, tubing hanger wI XO, and landing jt. Install control line and test. RIH and land 27,50' below N2 RKB. Left landing jt in hanger as guide for WL. Left control line in stack pressured up (SSSV open) Used 35 SS bands. String wts before landing 54K up, 42k down 16:15 - 17:30 1.25 CASE P DECOMP Safety mtg: RU and run WL AU HES slickline unit. MU tool string and strip thru TIW valve on landing jt 17:30 - 21 :05 3.58 CASE P DECOMP Make drift run w/2.70. TS to 7826'. PIU TIP and set in Camco D nipple at 7211' WLM. R?D SL Printed: 11/1612004 2:57:54 PM ") ') Page 184118 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y-24 1 Y -24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT Phase 10/4/2004 2.17 CASE ( I 21 :05 - 23:15 DECOMP 23:15 - 00:00 0.75 CASE IP DECOMP 10/5/2004 00:00 - 02:00 2.001 WHSURlp DECOMP 02:00 - 04:30 2.50 WHSUR P DECOMP 04:30 - 06:30 2.00' WHSUR P DECOMP 06:30 - 11 :00 4.50 BOPSUP P PRE 11 :00 - 15:00 4,00 BOPSUFt P PRE 15:00 - 16:30 1.50 WHSUB! P DECOMP ¡ I 16:30 - 17:30 1.00 WHSUB ¡ P DECOMP 17:30 - 18:30 1.00 WHSUR I P DECOMP I ! 18:30 - 20:00 1.50 PULL iN DPRB DECOMP 20:00 - 21 :00 1.00 PULL N DPRB DECOMP 21 :00 - 22:00 1.00 PULL P DECOMP 22:00 - 22: 10 0.17 DHEOP P DECOMP 22: 1 0 - 22:50 0.67 DHEOP P DECOMP 22:50 - 23:30 0.67 PULL P DECOMP 23:30 - 00:00 0.50 PULL P DECOMP 10/6/2004 00:00 - 00:30 0.50 PULL P DECOMP 00:30 - 01:15 0.75 PULL P DECOMP 01:15 - 03:15 2.00 CLEAN P WEXIT 03:15 - 03:35 0.33 CLEAN P WEXIT 03:35 - 05:15 1.67 CLEAN P WEXIT 05:15 - 07:30 2.25 CLEAN P WEXIT 07:30 - 10:30 3.00 DRILL P WEXIT 10:30 - 11 :00 0.50 DRILL P WEXIT 11:00 - 12:30 1.50 DRILL P WEXIT 12:30 - 13:00 0.50 DRILL P WEXIT 13:00 - 14:30 1.50 DRILL P WEXIT 14:30 - 15:00 0.50 DRILL P WEXIT 15:00 - 16:50 1.83 DRILL P WEXIT Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Description of Operations -------.---_.- Open IA RlU to tbg and PT to 2500 psi/15 min - good test. Bleed off to 1500 psi then PT IA to 2500psi 15 min - good test. Drop pressure on tbg and sheared DRC valve. Pressure up tbg/IA to 1500 psi and close SSSV dump pressure above SSSV. Monitor pressure and SSSV is working. Dump all pressures. RID hoses, Remove landing joint and set FMC BPV. NO lower double gate and spools. NU production tree. PT tbg hanger pack-off to 5k. Pull BPV and set FMC test plug, PT tree to 5000 psi. Pull test plug NU BOPE Test BOPE. Witness waived by AOGCC Line up on IA and pump 55 bbls diesel. Final differential pressure 300psi. Blowdown lines. RlU slickliner equipment including lubricator. RIH with slickline pulling toot. Pull DRC plug from GLM station #1. Run dummy GLM in station #1. Kickover tool activated in station #2 while RIH. POOH to recock tool. Run dummy GLM again to set in station #1. Had 2nd failure to set. Unable to set the dummy. Reconfigure setting tool. Attempt to set dummy GL V in station 1 again. This attempt was successful. Hold safety meeting prior to PT'ing IA. Pressure test dummy GL V in station #1. 1512 psi at 22:28 pm. 1465 psi at 22:45 pm. Holding like a rock for the last 10 minutes. RIH with slickline to pull the prong from the TT plug. Recovered prong ok. RIH to recover TT plug. POOH, tag up at surface with TT plug. Recovered plug and all seals. Nothing left in hole. Rig down HES slickline lubricator and eq. Slip and cut drilling line. Safety meeting prior to stabbing coil and pumping slack management. Stab coil into injector, change packoffs. Pump slack management prior to cutting 2500' of coil. Cut 2500' of coil. Install SLB Kendel CTC. Pull test to 35k. Rehead with BHI upper quick connect. PT to 4k P/U BHi tools and 2.50. nozzle for cleanout. RIH to 7030'. Log tie in at GR marker -5' correction RIH 2.0/2.0 3400 11,8ECO tagged at 7815' with no progress, PU to 7800' RIH went to 7830'. PU clean to 7775'. RIH to 7854' pu clean RIH tagged at 7857' PU to 7850'. RIH 7870', Work area to clean up fine snad over the shaker at bottoms up and small amount of gas. Still introducing new mud to the hole but as of now at 1.96 bpm 3360psi with the ECO at 11.9ppg annular at 3580psi Well is Printed: 11/1612004 2:57:54 PM ) ) BP EXPLORATION Operations Summary Report Page 19" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y-24 1 Y -24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/1 0/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Date Task Code NPT Phase Description of Operations ------.-.--- ----. -..--- 10/6/2004 15:00 - 16:50 1.83 DRILL P WEXIT drinking about .15bpm Shutdown pump and trapped 95psi on well. Stabilized annular 2911 psi and 9.86ECD reout (no circulation) 16:50 - 18:30 1.67 DRILL P WEXIT TOH following pressure schedule designed to maintain 3500psi IWEXIT at window. 18:30 - 19:30 1.00 CLEAN P Trap 200 psi on WHP, close the SSSV. Check for flow. None. !WEXIT Tag up, lay down nozzle BHA. 19:30 - 20:00 0.50 WHIP P Make up BHA #20. Baker 2.625" WS, Baker setting tool, BHI I BHA. 20:00 - 22:10 2.17 WHIP P IWEXIT RIH with BHA #20 to set whipstock. EDC open, RIH at 80 fpm,circulating at minimum rate. Following Dan Kara pressure I schedule. Losing fluid to hole while following pressure I schedule. We are basically getting 1 for 1 returns, with no I I extra for pipe displacement. Losing 3.8 bbls for every 1000' we I run in the hole. 22: 1 0 - 22:35 0.42 WHIP P IWEXIT Log tie in pass over GR spike at 7760' based on Cement Bond I Log of 7-16-2004. Make -10' correction. I 22:35 - 23:00 0.42 WHIP P !WEXIT RIH position botton of WS at 7867', TOW at 7854'. Attempt to shut EDC. BHI had problems with the EDC. There is a new generation of EDC in hole. It only appears to close 67% of the way. BHI had to muck about in the diagnostics software for 10 minutes to get it shut completely. Pressure up on Baker setting tool. Got good indication of shear at 2670 psi. WS tool face for face of tray set at 0 deg. Set 3000 Ibs down on WS tray. It appears to be set. Depths for whipstock; TOWS=7854'. Pinch Point= 7857' RA tag=7861.35' BOWS=7867' 23:00 - 00:00 1.00 WHIP P WEXIT Attempt to open EDC to be able to pump while POOH. BHI couldn't get the EDC open. It would only open 67% of the way. BHI had to muck about in the diagnostics software again to finally get it open. Additionally, BHI reports power and corns are working, but rest of BHA is not working properly. Will need to change out for next run. POOH pumping 1 bpm to keep hole full. Follow pressure schedule while POH. 1 On/2004 00:00 - 00:25 0.42 WHIP P WEXIT Continue POH with whipstock setting BHA. Trap 400 psi below IWEXIT SSSV. Close SSSV, continue to POH. 00:25 - 01:00 0.58 WHIP P Tag up at surface. Lay down WS setting BHA. Found that BHI EDC had been activated to disconnect and the lower section of the BHA left in the hole. In theory, this is not possible, lam not too impressed with the new generation of BHI EDC tool. 01 :00 - 04:00 3.00 FISH N HMAN WEXIT Call Baker TT for fishing equipment. Need a hydraulic GS, and a set of jars. They will prep and hotshot to rig ASAP. BHI has a model of the fishing neck, and gave to the BTT hand on location. The GS will match the model BHI has. The fish is 43.03' long, and should be setting on top of the whipstock. Top of fish at 7814'. 04:00 - 04:45 0.75 FISH N HMAN WEXIT Rig up fishing BHA. BHA #21 04:45 - 06:15 1.50 FISH N HMAN WEXIT RIH with BHA #21 to retrieve fish. 2.5. Hydraulic G Spear, 2.125. Bowen Bi directional oil jars, 1 joint of 2-1/16. CSH, BHI MWD tool. 06: 15 - 06:40 0.42 FISH N HMAN WEXIT Log tie-in at 7760' .84/.831992 psi annular 3515psi 11.79 Printed: 11/1612004 2:57:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') ) Page 20- BP EXPLORATION Operations Summary Report 1 Y -24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT Phase 10/7/2004 06:15 - 06:40 06:40 - 06:50 06:50 - 07:55 07:55 - 08:30 08:30 - 09:10 09:10- 10:30 10:30 - 15:00 15:00 - 13:50 13:50 - 17:15 17:15 - 18:40 18:40 - 19:00 19:00 - 19:45 19:45 - 20:30 20:30 - 22:15 22: 15 - 22:40 22:40 - 00:00 10/8/2004 00:00 - 03:05 03:05 - 03:30 03:30 - 05:55 05:55 - 08:30 0.42 FISH 0,17 FISH HMAN WEXIT HMAN WEXIT N N 1.08 FISH HMAN WEXIT N 0.58 FISH N HMAN WEXIT 0.67 STWHIP P 1.33 STWHIP P 4.50 STWHIP P WEXIT WEXIT WEXIT 22.83 STWHIP P WEXIT 3.42 STWHIP P WEXIT 1.42 STWHIP P 0.33 STWHIP P WEXIT WEXIT 0.75 STWHIP P WEXIT 0.75 DRILL P PROD1 1.75 DRILL P PROD1 0.42 DRILL P 1.33 DRILL P PROD1 PROD1 P PROD1 0.42 DRILL 2.42 DRILL PROD1 0.75 DRILL P PROD1 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Description of Operations ¡ ECD 21 Opsi wellhead -8' correction. i RIH pumping at.9 bpm and tagged fish at 7812'. Seen I pressure. Shutdown pump. P/U to 77790. RIH dry and tagged ¡at7812. ¡ TOH pumping down backside maintaining scheduled BHP to I SSSV. Close SSV and continue TOH. ¡ Bleed trapped WH and monitor for flow. Pull BHA. Recovered i entire fish. UD same and fishing tools. I P/U window milling BHA j RIH tagged pinch point. Correct depth and flag CT, ¡ Time milling window 1.65/1.64 3060psi 11.71 ecd 3528psi i annular milled to 7859.5' Need to stop and change shaker j screens blinding off with sand changed to 135 and 110 mesh. I Continue on time milling 500psi MW good show of metal ¡ cuttings. Punch though at 7862.1'. i Drill formation from 7862'.2 to 7867.2' 1,55/1.58 3125psi ! 11.84 ECD 3576psi annular. Drilled only 5' to prevent possible I interferance with other lateral below at 7874' I Ream and backream window area 3 times. 1.54/1.57 2900psi ! 11.76 ECD 3550psi annular. Made dry run thru window - no I problems. ! TOH following pressure schedule. ¡I Tag up at surface. Hold PJSM prior to making BHA swap. Check well for flow. No flow observed. I Lay down BHA #22, window milling BHA. Mills recovered with ! good center wear on the 00261 showing a swirl pattern. The 100261 gauged 2.74 go/2.73 no go. The string mill gauged 2.74 Igo/2.73" no go. I' PU BHA #23. Hycalog DS100 2.7x3.0. bicenter bit, 2.8 deg I BHI X-tream mud motor, Full BHI MWD tool. RIH with BHA #23 to drill build section. Open SSSV with 500 psi on the wellhead. Follow choke schedule while RIH, pumping thru an open EDC at minimum rate. Log tie in pass at 7680'. Make -10' correction. RIH thru window slick with pumps down. Shut EDé. Orient to 0 deg. Pit vol=3oo bbls. IAP=470 psi, OAP=363 psi. e on line with pumps. Free spin=3160 psi at 1.65 . Drilling with choke open. 1.64/1.66/3230 psi. B - 612 psi. ECD=11.9 ppg. Continue drilling the build on of the well. 1.75/1.78/3460 psi. IAP=916 psi, =581 psi. Pit vol=297 psi. TF=75R. ROP=25 f P=3670 psi. ECD=12.0 ppg. WHP=O. Wi P to the window. Clean PU off bottom at 22 klbs, and ack in the hole. Resume drilling. 1.67/1.72/3440 psi. Pit vol=314 bbls. (Mud up from centrifuge). ROP=75 fph. @ 8155' TF 50R BHP- ECD=11.95 Drilled to 8165' need to trip for lower bend motor. Pull above window. EDC. TOH following pressure schedule pumping at 2.4bp hing long tangent section. Change shaker screens to 175/17 Close SSSV. Tag up RIH 400' TOH flush us. UD build assembly and PIU lateral BHA # 24 R 11 " Printed: 11/1612004 2:57:54 PM ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION If",:;'"'' APPLICATION FOR SUNDRY APPROVÁL~" 20 AAC 25.280 j;.J L Ø~~/¡) ~ C ?OO4 /j 1. Type of Request: II Abandon 0 Repair Well II Plug Perforations 0 Stimulate 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 2. Operator Name: Conoco Phillips Alaska Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): 106' 8. Property Designation: ADL 025646 0 Other 0 Time Extension 4. Current Well Class: 1m Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number 193-072 V 6. API Number: t./ 50- 029-22371-00-00 9. Well Name and Number: Kuparuk 1Y-24 10. Field 1 Pool(s): Kuparuk River 1 Kuparuk River Oil Pool Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): IEffective Depth TVD (ft): Plugs (measured): Junk (measured): 8375 6420 8282 6338 None None Structural Conductor 121' 16" 121' 121' Surface 4599' 9-5/8" 4599' 3600' 3520 2020 Intermediate Production 7568' 7" 7568' 5733' 7240 5410 Liner 1108' 5" 7264' - 8372' 5501' - 6417' 10140 10490 12. Attachments: 1m Description Summary of Proposal 0 Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Thomas McCarty Title CT Drilling Engineer ., ,.~---> Perforation Depth MD (ft): Perforation Depth TVD (ft): 8014' - 8107' 6103' - 6184' Packers and SSSV Type: Baker 'FHL' packer; 4" Cameo 'TRDP-4' SSSV 0 BOP Sketch July 16, 2004 Date: Tubing MD (ft): 7681' Tubing Size: Tubing Grade: 4" 11# 1 3-1/2" 9.3 & 9.2# J-55 1 L-80 Packers and SSSV MD (ft): 7193' 1793' 13. Well Class after proposed work: 0 Exploratory 1m Development 0 Service 15. Well Status after proposed work: 0 Oil 0 Gas 0 WAG DGINJ 0 Plugged DWINJ 1m Abandoned 0 WDSPL Contact Thomas McCarty, 564-4378 Phone 564-4378 Sundry Number: ....?o-f- 'd-t,1 Conditions of approval: Notify Commission so a representative may witness 0 Location Clearance 0 Plug Integrity ~OP Test 0 Mechanical Integrity Test Other: '::>vlœa.\-\YLí'\.\ "::>\clá~\s,. ~'\\.} \ \<t <;,¡t~ \ú. \€ CJ ~ ~\ V\.Q. '-\0\. OR\G\NAL JUl 1 4 1ßI~k 1611.. ,c.£ V Date . I Du~cate ubm n RBDMS 8ft APPROVED BY COMMISSIONER THE COMMISSION ( ( bp To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Thomas McCarty Drilling Engineer Date: July 8, 2004 Re: Well KR U 1 Y - 24 prep for a CTD sidetrack Production well KRU 1 Y -24 is scheduled for a through tubing sidetrack with the SLB/Nordic 2 Coiled Tubing Drilling rig. Two laterals will be drilled (1 Y -24A and 1 Y -24ALl), the existing perfs will be isolated with cement pumped past the whipstock. The following describes work planned for the P&A and sidetrack and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for r~nce. '- """"\ .............. /" CTD Pre-Rig Summary 1) Slickline - Drift tubing and liner. Dummy gas lift valves. Pressure test IA to 2500 psi. Pressure test OA to 2000psi. No Flow test on SSSV. 2) Eline - Set whipstoék at approx. 7885'md 3) Coil- Pump approx. 15bbls of 15.8ppg cement past whipstock to isolate A sands '--- ~~CL '-.')0 \ ~ 'M...«Z. ~ L\ ~ b \ CTD Sidetrack Summary ~ ~ ~ 1) MIRU Nordic 2. NU 7-1/16" BOPE, test. 2) Mill 3.80" window at 7885' md and 10' of openhole. 3) Drill 3" bicenter hole horizontal sidetrack 1 Y -24A from window to -9850' TD targeting Kuparuk A sand interval. 4) Run and drop a 2-3/8" slotted (pre-drilled) liner from TD of 9850', up to 8140' md. 5) Openhole sidetrack at 8140' , above the 2-3/8" liner. 6) Drill 3" bicenter horizontal sidetrack 1Y-24AL1 from open-hole side track to - 10225' TD targeting Kuparuk A sand interval. 7) Complete with 2 3/8" pre-drilled liner from the TD of L2 at 10225', up into the 3-1/2" tubing to -7600 '. 8) Post CTD rig -Run GL V s. Bring on production. 3~~ -~(p \ / The pre CTD work is scheduled to begin July 16,2004. The drilling portion is scheduled for Aug 5,2004. Thomas McCarty CTD Drilling Engineer 564-4378, 748-2598 CC: Well File Terrie Hubble ( 8." ConocoPhillips Alaska, Inc. 1Y-24 API: 500292237100 - - I SSSV Type: TRDP sssv - (1793-1794. I Annular Fluid: 00:4.000) Reference Log: Last Tag: 8240 t r-I Last Tag Date: 2/22/2004 ... Caslna String - ALL STRINGS ~~..: Description , . CONDUCTOR SUR. CASING II PROD. CASING .. SUR. CASING '. ., LINER ¡,; ~ Tubing String - TUBING ,I ~ Size Top 4.000 0 3.500 4893 3.500 7223 .ì: . P.'.. Perforations Summary !!'---) Interval TVD 8014 - 8016 6103 - 6105 i Gas Lift MandrelNalve 1 (3066-3067. Gas lift mdrellOummy Valve 2 (4899-4900. 00:5.968) Gas lift MandrelNalve 3 (5658-5659. Gas lift ~ndrellOummy Valve 4 (6420-6421. 00:5.968) Gas lift MandrelNalve 5 (7126-7127. NIPPLE (7171-7172, 00:3.500) PBR (7180-7181. 00:3.500) PKR (7193-7194, 00:6.156) NIP (7211-7212, 00:3.500) TUBING (7223-7681. 00:3.500. 10:2.992) Perf (8016-8022) Perf (8014-8039) Perf (8030-8038) Perf (8060-8074) Perf (8101-8107) ..j' .- ¡:i_..._",- .11:;..'" 1'.. ..... L . III ... II-III - - - - - - 8016 - 8022 8022 - 8030 Status Ft SPF Date Type Comment 2 4 9/9/1993 IPERF 33/8" SWS Guns; 180 deg. Phasing 6 10 12/22/1996 RPERF 21/8" EnerJet DP 8 4 9/9/1993 IPERF 3 3/8" SWS Guns; 180 deg. Phasing 8 10 12/22/1996 APERF 21/8" EnerJet DP 1 4 9/9/1993 IPERF 33/8" SWS Guns; 180 deg. Phasing 14 6 12/22/1996 APERF 21/8" EnerJet DP 6 6 12/22/1996 APERF 21/8" EnerJet DP ( Well Type: PROD Orig 6/28/1993 Completion: Last W/O: 3/21/1994 Ref Log Date: TO: 8375 ftKB Max Hole Angle: 47 deg @ 2431 Size Top Bottom 16.000 0 121 9.625 0 3041 7.000 0 7568 9.625 3041 4599 5.000 7264 8372 Bottom TVD Wt 4893 3807 11.00 7223 5470 9.30 7681 5819 9.20 Zone A-5 6105 - 6110 A-5 6110 - 6117 A-5,A-4 8060 - 8074 6143 - 6155 8101 - 8107 6179 - 6184 Gas Lift MandrelsNalves St MO TVD Man Man Type V Mfr V Type V 00 Latch Port TRO Mfr 1 3066 2523 Merla TMPD 2 4899 3811 Camco MMG2 3 5658 4340 Camco MMG2 4 6420 4878 Camco MMG2 5 7126 5398 Camco MMG2 Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 1793 1645 SSSV 7171 5431 NIPPLE 7180 5438 PBR 7193 5448 PKR 7211 5461 NIP 7680 5819 SOS 7681 5819 TTL General Notes Date Note 1/17/1997 Under-reamed HARD ASP HAL TENES out of Liner from 7930'-7993'; Underreamed remainder of Liner to PBTD with No Obstructions. NOTE: Under-reamer blades were severely worn on top side of blades (indicates possible Csg Damage) See WSR 1/17/97 8030 - 8038 8038 - 8039 6117 - 6124 6124 - 6125 A-4 A-4 A-3 A-3 GLV DMY GLV OMY OV 1.0 1.5 1.5 1.5 1.5 Description Camco 4" TRDP-4 Cameo W-1' Landing Baker Baker 'FHL' Cameo 'D' Nipple NO GO Baker KRU 1Y-24 Angle @ TS: 31 deg @ 7765 Angle @ TD: 28 deg @ 8375 Rev Reason: TAG FILL Last Update: 2/27/2004 TVD Wt Grade Thread 121 62.50 H-40 2506 47.00 L-80 5733 26.00 L-80 3600 36.00 J-55 6417 18.00 L-80 Grade Thread J-55 DSSHTC J-55 EUE 8RD MOD L-80 EUE 8RD MOD BK 0.156 1342 RK 0.000 0 RK 0.188 1292 RK 0.000 0 RK 0.250 0 Date Run 4/20/1997 3/21/1994 4/20/1997 3/21/1994 4/20/1997 Vlv Cmnt ID 3.312 2.812 3.000 2.937 2.750 2.992 2.992 ( KRU 1Y-24A & 1Y-24AL1 Producer Proposed CTD Completion :í. ~ ~ ~ ~ ~ ~ 9-5/8" 36# J-S5 ~ casing @ 459~ L~J H. 4" 11.0# J-SS DSS-HTC tubing to surface. G. 4" Cameo 'TRDP-4' SSSV set at 1793' MD, 3.312" 10 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ! ! ! ! ~ ~ ~ ! ~ ~ ~ ~ ! ~ ,. ~ ;¡: 7" 26# L80 @ 7568' MD ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 2-3/8" liner top @ +/-7600' MD ~. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ L ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ ,- i . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ A. 3-1/2" tubing tail at 7681' MD B. 3-%" Cameo D nipple with 2.75" ID at 7211' MD (may be milled out to 2.80" for CTD bits) ~ (' Conoc~hillips Alaska, Inc. I. 4" x 3-%" crossover at 4893' MD I. 4" x 1" Merla TMPD mandrel at 3066' MD - ~ ~ F. 3-1/2" 9.3# J-SS EUE 8rd Mod tubing to crossover wi 3-1/2" x 1-112" Cameo 'MMG2' mandrels -- 5" liner top @ 7264' MD C. Baker 3-1/2" FHL packer at 7193' MD with PBRlseal assembly Top of Whipstock +/-7885' MD Cemented in Place Window in 5" 3" open hole Open hole KOP @ 8,140' md Lateral (1Y-24AL 1), TO @ 10225' md 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 Y -24A, TO @ 9850' md 5" 18# L.80 @ 8372' MD 2-3/8" pre-drilled liner MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. I. Supervisor DATE: FROM: John Crisp, SUBJECT: Petroleum Inspector May 17-18, 2001 Safety Valve Tests Kuparuk River Unit 1Y Pad MaY 17 & 18,2001: I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner, i witnessed one failure, the LPP failed to trip above 50% of primary separator pressure. The pilot was re-tested & passed the re-test. The AOGCC test report is attached for reference. I conducted 25 well house inspections on 1Y Pad. The majority of the houses were in good shape w/no problems witnessed. Well houses # 30 & 22 were found w/the well house lids resting on the tree cap gauges. The VSM for the flow line on well # 29 looked as if it had shifted up & had the line in a slight bind. I asked Phillips Rep. Pete Nezaticky to inspect this line. Prudhoe Bay Field has had problems w/VSM's shifting up & i wanted to make sure KRU Rep's were aware of this problem. SUMMARY: I witnessed SVS testing in Kuparuk River Field. 16 wells, 32 components tested. 1 failure witnessed. 3.13% failure rate. 25 well house inspections conducted. Atta.qhmen~: svs KRU 1Y 5-17 & 18-01jc CC; . NO. N-CONFID. ENTIA. L SVS KRU IY 5-t7 & 18-01jc AlaSka Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Operator Rep: Emie Bamdt AOGCC Rep: John Crisp Submitted By: John Crisp Date: 5/17 & 18/01 Field/Unit/Pad: Kuparuk River Unit 1Y Pad Separator psi: LPS 85 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, G/NJ, Number Number PSI PSI Trip Code Code Code Passed GASorC¥CLE 1Y-01 1830500 Y-02 1830590 1Y-03 1830610 3750 2000 1800 p P wAG Y-04 1830660 Y-05 1830870 , 1Y-06A 1971340 85 70 55 P P OIL Y-07 1830680 Y-08 1830620 , 1Y-09 1830520 1Y-10 1830510 3750 2000 1750 P 'P W~kG 1Y-11 1830410 1Y-12 1830260! 1Y-13 1830150 1Y-14 1830230~ , 1Y-15A 1981860 85 70 50 P P OIL 1Y-16 1830420 Y- 17 1930680 85 60 60, P P OIL Y- 18 1931060 1Y-19 1931070 85 60 65 P P OIL 1Y-21 1931020 85 70 65 P P OIL Y-22 1930700 85 60 55 P P OIL , 1Y-23 1930710 85 70 28 3 P 5/18/01 OIL 1~y,24. ~5:~ .q930720 85 70 78 P P OIL Y-25 1880890 , Y-26A 1881160 85 70 50 P P OIL 1Y-27 1930880 85 70 64 P P OIL , Y-28 1930890 , Y-29 1880910 85 70 60 P P OIL . Y-30 1880900 85 70 70 P P OIL , Y-31 1930900 Y-32 1880930 85 70 70 P P OIL 1Y-34 1930910 85 70 65 p p OIL Wells: 16 Components: 32 Failures: , 1 Failure Rate: 3.13% []90Day RJF ~1]~: Page 1 of 2 SVS I(l~ll 1V q_l'7 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE RJF 1/16/01 Page 2 of 2 SVS KRU 1Y 5-17 & 18-01jc ON OR BEFORE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address 5. Type of Well: Plugging P. O; Box 100360, Anchorage, AK 99510 Development X Exploratory _ Stratigraphic _ Service .4. Location of well at surface 570' FNL, 1762' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 118' FSL, 2277' FEL, Sec. 1, T12N, R9E, UM At effective depth 125' FNL, 2198' FEL, Sec. 12, T12N, R9E, UM At total depth 167' FNL, 2186' FEL, Sec. 12, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8375 6420 Perforate X Other Effective depth: measured 8 2 8 2 true vertical 6338 6. Datum elevation (DF or KB) RKB 106 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 Y-24 9. Permit number/approval number 93-72 10. APl number 50-029-22371-00 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None feet feet Junk (measured) None feet ORIGINAL Casing Structural Conductor Surface Intermediate Production' Liner Perforation depth: Length Size 80' 16" 4573' 9-5/8" 7537' 7" 1108' 5" measured 8014'-8039', true vertical 6103'-6125', Tubing (size, grade, and measured depth) Cemented Measured depth 218'Sx PFC 1 21' 800 Sx P F E, 4599' 480SxCIG,&TJ 105SxPFC 250 Sx Class G 7 5 6 8' 175 Sx AS I 8372' True vertical depth 121' 3494' 5625' 6311' 8060'-8074', 8101'-8107' 6143'-6155', 6179'-6184' 4", 11#/ft., J-55 @ 4893', 3.5", 9.3#/ft., J-55 @ 4893'-7223' 3.5" 9.2#/ft., ~{~1:~. ~h,¢2~3~-~681' Packers and SSSV (type and measured depth) ' ' r'_ Pkr: Baker FHL @ 7193'; SSSV: Camco TRDP-4A @ 1793' 13. Stimulation or cement squeeze summary Perforated "A2 & A3" sands on 12/22/96. Intervals treated (measured) 8060'-8074', 8101'-8107' Treatment description including volumes used and final pressure Perforated using 2 1/8 EJ guns w/BH & DP charges @ 6 SPF, fp = 1300 psi. 14. Bepresentative Daily Average Production or Injection Data OiI-Bbl Gas-tvlcff Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 621 690 1122 1130 213 Subsequent to operation 621 690 1122 1130 213 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereb~rtify that the foregoing is true and correct to the best of my knowledge. Signed "'~~ ~'~'~~,,~ Title Wells Superintendent Form 10/~4 ~ev/06/'i'5/8~ - / Date ~'/~ 2~.2 SUBMIT IN DUPLICATE ARCO Alaska, Inc. .~ UPARUK RIVER UNIT '' WELL SERVICE REPORt" '~ K1(1Y-24(W4-6)) WELL JOB SCOPE JOB NUMBER 1Y-24 PERFORATE, PERF SUPPORT 0717961857.1 DATE DAILY WORK UNIT NUMBER 12/22/96 PERFORATE F/8016 - 8107 FT ELM UNIT #1 DAY OPERATION COMPLb I E I SUCCESSFUL KEY PERSON SUPERVISOR 9 (~) Yes (~)N° (~)Yes O N° SWS'SCHWARTZ' i~~ FIELD AFC# CC__,~ DAILY COST ACCUM COST ESTIMATE KAWWRK 230DS1 0YL $1 7,720 $87,025 Initial Tbcl Press Final Tbcl Press Initial Inner Ann Final Inner Ann i initial Outer Ann I Final Outer Ann 1300 PSI 1300 PSI 1800 PSI 1800 PSll 0 PSll 0 PSi DAILY SUMMARY PERFORATE 8016- 8022, 8030- 8038, 8060- 8074 & 8101 - 8107 FT ELM I TIME LOG ENTRY 08:30 10:30 12:30 13:00 MIRU SWS (SCHWARTZ & CREW) / LRS. TGSM- GUN SAFETY / MUSTER POINT. MU GUN ASSEMBLY #1 (2-1/8" ENERGET BH @ 6 SPF) WT/CCL/GUNS (TL- 19'). PT DOPE 3000 PSI. RIH W/ASSEMBLY #1. STICKY F/3500 Ff' ELM TO BO'FI'OM (8200 FT ELM). PUMPED 1/4- 1/2 BPM (TOTAL 35 BBLS WARI~. DIESE]L)';' TI~ED INTO 7/16/93 CASED HOLE LOG. SHOT F/8101 - 8107 FT ELM. OHW/,ASSEMBLY.:'#1. ALL SHOTS FIRED. 14:00 14:45 POOH W/ASSEMBLY #2. ALL SHOTS FIRED. 15:30 16:00 17:15 18:15 MU GUN ASSEMBLY #2 (2-1/8" ENERGET BH @ 6 SPF) WT/CCL/GUNS (-I'L - 28'). RIH W/ASSEMBLY #2. NO PROBLEM GE-f-TING DOWN. TIE IN. SHOT F/8060 - 8074 FT ELM. MU GUN ASSEMBLY #3 (2-1/8" ENERGET DP @ 6 SPF ) VV-I'/CCL/GUN/SPACE/GUN (TL -26'/. RIH W/ASSEMBLY #3. COULD NOT GET PAST 3070 FT ELM (GLM #1). WORKED.& PUMPED DIESEL. POOH TO CHECK TOOL. REMOVED NO GO F/GUN ASSEMBLY. RIH W/ASSEMBLY #3. NO PROBLEM GE'I-I'ING DOWN. TIE IN. SHOT F/8016 - 8022 & F/8030 - 8038 FT ELM. POOH W/ASSEMBLY #3. ALL SHOTS FIRED. RD SWS / LRS. SECURE LOCATION. 19:00 OFF LOCATION & WELL BACK TO PRODUCTION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $408.00 APC $250.00 $9,300.00 ARCO $0.00 $720.00 BAKER OIL TOOLS $0.00 $15,900.00 DIESEL $0.00 $500.00 DOWELL $0.00 $35,733.00 HALLI BU RTO N $0.00 $3,785.00 LITTLE RED $2,500.00 $5,710.00 SCHLUMBERGER $14,970.00 $14,970.00 TOTAL FIELD ESTIMATE $1 7,720.00 $87,026.00 STATE OF ALASKA AIJ-~SKA OIL AND GAS CONSERVATION COMMI~51ON 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 570' FNL, 1762' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 118' FSL, 2277' FEL, Sec. 1, T12N, R9E, UM At effective depth 125' FNL, 2198' FEL, Sec. 12, T12N, R9E, UM At total depth 167' FNL, 2186' FEL, Sec. 12, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8375 6420 6. Datum elevation (DF or KB) RKB 106 7. Unit or Property name Kuparuk River Unit 8. Well number 1 Y-24 9. Permit number/approval number 93-72 10. APl number 50-029-22371-00 11. Field/Pool Kuparuk River Field/Oil Pool feet feet Plugs (measured) None feet Effective depth: measured 8 2 8 2 true vertical 6338 feet Junk (measured) None feet Casing Length Size Structural Conductor 8 0' 1 6" Surface 45 7 3' 9 - 5 / 8" Intermediate Production 7537' 7" Cemented Measured depth 218 Sx PFC 1 21' 800 Sx PF E, 4599' 480SxCIG,&TJ 105SxPFC 250 Sx Class G 7 5 6 8' True vertical depth 121' 3494' 5625' Liner 1 1 08' 5" 175 Sx AS I 8372' 631 1 ' Perforation depth: measured 8014'-8039', 8060'-8074', 81 01 '-81 07' .. true vertical 61 03'-61 25', 61 43'-61 55', 61 79'-61 84' Tubing (size, grade, and measured depth) 4", 11#/ft., J-55 @ 4893', 3.5", 9.3#/ft. , J-55 @ 4893'-7223', 3.5", 9.2#/ft. , L-80 @ 7223'-7681' Packers and SSSV (type and measured depth) Pkr: Baker FHL @ 7193'; SSSV: Camco TRDP-4A @ 1793' 13. Stimulation or cement squeeze summary Fracture stimulated "A" sands on 2/28/97. Intervals treated (measured) 0R I GINAL 801 4'-8039', 8060'-8074', 81 01 '-81 07' Treatment description including volumes used and final pressure Pumped 190.5 MIbs of 20/40 and 12/18 ceramic proppant into formation, fp = 8300 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 621 690 1122 1145 213 Subsequent to operation 1 0 3 7 738 648 1153 219 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 7. I here.~c~ertify that the foregoing is true and correct to the best of my knowledge. Signed Title Wells Superintendent Form 1(:~'~ ~"~'~)4 Rev/ 0~'/1~ - - Date ~Z~--f? SUBMIT IN DUPLICATE ARCO Alaska, Inc. Date' January 31, 1996 Transmittal #' 9328 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open/cased hole items. Please acknowledge receipt and return one signed copy of this transmittal. ~2--~ 0~ 1 H-08 ~3 'o'-72,-1Y-24 R~%'t:.~? 3R-26 q )'?'-/76 2X-12A ~ ¢'" ~'~.3A-04 Dual Burst TDT-D Dual Burst TDT-D ARC's ARC's Dual Burst TDT-D 02/05/95 01/07/95 12/15/95 11/25/95' 01/09/96 50-029-20763-00 50-029-22371-00 5172-8866 5797-864O 50-029-21433-00 Acknowledged: Date: DISTRIBUTION: Mr. Vernon E. Pringle Jr. DeGioyler and MacNaughton One Energy Square Dallas, TX 75206 EricksorVZuspan NSK Central Files NSK 69 Sharon Allsup-Drake DS Develo0ment ATO - 1205 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Clifton Posey Geology ATO - 1251 yon,,. C,~mmission ¢;chlul'lrlber er .... :.. ge_._ GeoQuest §00 W. International Airport Road Anchora.(ile, A~( 995~8-1199 ATTN: Sherrie NO. 10004 Company: Field: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Kuparuk (Open/Cased Hole) 11241 6 US Well Jo!b if Log Description Date BL RF Sepia DIR MWD Tape I ft-08 ,72 --0~/5 95064 DUAL BURST TDT-P (BORAX) 950205 1 ........ 1 ...... 1 .1 y 72_4__ ~,:,..1 (') ',"2. 9 5 !) 3 6 DUAL BURST TDT-P (BORAX) 9 5.01 0 7 I _. 1 .... 3R-26__ .~.t-~ ,t~V;7 ._ 95406 ARC5 951 215 I I 1 2X-12A ~.C-f"i/(~ 95:[82 ARC5 951125 13A-04 "~,,;" -- 2 ~ '? 95_0_38 DUAL BURS'r' TDT-P (BORAX) 9501 09 I ___ I _ 1 , SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. FRAC / ~TIMULATION SUMMApV~ PROCEDURE DATE: . SERVICE CO: ~)~b,,,~/il .. ZONE: ANNULUS PRESS: STAGE VOL. FLdlD PROP CONC. PROP SIZE RATE (BPM'i , i ] [ i iii i i · ~. too to'*5/e~,_o. ~,,~l~a,.,.,,.~ z~ z . ~ ,-I " F~L " · ~1 I ~, Iqfl ,, ~ ,,. ~ ,, I~ ~~.~~ ~o, {~o ",. (o~" " " (~d ~z, ~-~ " ~4~" " " (q- - , - _ .-: ..... '... ~... ~' ~ ,, . '- , _ i . m Il ~ I · . p . · . ..... ISIP: ~ PSI 15 MIN. ----- FLUID TO RECOVER: (~q~) BBL SAND IN ZONE: ITEMIZED COST: FRAC: ROU~I'ABOUTS: t OO~ .-. DIESEL: ( ( ..~..~- PSi AVG. PRESS: ~ !-/'C~ JOB COMPLETE: {2.~ q {~{~ SAND IN CASING: Z (,~ HOT OIL SERVICE: 4/t~ ._- TRUCKING: !--~ Oo - - i i I1 SUPERVISION: (~o~ - PSI LB RIG SUPER~,..~ RECEIVED NI~Y. "1 '1 19~4 ~.t~ska O&l & Gas Cons. Cornmissior~ Anchorage WELL: 1Y-24 API: 50-029-22371 PERMIT: 93-72 PAGE: 3 06/18/93 (8) PARKER 245 TD: 7576'( o) 06/19/93 (9) PARKER 245 TD: 7870' ( 294) 06/20/93 (10) PARKER 245 TD: 8145' ( 275) 06/21/93 (11) PARKER 245 TD: 8380' ( 235) DRILLING FLOAT EQUIP 7"@ 7568' MW:ll.9 VIS: 54 PU STACK & SET SLIPS W/ll5K. MAKE ROUGH CUT & LD LANDING JT. RD CSG EQUIP. ND STACK. MAKE FINAL CUT. INSTALL PACKOFF & 11" 3M X 7-1/16" 5M TBG HEAD. TEST TO 3000 PSI-OK. NU BOP. CHANGE RAMS TO 3-1/2". CHANGE TOP DRIVE & IRON ROUGHNECK TO 3-1/2". TEST BOPE TO 300 PSI & 3000 PSI. JOHN SPAULDING W/AOGCC WAIVED WITNESSING TEST. SET WEAR RING. INJECT 100 BBLS WATER & 70 BBLS DIESEL INTO ANN @ 3 BPM W/300 PSI. CUT & SLIP 105' DRILL LINE WHILE INJECTING. SERVICE RIG. MU BHA & PU 3-1/2" DP & TIH. TAG CMT STRINGER @ 7470'. CIRC & COND MUD TO 11.7 PPG. TEST 7" CSG TO 3500 PSI FOR 30 MIN-OK. DRILLING 7"@ 7568' MW:ll.6 VIS: 45 DRILL FC, CMT, FS, & 10' NEW FORMATION TO 7586'-5734' TVD. FIT @ 7586' W/ll.8 PPG @ 250 PSI. EMW=12.6 PPG. DRILL F/7586'-7870'/5955' TVD. DRILLING 7"@ 7568' MW:12.2 VIS: 47 DRILL F/7870'-7911'. SHORT TRIP TO SHOE-NO FILL. MUD WT CUT F/ll.8 PPG TO 10.4 PPG. DRILL F/7911'-8102' CBU. DROP SURVEY. PMP SLUG. POOH. RETRIEVE SURV. MU NEW BIT & TIH. NO FILL. DRILL F/8102'-8145'. MUD WT CUT TO 11.2 PPG. @ BU. SHORT TRIP 7"@ 7568' MW:12.2 VIS: 47 DRILL F/8145'-8380' TD. 06/22/93 (12) PARKER 245 TD: 8380'( o) FISHING 7"@ 7568' MW:ll.8 VIS: 47 SHORT TRIP TO CSG SHOE. TIGHT SPOT F/8180'-8148'. TIH TO 8297'. PIPE STUCK AFTER MAKING CONECTION & WASHING DOWN F/8287'-8297'. COULD NOT ROTATE, SLACK OFF OR PU. WORK PIPE & CUT MUD WT TO 11.8 PPG. JARS STOPPED HITTING. SPOTTED EZ-SPOT PILL IN OPEN HOLE. LET PILL SOAK FOR 2 HRS, & THEN STARTED WORKING PIPE. CONT WORKING PIPE & MOVING PILL EVERY HOUR UNTIL APRS ARRIVED. RU SCHLUMBERGER & APRS & LOCATE FREEPOINT @ 7768' WLM-TOP OF DC. MU BACKOFF CHARGE & TIH. SET CHARGE @ 7768' & BACKOFF. POOH W/WL. CBU. BLED OFF 200 PSI (975-775)0FF 7" CSG & ANN ON 1Y-17. TOTAL OF 4 BBLS. PRESS BLED DOWN TOGETHER & BOTH BUILT UP IMMEDIATELY. SHUT WELL IN & SECURED. RECEIVED & 6as Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate __ Plugging Perforate Pull tubing X Alter casing Repair well Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 570' FNL, 1762' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 118' FSL, 2277' FEL, Sec. 1, T11N, R9E, UM At effective depth 125' FNL, 2198' FEL, Sec 12, T11N, R9E, UM At total depth 167' FNL, 2186' FEL, Sec. 12, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) RKB 106'. PAD 65' GL 7. Unit or Property name Kuparuk River Unit 8. Well number 1 Y-24 9. Permit number/approval number 93-72 10. APl number 50-029-22371 11. Field/Pool Kuparuk River Oil Pool 8375' feet Plugs (measured) None 6420' feet feet Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 8282' feet Junk (measured) true vertical 6338' feet Length Size Cemented Measured depth True vertical depth 121' 16" 218 Sx PFC 121' MD 121'TVD 4599' 9-5/8" 800 sx Perm E 4599' MD 3600' TVD 480 sx Class G & Top Job w/ 105 sx PFC 7568' 7" 250 sx Class G 7568' MD 5731' TVD 7264'-8372' 175 sx Class G 8372' MD 6338' TVD measured 8015' - 8040' true vertical 6104' - 6126' Tubing (size, grade, and measured depth) 3-1/2", 9.3#/9.2#, J-55/L-80 TBG W/ TAIL @ 7681' Packers and SSSV (type and measured depth) Baker "FHL" Pkr @ 7193', TRDP-4A SSSV @ 1793' RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure APR 1 1 1994 Aiaska Oil & Gas Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 R~v 05/17/89 Title Area Drilling Engineer Date SUBI(/IlT IN DUPLICATE WELL: 1Y-24 API: 50-029-22371 PERMIT: 93-72 PAGE: 4 06/23/93 (13) PARKER 245 TD: 8380'( 06/24/93 (14) PARKER 245 TD: 7583'( o) o) 06/25/93 (15) PARKER 245 TD: 8100'( 517) POH 7"8 7568' MW:ll.8 VIS: 50 CIRC & COND MUD. SLUG DP. POH W/84 STS 3-1/2" DP. LD SHOT JT 3-1/2" DP. TOP OF FISH 8 7773'-4-3/4" DC W/3-1/2" IF BOX UP. FISH IS ENTIRE 4-3/4" BHA-523.5'LENGTH. PU 3-1/2" CUT LIP SCREW-IN SUB, BUMPER SUB, OIL JARS, 12-4-5/8" DC'S, ACCELERATOR SUB, & RIH TO 7763' CBU. MUD WT 11.7+. NO TRIP GAS-WASHED TO TOP OF FISH @ %773'-N0 FILL. ATTEMPT TO SCREW INTO FISH-COULD NOT TAG TOP OF FISH BUT ROLLED OFF-COULD GO DOWN BESIDE FISH 2-3'. UNABLE TO SCREW IN. SLUG DP. POH. LD SCREW-IN SUB. PU 5-3/4" OD SKIRTED SCREW-IN SUB & TIH. WASH 70' TO FISH-SCREWED INTO FISH @ 7773'. BROKE CIRC THRU FISH. JARRED UP & DOWN ON FISH PULLING 175,000 OVER STRING WT. FISH NEVER MOVED. JARS FAILED AFTER 2-1/2 HRS. HOLE PACKED OFF-PUMPING IN W/NO RETURNS. RU SCHLUMBERGER & APRS TO BACK OFF. RIH W/STRING SHOT. BACKED OFF 8 TOP OF FISH @ 7773' POH W/WL. SET LUB BACK. POH W/3 STDS DP-UP IN 7" C~G. CBU. RD SCHLUMBERGER & APRS OUT OF DERRICK. POH W/FISHING TOOLS. DRESS OFF CMT PLUG 7"8 7568' MW:ll.8 VIS: 51 FIN POH-LD TOOLS. LEFT 3-1/2" SCREW IN SUB IN HOLE. 3-1/2" IF PIN LOOKING UP. WO 2-7/8" TBG. PU 2-7/8" TBG. GREASE UP. FIN PU 2-7/8" TBG. RIH W/ 3-1/2" DP TO 7765' CIRC & COND MUD. MUD BALANCED. TEST HOWCO LINES TO 2500 PSI. HALLIBURTON SPOTTED 100 SX CLASS "G" IN 6.125" OPEN HOLE & 7" CSG F/7765'-7241'. MIXED CMT 8 16.1 PPG W/10 BBLS WATER AHEAD & 2.5 BBLS WATER BEHIND CMT DISPLACED W/44.5 BBLS MUD, JC @ 1500 HRS. PULLED 3 STDS TO 7483'. REVERSED OUT DP. RECOVERED + 10 BBLS WATER-NO CMT. CIRC OUT DOWN DP. SLUG DP. POH W/DP & LD 2-7/8" TBG. PULL WEAR BUSHING. RU TEST EQUIP. TEST HYDRIL, ALL RAMS, CHOKE MAN, CHOKE & KILL LINE VALVES, TOP DRIVE & FLOORS VALVES TO 300 & 3000 PSI-VOLUME TEST KOOMEY. RD TEST EQUIP. INSTALL WEAR BUSHING. PU BHA, ORIENT TOOLS, SHALLOW TEST MWD. RIH W/6.125" BIT. TAGGED UP @ 7479'. CIP 8 1400 HRS 06/23/93. DRLG GOOD CMT F/7479'-7568' IN 7" CSG & F/7568'-7583' IN OPEN HOLE. AT 7583' ROP 100'/HR, llK WOB, 300 RPM. DRILLING 7"8 7568' MW:ll.7 VIS: 46 DRESS OFF CMT PLUG F/7583'-7683' ROP 40-60'/HR W/10K WOB -- & 300 RPM. ORIENT & SLIDE F/7683' (KOP)-7740'. ROTARY DRLG 6.125" W/MOTOR F/7740'-7886'. ADT 7.3 HRS. CBU & SLUG DP. POH FOR BIT-LD MW-D, SHORT NM DC, DOT SUB, & 3- 4-5/8" DC'S. MU NEW BIT & BHA. TIH TO SHOE. CUT DRLG LINE. RIH TO 7675'. WASH & REAM THROUGH KOP & TO BTM-NO FILL. DRLG 6.125" HOLE F/7886'-8100'. NO TRIP GAS. ADT 4.45 HRS. ~:,.~.,..:.~;~ ~.)!! & Gas Cons. Commission Anchorage WELL: 1Y-24 API: 50-029-22371 PERMIT: 93-72 PAGE: 5 06/26/93 (16) PARKER 245 TD: 8375' ( 275) 06/27/93 (17) PARKER 245 TD: 8375'( o) 06/28/93 (18) PARKER 245 TD: 8375'( o) TIH 7"@ 7568' MW:ll.7 VIS: 45 DRLG 6.125" HOLE F/8100'-8375'. CBU-SLUG DP. MADE 10 STD SHORT TRIP TO SHOE. GREASE UP. RIH. WASH 38' TO BTM-NO FILL. CIRC & COND MUD & HOLE FOR LOGS. NO TRIP GAS. DROP SURVEY. SLUG DP. POH FOR LOGS-LD NM DP, STAB, MN DC'S, & MUD MOTOR. SLM-NO CORR. RU SCHLUMBERGER-RAN DIL/LDT/CNL/GR/AMS FROM WLTD 8368'-7568'. RD SCHLUMBERGER. PU BHA & START RIH. POH W/SETTING TOOL 5-@ 8371' MW:ll.7 VIS: 46 FIN TIH-NO FILL. CIRC & COND MUD & HOLE. UNLOADING LARGE SHALE SLIVERS. SLUG DP. DROP 2-3/8 OD RABBITT. POH TO RUN 5" LINER. LD 2-STAB. RU CASERS. HOLD SAFTETY MEETING. RAN 25 JTS 5" 18% L-80 LTC 8R CSG, TIW HYDROLIC SET HGR-LENGTH 1107'. PMP 30 BBLS MUD & CLEARED LINER· WT 15,000 LBS. RIH W/DP TO 7" SHOE & FILLED DP EVERY 10 STDS. CIRC @ SHOE. MU CMT HEAD ON JT DP. FRIH W/5" LINER & MU CMT'G HEAD. WASHED 25' TO BTM.. CIRC & RECIP LINER-HOLE PACKING OFF-WORK PIPE & CIRC UNTIL HOLE CLEANED UP. PMP 500 BBLS @ 3 BPM & 850 PSI. FULL RETURNS. BATCH MIX CMT. TEST HOWCO LINES. HALLIBURTON CMT'D 5" LINER PUMPING 20 BBLS 12.5 PPG SPACER, 175 SX CLASS "G" W/ADDITIVES(38 BBLS SLURRY), DROPPED PLUG-DISPLACED W/67.5 BBLS MUD. BMP PLUG. PRESS UP TO 3500 PSI & SET LINER HGR W/SHOE @ 8371', FC @ 8324', & LC @ 8282' CIP @ 0200 HRS. ATTEMPT TO RELEASE SETTING TOOL W/500 P~I ON DP. UNABLE TO RELEASE. PRESS UP TO 2000 PSI ON DP-WORKED PIPE & LOST DP PRESS & PIPE MOVE FREE UP HOLE 40' FREE. PULL 90' W/30-40K DRAG-COULD BE PULLING LINER UP HOLE. PMP DOWN DP-PRESS UP TO 1000 PSI-NO RETURNS-STILL IN LINER OR PACKED OFF-ROTATE W/PRESS-PIPE CAME FREE @ 7121'. CBU @ 7061'. REC 10-12 BBLS GOOD CMT. SLUG DP. POH W/SETTING TOOL. CHANGE SAVER SUB 5"@ 8371' MW: 0.0 VIS: 0 PU 6.125" BIT, CSG SCRAPER, BS, 3-4-5/8" DC'S, JARS, 2-4-5/8" DC'S & RIH TO 7022'. WASHED F/7022' T0L @ 7267' · HAD ABOUT 20' GREEN CMT ON TOP OF LINER. CIRC HOLE CLEAN @ 7267'. SLUG DP. POH & LD 4-5/8" DC'S. PU 4.125" GOPHER MILL, 5" CSG SCRAPER, 39 JTS 2-7/8" DP. RIH W/3-1/2" DP TO TOL @ 7267'_ TAGGED UP @ 7274'. CO CMT STRINGER F/7274'-7293'. FIN TIH. TAGGED UP ON LC @ 8284' PBTD. CIRC-SHUT WELL IN-TEST 5" LINER & LINER LAP TO 1500 PSI FOR 30 MIN. HELD. PMP 40 BBLS HI-VIS SWEEP & CIRC OUT. WASH OUT STACK. FLUSH OUT SURF EQUIP W/WATER. RU HALLIBURTON. DISPLACE WELL W/274 BBLS 11.7 PPG BRINE. PMP 100 BBLS FRESH WATER AHEAD OF BRINE & HELD 700 PSI ON CSG. POH. LD 3-1/2" & 2-7/8" DP, CSG SCRAPER, & BIT. CLEAN OFF RIG FLOOR & CHANGE SAVER SUB. & Gas Cons. COITII11JssJOrl Anchorage WELL: 1Y-24 API: 50-029-22371 PERMIT: 93-72 PAGE: 6 06/29/93 (19) PARKER 245 TD: 8375'( 08/15/93 (22) DOWELL TD: 8380 O9/09/93 (20) NORDIC 1 TD: 8375 PB: 8282 09/10/93 (21) NORDIC 1 TD: 8375 PB: 8282 03/15/94 (23) NORDIC 1 TD: 8380 PB: 8282 o) RIG RELEASED 5"@ 8371' MW: 0.0 VIS: 0 ND BOP'S. NU TREE. SERVICE TOP DRIVE-CHANGE OIL-CHECK & TIGHTEN BOLTS IN TOP DRIVE RAILS. CHANGE SAVER SUB. LD 10 STDS 3-1/2" DP F/DERRICK. RELEASED RIG @ 1200 HRS 06/28/93. MOVE RIG F/1Y-24 TO 1Y-34. 5"@ 8371' DO ARCTIC PACK-SUCCESSFUL CHANGING RAMS TO 4" 5"@ 8371' MW:ll.7 NaCl/Br MOVE RIG F/1Y-34 TO 1Y-24. ACCEPT RIG @ 1430 HRS 09/08/93. ND TREE. SET TEST PLUG & NU BOPE. CHANGE OUT PIPE RAMS FROM 4" TO 3-1/2". TEST BOP FLANGES, CHOKE LINE CONNECTIONS, & 3-1/2" PIPE RAMS ALL TO 3000 PSI. RU SWS. TEST LUB TO 900 PSI. RIH @ 1745 HRS W/SWS & 25' PERF GUN, 4 SPF, 180 DEG PHASING. PERF F/8014'-8039'. OOH @ 1915 HRS. RD SWS. LOAD PIPE SHED W/TBG & TBG JEWELRY. DRIFT & TALLY SAME. RU FLOW LINE & FLOOR EQUIPMENT TO RUN TBG. RUN 3-1/2" COMPLETION EQUIP. MU XO TO 4" DSSHTC. MU TBG HGR & TEMPORARILY LAND TBG IN WELLHEAD TO ENABLE CHANGEOVER TO 4" RAMS. RIG RELEASED 5"@ 8371' MW:ll.7 NaC1/Br CHANGE 3-1/2" PIPE RAMS TO 4". TEST TO 3000 PSI. PULL & BREAK OUT TBG HGR. RUN 4" COMPLETION. LAND TBG, DROP BALL, RILDS. PMP DN BALL. PRESS TBG TO 2500 PSI & HOLD TO SET PKR. BLEED OFF TBG PRESS. BOLDS. PRESS TBG TO 1000 PSI & PU TBG STRING TO SHEAR PBR. PBR SHEARED @ 86K LBS UP WT. BLEED OFF TBG PRESS & RE-LAND. RILDS. PRESS TBG & ANN TO 1000 PSI, BLEED OFF SSSV CONTROL LINE PRESS TO CLOSE SSSV, BLEED TBG PRESS TO 500 PSI & MONITOR FOR 15 MIN SSSV TEST. OPEN SSSV & PRESS TBG & ANN TO 2500 PSI. HOLD & MONITOR FOR 15 MIN. ATTEMPT TO PRESS TBG TO 3000 PSI. ANN PRESS TRACKED TBG PRESS-ORIFICE VALVE LEAKING. WORK FLUID BOTH WAYS THROUGH ORIFICE, WITH & WITHOUT PRESS-NG. CALLED TO ORDER OUT SL UNIT TO REPLACE ORIFICE. NO CREWS AVAILABLE. VERIFY BURST STRENGTH OF 7" CSG & ALLOWABLE TOP-DOWN PRESS LIMIT ON PKR. PMP DN TBG TO SHEAR SHEAR-OUT SUB. SHEARED @ 3700 PSI. BLEED OFF PRESS, SET BPV, CLOSE SSSV. ND BOP STACK, NU TREE. TEST FLANGE & PACKOFF TO 5000 PSI. PULL BPV, SET TEST PLUG. TEST TREE TO 250 & 5000 PSI. PULL TEST PLUG, RU TO PMP. FREEZE PROTECT ANN BY CIRC DN 10 BBLS DIESEL. FREEZE PROTECT TBG BY BULLHEADING 6 BBLS DIESEL @ 1 BPM, 1500 PSI. RD PMP LINES, VAC BRINE F/PITS, SET BPV, SECURE WELL. RIG RELEASED @ 2100 HRS 09/09/93. MOVE RIG F/2E PAD TO 1Y PAD 5"@ 8371' MW:ll.7 NaC1/Br MOVE RIG F/2E-08 TO 1Y-24 RECEIVED WELL: 1Y-24 API: 50-029-22371 PERMIT: 93-72 PAGE: 7 03/16/94 (24) NORDIC 1 TD: 8380 PB: 8372 03/17/94 (25) PARKER 245 TD: 0'( 0) 03/18/94 (26) PARKER 245 TD: 8375'(8375) 03/19/94 (27) NORDIC 1 TD: 8375 PB: 8282 POH W/COMPLETION ASSEMBLY 5"@ 8371' MW:ll.7 NaCl/Br MOVE RIG F/2E-08 TO 1Y-24. SPOTTED RIG OVER 16-24 & RIGGED UP FLOWLINE. ACCEPTED RIG @ 0900 3/15/94. RU OTIS & TESTED LUBRICATOR TO 1000 PSI. PULLED BPV F/TUBING HANGER. RD OTIS. SITP 1050 PSI. SICP 1050 PSI. BLED OFF TUBING & CASING TO 0 PSI. DISPLACED TUBING W/ll.7 PPG BRINE. ATTEMPTED TO PUMP IN PERFS 8015-8040 W/2500 PSI. COULD NOT ESTABLISH INJECTION RATE. SI & PRESSURE BLED TO 1900 PSI IN 90 MINS. CIRC HOLE WITH 11.7 PPG BRINE @ 3 BPM. CHECKED FOR FLOW. CIRCULATED WITH 11.7 PPG BRINE @ 3 BPM. WELL DEAD. SET BPV IN TUBING HANGER. ND TREE. INSTALLED XO'S & TEST PLUG. NU BOP & TESTED BOPE TO 3000 PSI. RETRIEVED TEST PLUG. RETRIEVED BPV. LAID DOWN TUBING HANGER & LANDING JOINT. CIRCULATED BOTTOMS UP. POH STANDING BACK 4" TUBING WHILE CHANGING OUT SEAL RINGS & DRIFTING TO 3.36" 5"@ 8371' MW: 0.0 VIS: 0 SERVICE RIG. POH W/4" X 3-1/2" COMPLETION ASSEMBLY DRIFTING AND STRAPPING TUBING. LD SSSV & GLM'S. INSTALLED WEAR BUSHING & RU TO PU & RUN 3-1/2" DP. PU CAMCO PBR RETRIEVING TOOL. LATCHED TOF @ 7226'. WORKED FISH & CIRCULATED BOTTOMS UP 3 BPM @ 1000 PSI. PU ADDITIONAL 6K#. POH W/FISHING ASSEMBLY. FISH DRAGGING. 0-20K#. FISH HUNG UP WITH RETRIEVING TOOL @ 5895'. CIRCULATED & WORKED FISH FREE. POH W/FISHING ASSEMBLY. POH W/4-1/8" BIT 5"@ 8371' MW: 0.0 VIS: 0 SERVICED RIG. FINISHED POH W/FISHING ASSEMBLY. RECOVERED PBR, PKR & 3-1/2" TAILPIPE. PU & RIH W/4-1/8" MILL & 37 JOINTS 2-7/8" PAC DP ON 3'1/2" DP. TAGGED TOL @ 7264'. CONTINUED RIH & TAGGED PBD @ 8282'. CIRCULATED 3.4 BPM @ 1400 PSI. SECURED WELL & REPAIRED FLUID END SEAL ON PUMP. CIRCULATED BOTTOMS UP 3.4 BPM @ 1400 PSI. POH 2/4-1/8" BIT. RUNNING COMP ASSY 5"@ 8371' MW:ll.7 NaCl/Br SERV RIG. POH W/4-1/8" MILL LAYING DOWN 2-7/8" PAC DP. RIH W/4-3/4" DC'S & 3-1/2" DP. SLIP & CUT DRILL LINE. FIN RIH W/4-3/4" DC'S & 3-1/2" DP. CBU. POOH. LD 3-1/2" DP & 4-3/4" DC'S. RU HANDLING TOOLS & RIH W/SHEAR OUT SUB, 15 JTS 3-1/2" L-80 BTSC TAILPIPE, 2.75" D NIPPLE, BAKER FHL PKR & PBR, 2.812" W-1 NIPPLE, & GLM'S ON 3-1/2" J-55 TBG. RECEIVED Af"fR !'1 'i994 Anchorage WELL: 1Y-24 API: 50-029-22371 PERMIT: 93-72 PAGE: 8 03/20/94 (28) NORDIC 1 TD: 8375 PB: 8282 03/21/94 (29) NORDIC 1 TD: 8375 PB: 8282 O3/22/94 (30) NORDIC 1 TD: 8375 PB: 8282 POH W/BIT & SCRAPER 5"@ 8371' MW:ll.7 NaCl/Br SERV RIG. SHEEVES ON TRAVELING BLOCKS NOT ROTATING. THAWED OUT BLOCKS & CLEANED SAME. RIH W/BAKER FHL PKR ON 3-1/2" & 4" TBG. SET DOWN PKR @ 3170'. ATTEMPT TO WORK PKR FREE W/NO SUCCESS. SHEARED OFF PBR W/33K# OVER STRING WT. POOH W/TBG & PBR SEAL ASSY. RIH W/PBR SEAL ASSY. RIH W/PBR RETRIEVING TOOL ON 3-1/2" TBG. LATCHED PBR @ 3156' PU & SHEARED PKR @ 65K OVER STRING WT. POOH W/FHL PKR & TAILPIPE ON RETRIEVING TOOL. PKR HAD SET & RELEASED, NO INDICATIONS OF JUNK ON OR ABOVE PKR. RIH W/6-1/8" BIT & 7" CSG SCRAPER ON TBG. WORKED CSG SCRAPER F/3106'-3225' W/NO INDICATIONS OF JUNK OR DRAG. RIH W/6-1/8" BIT & 7" CSG SCRAPER TO TOL @ 7264'. CBU. POOH W/6-1/8" BIT & 7" CSG SCRAPER. SETTING BPV TO MOVE OFF RIG 5"@ 8371' MW:ll.7 NaCl/Br SERV RIG. FIN POH W/6-1/8" BIT & 7" CSG SCRAPER. MU COMPLETION ASSY AS PER DETAIL & RIH W/SAME ON 3-1/2" & 4" TBG. MU 4" CAMCO TRDP-4A SSSV & ATTACHED 1/4" CONTROL LINE. CONT RIH. MU TBG HGR & LAND SAME. RILDS. DROP BALL & ALLOWED TO FALL TO SHEAR OUT SUB. PRESS TBG TO 2300 PSI & SET BKR FHL PKR @ 7193'_ HELD PRESS FOR 30 MIN TO TEST TBG. BLED OFF PRESS. BOLDS. PU & SHEARED PBR W/20K# OVER STRING WT. RELANDED TBG. RILDS. PRESS ANN & TBG TO 1000 SPI. BLED OFF TBG TO 500 PSI & CLOSED SSSV TO TEST SAME. EQUALIZED TBG & ANN. OPENED SSSV. PRESS ANN & TBG TO 2000 PSI FOR 15 MIN. PRESS TBG TO 2500 PSI & HELD FOR 15 MIN. PRESS TBG TO 3800 PSI & SHEARED OUT BALL. BLED PRESS OFF OF TBG & ANN. CLOSED SSSV. BACKED OUT LANDING JT. SET BPV. ND BOP. NU TREE. RETRIEVED BPV. INSTALLED TEST PLUG. TESTED TREE TO 250/5000 PSI. TESTED PACKOFF TO 5000 PSI. RETRIEVED TEST PLUG. OPENED SSSV. RU & FREEZE PROTECTED AS FOLLOWS: PMP 11 BBLS DIESEL DOWN ANN WHILE TAKING RETURNS OUT TBG. PMP 6 BBLS DN TBG BULLHEADING INTO PERF @ 2 BPM @ 1750 PSI. DRAINED LINES & CLEANED PITS. RU BPV LUB. FINAL REPORT 5"@ 8371' MW:ll.7 NaCl/Br SET BPV IN TBG HGR. CLEANED PITS & MOVED OFF OF WELL. RIG RELEASED @ 0730 HRS 03/21/94. SIGNATURE: d~uperint~nt DATE: RECEIVED ,~,,:~,,,,-; ui! & Ga,; Cot~$. Corr~mission Anchora¢.¢, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIbofON WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~] GAS ~-~ SUSPENDED ~ ABANDONED [] SERVICE ~ /~"'~, 2 Name of Operator 7 Permit Number ARCO Alaska, lnc 93-72 ~.~ _ 3 Address 8 APl Number ~ P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22371 4 Location of well at sudace ~ ........ ~ ~ ~..-~ ,~-'~"~' r~-- 9 Unit or Lease Name 570' FNL, 1762' FWL, SEC 1, T 11N, R 9E, U~. ;~,':~7 E ~:~ ----"~:~c~ KUPARUK RIVER 167' FNL 2186' FEL, SEC 12, T 11N, R 9E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. KUPARUK RIVER RKB 106', PAD 65' GL ADL 25646 ALK 2577 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. ~ ] 15 Water Depth, if offshore ]16 No. of Completions 10-Jun-93 21-Jun-93 ~(COMP) ~ ~ ] NA feet MSL~ 1 17 Total Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey ' 20 Dep~ where SSSV set ~ 21 Thickness of permafrost 8375' MD, 6420' TVD 8282' MD, 6338' TVD YES ~ NO ~ 1795' feet MD~ 1500' APPROX ~ Type Electric or O~er Logs Run CDR, CDN, HLDT, CNTG, TDTP, CET, CBT, GCT 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP ~ HOLE SIZE C~RE~RD 16" 62.5ff H-40 SURF 121' 24" 218 SX PFC CMT 9.625" 47~/36~ L-80/J-55 SURF 4599' 12.25" 800 SX PERM E CMT, 480 SX CLASS G CMT TOP JOB 105 SX PFC CMT 7" 26~ L-80 SURF 7568' 8.5" 250 SX CLASS G CMT 5" 18~ L-80 7264' 8372' 6.125" i175 SX CLASS G CMT 24 Pedorations open to Production (MD+TVD of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE ~DEPTH SET (MD) PACKER SET (MD) 4"/3.5" 11~/9.3~ J-55/L-80 7691' 7202' SWS3-3/8" BH41B ~ 4SPF8015'-8040' MD' 6104'-6126'TVD ~ 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production JMe~od of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL RA~IO TEST PERIOD ~ FIowTubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28 CORE DATA or water. Submit core Brief description of lithology, porosi~, fractures, apparent dips and presence of oil, gas chips. ~EGE~V~D 00T 2 7 199 Aiaska 0il & Gas Cons. C0rnt'n[ss[0~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. -'.. ,. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP OF KUPARUK C 7 7 6 5' 5 8 89' 31. LIST OF A-FrACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEY 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed Title DATE O' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1Y-24 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25646 ALK 2577 50-029-22371 93-72 ACCEPT: 06/10/93 09:30 SPUD: 06/10/93 01:00 RELEASE: 09/09/93 09:00 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 06/11/93 (1) PARKER 245 TD: 3725' (3725) 06/12/93 (2) PARKER 245 TD: 4615' ( 890) 06/13/93 (3) PARKER 245 TD: 5770' (1155) 06/14/93 (4) PARKER 245 TD: 7576' (1806) DRILLING AHEAD 16"@ 121' MW:10.1 VIS: 49 MOVE RIG F/1Y-23 TO 1Y-24. Nil 20" DIVERTER. 41.55' FROM STARTING HEAD TO RT. FUNCTION TEST DIVERTER & VOLUME TEST KOOMEY. TEST WAIVED BY DOUG AMOS W/AOGCC. FILL STACK & CHECK FOR LEAKS. PU BHA & ORIENT TOOLS. TAGGED UP @ 110' C/O CONDUCTOR. DRILLING 12.25" HOLE F/121'-3725'. PREPARE TO CMT 9-5/8" CSG 16"@ 121' MW:10.2 VIS: 43 DRLG 12.25" HOLE F/3725'-4615'. CBU-SLUG DP. POH-TIGHT HOLE & SWABBING F/2317'-1700'. LD MWD, STAB'S & MUD MOTOR. SERVICE RIG. PU 12.25" H/O & BHA. RIH. WASH & RMR F/1700'-1950' FIN RIH TO BTM @ 4615'. NO FILL. CIRC & COND MUD & HOLE FOR 9-5/8" 47# L-80 BTC. CBU @ 3000' MU HGR & CMT HEAD. CIRC & COND MUD & HOLE F/CMT JOB. PUMPING @ 7 BPM @ 450 PSI & MOVING PIPE. DRILLING 9-5/8"@ 4598' MW: 8.8 VIS: 30 PU BHA. OREINT TOOLS, SHALLOW TEST, & CHANGE OUT JARS. RIH TO 4327'_ CUT DRLG LINE. RIH TO 4502'. CIRC. ATTEMPT TO TEST 9-5/8" CSG. VR PLUG LEAKING. CHANGE OUT PLUG. TEST 9-5/8" CSG TO 2050 PSI FOR 30 MIN. LEAKED OFF 50 PSI. DRLG PLUGS, FC @ 4517', GOOD CMT, SHOE @ 4598', & 10' NEW HOLE TO 4625'. CIRC & COND. MUD WT 8.5 PPG. RAN EMW TEST. PRESS UP TO 800 PSI-LEAKED OFF TO 600 PSI. PUMPED INTO FORMATION 1.5 BPM @ 700 PSI(1BBL). HELD 600 PSI FOR 10 MIN. EMW=ll.7 PPG @ 3586' TVD W/8.5 PPG MUD. DRLG 8.5" HOLE F/4625'-5770'. RAISING-MUD WT. 9-5/8"@ 4598' MW:ll.0 VIS: 51 DRLG 8.5" HOLE F/5770'-6842'. LOADED MUD SYSTEM W/8 PPB LIQUID CSG LCM-40/60 SCREENS ON BRANT SHAKERS. GREASE UP. DRLG 8.5" HOLE F/6842'-7576'. RAISED MUD WT TO 11 PPG. NO MUD LOSS. CBU-NO MLTD LOSS. SLUG DP. POH TO CHANGE BHA. TIGHT & SLIGHTLY SWABBING F/5070'-4788'. LD MOTOR & TURBINE. PU NEW BHA. PROGRAM LWD TOOLS & LOAD RA SOURCE. PU 3 STEEL DC'S. TIH SLOW FILL PIPE & MONITOR @ 2562', 5000', & 7524'. NO MUD LOSS. WASH TO BTM. HOLE PACKING OFF-CLEANED UP OK. CIRC & WATCH HOLE WHILE CBU. PITS APPEARED TO LOSE ABOUT 10 BBLS SLOWLY & THEN COME BACK UP. CHECKED FOR FLOW. HAD SMALL AMT OF FLOW. WELL IS BREATHING SLIGHTLY. CIRC & RAISE MUD WT SLOWLY. MUD WT GOING DOWN 11.2 PPG @ 0600. 4Jaska Oil & ,Sas Oons, Anchorage WELL: 1Y-24 API: 50-029-22371 PERMIT: 93-72 PAGE: 2 06/15/93 (5) PARKER 245 TD: 7576'( 06/16/93 (6) PARKER 245 TD: 7576'( o) 06/17/93 ( 7) PARKER 245 TD: 7576'( o) o) RAISING MUD WT. 9-5/8"@ 4598' MW:10.2 VIS: 40 CIRC @ 7576' & RAISE MUD WT SLOWLY TO 11.7 PPG. LOST RETURNS & 400 PSI PMP PRESS @ 09:30 HRS W/11.6-11.7 PPG. UNABLE TO SEE FLUID LEVEL ON BACKSIDE. PUMPED AWAY 60 BBLS @ 2 BPM. BROKE OFF TOP DRIVE-DP ON HARD VACCUM. POH W/16 STDS DP TO 6124'. SPOTTED 80 BBLS LCM PILL OUT BIT. PILL HAD 40 LB/BBL MICA, QUICK SEAL, & NUT PLUG. POH W/17 STDS DP TO 4530'. FILLED ANN W/31 BBLS WATER. CUT MUD WT IN PITS TO 10 PPG. PUMPED TOTAL 60 BBLS WATER DOWN ANN. HOLE STANDING FULL. CIRC & DISPLACE HOLE @ 4530' W/10 PPG MUD. LOST 110 BBLS PUMPING OUT 11.7 PPG MUD. NO MUD LOSS W/10.2 PPG MUD @ 4530'. BY PASS SHAKERS & LOAD SYSTEM W/15 PPB LCM @ 4530'. RIH W/15 STDS TO 5937'. CIRC & COND MUD. MUD WT 10.3 PPG W/15 PPB LCM-LOST 20 BBLS IN 45 MIN. SHUT PUMP DOWN-WELL FLOWING. RIH TO 7250'. TIGHT F/6450'-6470' FLUID LEVEL DROPPED, THEN FLOWED HARD AFTER GOING THRU TIGHT SPOT. WASHED TO BTM @ 7576'. CONTINUALLY LOSING MUD-LOST 53 BBLS WASHING TO BTM. CIRC & COND @ 7576' W/75% RETURNS PUMPING 4.2 BPM-450 PSI-10.5 PPG MUD. SHUT PUMPS DOWN-WELL FLOWED BACK 50 BBLS IN 15 MIN. CIRC @ 3 BPM-325 PSI & CUT MUD WT TO 10.2 PPG. NO MUD LOST. SHUT PUMPS DOWN-WELL FLOWING BACK 1 BPM EVERY 4 MINUTES. CIRC @ 6 BPM-790 PSI-RAISE MUD WT & MONITOR HOLE. MUD WT 10.6 PPG IN & 10.5 PPG OUT @ 0600 HRS. NO MUD LOST @ 10.6 PPG. SHUT PUMPS DOWN-WELL SLIGHTLY FLOWING-5 GAL/MIN. START RAISING WT TO 11.0 PPG @ 0600 HRS. RUNNING USIT LOG 9-5/8"@ 4598' MW:10.2 VIS: 39 CIRC & INCREASE MUD WT TO 11 PPG. LOST 60 BBLS IN 30 MIN. CIRC & CUT MUD WT BACK TO 10.2 PPG. SHORT TRIP TO CSG SHOE. WELL FLOWING SLIGHTLY. TIH SLOWLY TO 7576'. NO FILL. CBU. POOH TO CSG SHOE-INSPECTING HARDBANDING WITH TUBOSCOPE. CIRC & STRIP LCM OUT OF MUD @ CSG SHOE. FIN POOH INSPECTING HARDBANDING. DOWN LOAD RA SOURCE & LD ANADRILL TOOLS. RU SCHLUMBERGER & RUN USIT LOG. ND BOP 7"@ 7568' MW:10.3 VIS: 42 FIN RUNNING USIT LOG . RD SCHLUMBERGER. TIH-WIPER TRIP. 4' FILL. CBU. POOH TO RUN CSG. LD 3 DC & 3 ST. PULL WEAR RING. RU CSG TOOLS & HOLD SAFETY MEETING. RUN 179 JTS 7" 26# L-80 BTC AB-MOD. SHOE @ 7568' CIRC & COND MUD-ONLY PARTIAL RETURNS-75%. TEST LINES TO 4000 PSI. PMP 20 BBLS FLUSH, 20 BBLS SPACER, MIX & PMP 250 SX CLASS "G" CMT @ 15.8 PPG. DISPLACE W/RIG PMP. BMP PLUG TO 3500 PSI. FLOATS HELD. MONITOR WELL-FLOWING LESS THAN ONE BBL PER MINUTE & SLOWING DOWN. WELL: 1Y-24 API: 50-029-22371 PERMIT: 93-72 PAGE: 3 06/18/93 (8) PARKER 245 TD: 7576'( o) 06/19/93 (9) PARKER 245 TD: 7870' ( 294) 06/20/93 (10) PARKER 245 TD: 8145' ( 275) 06/21/93 (11) PARKER 245 TD: 8380' ( 235) DRILLING FLOAT EQUIP 7"@ 7568' MW:ll.9 VIS: 54 PU STACK & SET SLIPS W/ll5K. MAKE ROUGH CUT & LD LANDING JT. RD CSG EQUIP. ND STACK. MAKE FINAL CUT. INSTALL PACKOFF & 11" 3M X 7-1/16" 5M TBG HEAD. TEST TO 3000 PSI-OK. NU BOP. CHANGE RAMS TO 3-1/2". CHANGE TOP DRIVE & IRON ROUGHNECK TO 3-1/2". TEST BOPE TO 300 PSI & 3000 PSI. JOHN SPAULDING W/AOGCC WAIVED WITNESSING TEST. SET WEAR RING. INJECT 100 BBLS WATER & 70 BBLS DIESEL INTO ANN @ 3 BPM W/300 PSI. CUT & SLIP 105' DRILL LINE WHILE INJECTING. SERVICE RIG. MU BHA & PU 3-1/2" DP & TIH. TAG CMT STRINGER @ 7470'. CIRC & COND MUD TO 11.7 PPG. TEST 7" CSG TO 3500 PSI FOR 30 MIN-OK. DRILLING 7"@ 7568' MW:ll.6 VIS: 45 DRILL FC, CMT, FS, & 10' NEW FORMATION TO 7586'-5734' TVD. FIT @ 7586' W/ll.8 PPG @ 250 PSI. EMW=12.6 PPG. DRILL F/7586'-7870'/5955' TVD. DRILLING 7"@ 7568' MW:12.2 VIS: 47 DRILL F/7870'-7911' SHORT TRIP TO SHOE-NO FILL. MUD WT CUT F/ll.8 PPG TO 16.4 PPG. DRILL F/7911'-8102' CBU. DROP SURVEY. PMP SLUG. POOH. RETRIEVE SURV. MU NEW BIT & TIH. NO FILL. DRILL F/8102'-8145'. MUD WT CUT TO 11.2 PPG. @ BU. SHORT TRIP 7"@ 7568' MW:12.2 VIS: 47 DRILL F/8145'-8380' TD. 06/22/93 (12) PARKER 245 TD: 8380'( 0) FISHING 7"@ 7568' MW:ll.8 VIS: 47 SHORT TRIP TO CSG SHOE. TIGHT SPOT F/8180'-8148' TIH TO 8297'. PIPE STUCK AFTER MAKING CONECTION & WASHING DOWN F/8287'-8297'. COULD NOT ROTATE, SLACK OFF OR PU. WORK PIPE & CUT MUD WT TO 11.8 PPG. JARS STOPPED HITTING. SPOTTED EZ-SPOT PILL IN OPEN HOLE. LET PILL SOAK FOR 2 HRS, & THEN STARTED WORKING PIPE. CONT WORKING PIPE & MOVING PILL EVERY HOUR UNTIL APRS ARRIVED. RU SCHLUMBERGER & APRS & LOCATE FREEPOINT @ 7768' WLM-TOP OF DC. MU BACKOFF CHARGE & TIH. SET CHARGE @ 7768' & BACKOFF. POOH W/WL. CBU. BLED OFF 200 PSI (975-775)0FF 7" CSG & ANN ON 1Y-17. TOTAL OF 4 BBLS. PRESS BLED DOWN TOGETHER & BOTH BUILT UP IMMEDIATELY. SHUT WELL IN & SECURED. aiaska Oil & Gas CoBs, Anchorage WELL: 1Y-24 API: 50-029-22371 PERMIT: 93-72 PAGE: 4 06/23/93 (13) PARKER 245 TD: 8380'( 06/24/93 (14) PARKER 245 TD: 7583'( o) o) 06/25/93 (15) PARKER 245 TD: 8100' ( 517) POH 7"@ 7568' MW:ll.8 VIS: 50 CIRC & COND MUD. SLUG DP. POH W/84 STS 3-1/2" DP. LD SHOT JT 3-1/2" DP. TOP OF FISH @ 7773'-4-3/4" DC W/3-1/2" IF BOX UP. FISH IS ENTIRE 4-3/4" BHA-523.5'LENGTH. PU 3-1/2" CUT LIP SCREW-IN SUB, BUMPER SUB, OIL JARS, 12-4-5/8" DC'S, ACCELERATOR SUB, & RIH TO 7763'. CBU. MUD WT 11.7+. NO TRIP GAS-WASHED TO TOP OF FISH @ 7773'-NO FILL. ATTEMPT TO SCREW INTO FISH-COULD NOT TAG TOP OF FISH BUT ROLLED OFF-COULD GO DOWN BESIDE FISH 2-3'. UNABLE TO SCREW IN. SLUG DP. POH. LD SCREW-IN SUB. PU 5-3/4" OD SKIRTED SCREW-IN SUB & TIH. WASH 70' TO FISH-SCREWED INTO FISH @ 7773'. BROKE CIRC THRU FISH. JARRED UP & DOWN ON FISH PULLING 175,000 OVER STRING WT. FISH NEVER MOVED. JARS FAILED AFTER 2-1/2 HRS. HOLE PACKED OFF-PUMPING IN W/NO RETURNS. RU SCHLUMBERGER & APRS TO BACK OFF. RIH W/STRING SHOT. BACKED OFF @ TOP OF FISH @ 7773'. POH W/WL. SET LUB BACK. POH W/3 STDS DP-UP IN 7" CSG. CBU. RD SCHLUMBERGER & APRS OUT OF DERRICK. POH W/FISHING TOOLS. DRESS OFF CMT PLUG 7"@ 7568' MW:ll.8 VIS: 51 FIN POH-LD TOOLS. LEFT 3-1/2" SCREW IN SUB IN HOLE. 3-1/2" IF PIN LOOKING UP. WO 2-7/8" TBG. PU 2-7/8" TBG. GREASE UP. FIN PU 2-7/8" TBG. RIH W/ 3-1/2" DP TO 7765' CIRC & COND MUD. MUD BALANCED. TEST HOWCO LINES TO 2500 PSI. HALLIBURTON SPOTTED 100 SX CLASS "G" IN 6.125" OPEN HOLE & 7" CSG F/7765'-7241'. MIXED CMT @ 16.1 PPG W/10 BBLS WATER AHEAD & 2.5 BBLS WATER BEHIND CMT DISPLACED W/44.5 BBLS MUD, JC @ 1500 HRS. PULLED 3 STDS TO 7483' REVERSED OUT DP. RECOVERED + 10 BBLS WATER-NO CMT. CI~C OUT DOWN DP. SLUG DP. POH W/DP & LD 2-7/8" TBG. PULL WEAR BUSHING. RU TEST EQUIP. TEST HYDRIL, ALL RAMS, CHOKE MAN, CHOKE & KILL LINE VALVES, TOP DRIVE & FLOORS VALVES TO 300 & 3000 PSI-VOLUME TEST KOOMEY. RD TEST EQUIP. INSTALL WEAR BUSHING. PU BHA, ORIENT TOOLS, SHALLOW TEST MWD. RIH W/6.125" BIT. TAGGED UP @ 7479'. CIP @ 1400 HRS 06/23/93. DRLG GOOD CMT F/7479'-7568' IN 7" CSG & F/7568'-7583' IN OPEN HOLE. AT 7583' ROP 100'/HR, llK WOB, 300 RPM. DRILLING 7"@ 7568' MW:ll.7 VIS: 46 DRESS OFF CMT PLUG F/7583'-7683'_ ROP 40-60'/HR W/10K WOB & 300 RPM. ORIENT & SLIDE F/7683' (KOP)-7740'. ROTARY DRLG 6.125" W/MOTOR F/7740'-7886'. ADT 7.3 HRS. CBU & SLUG DP. POH FOR BIT-LD MWD, SHORT NM DC, DOT SUB, & 3- 4-5/8" DC'S. MU NEW BIT & BHA. TIH TO SHOE. CUT DRLG LINE. RIH TO 7675'. WASH & REAM THROUGH KOP & TO BTM-NO FILL. DRLG 6.125" HOLE F/7886'-8100'. NO TRIP GAS. ADT 4.45 HRS. Anchorage. WELL: 1Y-24 API: 50-029-22371 PERMIT: 93-72 PAGE: 5 06/26/93 (16) PARKER 245 TD: 8375' ( 275) 06/27/93 (17) PARKER 245 TD: 8375'( o) 06/28/93 (18) PARKER 245 TD: 8375'( o) TIH 7"@ 7568' MW:ll.7 VIS: 45 DRLG 6.125" HOLE F/8100'-8375'. CBU-SLUG DP. MADE 10 STD SHORT TRIP TO SHOE. GREASE UP. RIH. WASH 38' TO BTM-NO FILL. CIRC & COND MUD & HOLE FOR LOGS. NO TRIP GAS. DROP SURVEY. SLUG DP. POH FOR LOGS-LD NM DP, STAB, MN DC'S, & MUD MOTOR. SLM-NO CORR. RU SCHLUMBERGER-RAN DIL/LDT/CNL/GR/AMS FROM WLTD 8368'-7568'. RD SCHLUMBERGER. PU BHA & START RIH. POH W/SETTING TOOL 5"@ 8371' MW:ll.7 VIS: 46 FIN TIH-NO FILL. CIRC & COND MUD & HOLE. UNLOADING LARGE SHALE SLIVERS. SLUG DP. DROP 2-3/8 OD RABBITT. POH TO RUN 5" LINER. LD 2-STAB. RU CASERS. HOLD SAFTETY MEETING. RAN 25 JTS 5" 18# L-80 LTC 8R CSG, TIW HYDROLIC SET HGR-LENGTH 1107'. PMP 30 BBLS MUD & CLEARED LINER. WT 15,000 LBS. RIH W/DP TO 7" SHOE & FILLED DP EVERY 10 STDS. CIRC @ SHOE. MU CMT HEAD ON JT DP. FRIH W/5" LINER & MU CMT'G HEAD. WASHED 25' TO BTM.. CIRC & RECIP LINER-HOLE PACKING OFF-WORK PIPE & CIRC UNTIL HOLE CLEANED UP. PMP 500 BBLS @ 3 BPM & 850 PSI. FULL RETURNS. BATCH MIX CMT. TEST HOWCO LINES. HALLIBURTON CMT'D 5" LINER PUMPING 20 BBLS 12.5 PPG SPACER, 175 SX CLASS "G" W/ADDITIVES(38 BBLS SLURRY), DROPPED PLUG-DISPLACED W/67.5 BBLS MUD. BMP PLUG. PRESS UP TO 3500 PSI & SET LINER HGR W/SHOE @ 8371', FC @ 8324', & LC @ 8282' CIP @ 0200 HRS. ATTEMPT TO RELEASE SETTING TOOL W/500 P~I ON DP. UNABLE TO RELEASE. PRESS UP TO 2000 PSI ON DP-WORKED PIPE & LOST DP PRESS & PIPE MOVE FREE UP HOLE 40' FREE. PULL 90' W/30-40K DRAG-COULD BE PULLING LINER UP HOLE. PMP DOWN DP-PRESS UP TO 1000 PSI-NO RETURNS-STILL IN LINER OR PACKED OFF-ROTATE W/PRESS-PIPE CAME FREE @ 7121'. CBU @ 7061' REC 10-12 BBLS GOOD CMT. SLUG DP. POH W/SETTING TOOL. CHANGE SAVER SUB 5"@ 8371' MW: 0.0 VIS: 0 PU 6.125" BIT, CSG SCRAPER, BS, 3-4-5/8" DC'S, JARS, 2-4-5/8" DC'S & RIH TO 7022'. WASHED F/7022' T0L @ 7267'. HAD ABOUT 20' GREEN CMT ON TOP OF LINER. CIRC HOLE CLEAN @ 7267'. SLUG DP. POH & LD 4-5/8" DC'S. PU 4.125" GOPHER MILL, 5" CSG SCRAPER, 39 JTS 2-7/8" DP. RIH W/3-1/2" DP TO TOL @ 7267'_ TAGGED UP @ 7274'. CO CMT STRINGER F/7274'-7293'. FIN TIH. TAGGED UP ON LC @ 8284' PBTD. CIRC-SHUT WELL IN-TEST 5" LINER & LINER LAP TO 1500 PSI FOR 30 MIN. HELD. PMP 40 BBLS HI-VIS SWEEP & CIRC OUT. WASH OUT STACK. FLUSH OUT SURF EQUIP W/WATER. RU HALLIBURTON. DISPLACE WELL W/274 BBLS 11.7 PPG BRINE. PMP 100 BBLS FRESH WATER AHEAD OF BRINE & HELD 700 PSI ON CSG. POH. LD 3-1/2" & 2-7/8" DP, CSG SCRAPER, & BIT. CLEAN OFF RIG FLOOR & CHANGE SAVER SUB. WELL: 1Y-24 API: 50-029-22371 PERMIT: 93-72 PAGE: 6 06/29/93 (19) PARKER 245 TD: 8375'( o) RIG RELEASED 5"@ 8371' MW: 0.0 VIS: 0 ND BOP'S. NU TREE. SERVICE TOP DRIVE-CHANGE OIL-CHECK & TIGHTEN BOLTS IN TOP DRIVE RAILS. CHANGE SAVER SUB. LD 10 STDS 3-1/2" DP F/DERRICK. RELEASED RIG @ 1200 HRS 06/28/93. MOVE RIG F/1Y-24 TO 1Y-34. 09/09/93 (20) TD: 8375 PB: 8282 CHANGING RAMS TO 4" 5"@ 8371' MW:ll.7 NaC1/Br MOVE RIG F/1Y-34 TO 1Y-24. ACCEPT RIG @ 1430 HRS 09/08/93. ND TREE. SET TEST PLUG & NU BOPE. CHANGE OUT PIPE RAMS FROM 4" TO 3-1/2". TEST BOP FLANGES, CHOKE LINE CONNECTIONS, & 3-1/2" PIPE RAMS ALL TO 3000 PSI. RU SWS. TEST LUB TO 900 PSI. RIH @ 1745 HRS W/SWS & 25' PERF GUN, 4 SPF, 180 DEG PHASING. PERF F/8014'-8039'. OOH @ 1915 HRS. RD SWS. LOAD PIPE SHED W/TBG & TBG JEWELRY. DRIFT & TALLY SAME. RU FLOW LINE & FLOOR EQUIPMENT TO RUN TBG. RUN 3-1/2" COMPLETION EQUIP. MU XO TO 4" DSSHTC. MU TBG HGR & TEMPORARILY LAND TBG IN WELLHEAD TO ENABLE CHANGEOVER TO 4" RAMS. 09/10/93 (21) TD: 8375 PB: 8282 RIG RELEASED 5"@ 8371' MW:ll.7 NaC1/Br CHANGE 3-1/2" PIPE RAMS TO 4". TEST TO 3000 PSI. PULL & BREAK OUT TBG HGR. RUN 4" COMPLETION. LAND TBG, DROP BALL, RILDS. PMP DN BALL. PRESS TBG TO 2500 PSI & HOLD TO SET PKR. BLEED OFF TBG PRESS. BOLDS. PRESS TBG TO 1000 PSI & PU TBG STRING TO SHEAR PBR. PBR SHEARED @ 86K LBS UP WT. BLEED OFF TBG PRESS & RE-LAND. RILDS. PRESS TBG & ANN TO 1000 PSI, BLEED OFF SSSV CONTROL LINE PRESS TO CLOSE SSSV, BLEED TBG PRESS TO 500 PSI & MONITOR FOR 15 MIN SSSV TEST. OPEN SSSV & PRESS TBG & ANN TO 2500 PSI. HOLD & MONITOR FOR 15 MIN. ATTEMPT TO PRESS TBG TO 3000 PSI. ANN PRESS TRACKED TBG PRESS-ORIFICE VALVE LEAKING. WORK FLUID BOTH WAYS THROUGH ORIFICE, WITH & WITHOUT PRESS-NG. CALLED TO ORDER OUT SL UNIT TO REPLACE ORIFICE. NO CREWS AVAILABLE. VERIFY BURST STRENGTH OF 7" CSG & ALLOWABLE TOP-DOWN PRESS LIMIT ON PKR. PMP DN TBG TO SHEAR SHEAR-OUT SUB. SHEARED @ 3700 PSI. BLEED OFF PRESS, SET BPV, CLOSE SSSV. ND BOP STACK, NU TREE. TEST FLANGE & PACKOFF TO 5000 PSI. PULL BPV, SET TEST PLUG. TEST TREE TO 250 & 5000 PSI. PULL TEST PLUG, RU TO PMP. FREEZE PROTECT ANN BY CIRC DN 10 BBLS DIESEL. FREEZE PROTECT TBG BY BULLHEADING 6 BBLS DIESEL @ 1 BPM, 1500 PSI. RD PMP LINES, VAC BRINE F/PITS, SET BPV, SECURE WELL. RIG RELEASED @ 2100 HRS 09/09/93. SIGNATURE: DATE: SUB - S URFA CE DIRECTIONAL SURVEY UIDANCE NICi OI:ILIqED ITl OOL Date_ //_~/~1 Company Well Name Field/Location Job Reference No. 93314 Lo~Kled BV: FORMICA ARCO ALASKA, INC. 1Y-24 (570' FNL, 1762' Fkl, SEC 1, T11N, RgE, UN) KUPARUK, NORTH SLOPE, ALASKA OCT ~ 7 199~ ~,~aska Oil a Gas Cons. 6om. rr_~issio;~ A~chorage Date 16-dUL-93 Computed By: DEES SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 1Y-24 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE: 16-JUL-g3 ENGINe: JEFF FORMICA METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 14 DEG 27 MIN EAST COMPUTATION DATE' 27-JUL-93 PAGE I ArCO ALASKA, INC. 1Y-24 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 16-JUL-93 KELLY BUSHING ELEVATION' 106.00 FT ENGINEER' JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 100 O0 2OO O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 -106 O0 100 O0 -6 200 O0 94 299 99 193 399 91 293 499 47 393 598 51 492 696 31 590 792 35 686 887 25 0 0 N 0 0 E O0 0 11 S 27 6 E O0 0 14 S 51 59 E 99 1 3 S 23 11 E 91 3 43 S 4 53 E 47 6 38 S 3 38 E 51 9 42 S 2 16 E 31 14 21 S 1 40 E 35 17 24 S 2 31 E S 336E 781.25 19 23 0 O0 0 24 0 5O I 3O 5 21 14 31 27 75 47 97 75 14 106 03 0 O0 0 13 0 07 2 82 3 48 2 18 4 86 4 47 1 77 I 71 0 O0 N 0 21S 0 42 S I 10 S 4 99 S 14 22 S 27 91 S 48 63 S 76 43 S 107 90 S 0 O0 E 0 12 E 0 37 E 0 92 E I 52 E 2 18 E 2 87 E 3 50 E 4 52 E 6 000 N 0 0 E 0 0 1 5 14 28 48 76 18 E 108 25 S 30 15 E 56 S 41 22 E 44 S 40 1E 21 S 16 58 E 38 S 8 42 E O6 S 5 53 E 76 S 4 7 E 57 S 3 23 E 07 S 3 17 E 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 O0 1073 02 967 O0 1163 O1 1057 O0 1251 15 1145 O0 1336 79 1230 GO 1419 92 1313 O0 1499.73 1393 GO 1576.32 1470 O0 1649.54 1543 O0 1720.01 1614 981 O0 875 O0 21 23 02 24 32 O1 26 58 15 29 34 79 32 18 92 35 21 73 38 39 32 41 26 54 44 33 O1 45 34 S S 9 E S 6 14 E S 7 30 E S 9 57 E S 12 25 E S 13 11 E S 14 6 E S 1S 18 E S 16 0 E S 15 29 E 140 27 178 94 222 13 269 10 320 376 436 500 568 639 64 16 38 66 73 66 2 52 2 8O 2 31 3 89 1 84 3 66 2 9O 2 85 2 26 0 52 142 56 S 181 48 S 224 76 S 271 44 S 322 02 S 376 21S 434 71S 496 92 S 562 45 S 63O 8 90 E 142 84 S 3 34 E 12 17 25 35 47 61 77 96 73 S 115 82 E 181 95 E 225 03 E 272 29 E 323 51E 379 81E 439 98 E 503 49 E 570 77 E 641 93 S 4 2 E 48 S 4 34 E 59 S 5 16 E 95 S 6 1S E 20 S 7 12 E 09 S 8 6 E O0 S 8 55 E 66 S 9 44 E 26 S 10 24 E 2000 O0 1789 86 1683 86 45 44 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 1859 O0 1929 O0 1998 O0 2067 O0 2135 O0 2203 O0 2272 O0 2340 O0 2409 55 1753 O0 1823 42 1892 20 1961 27 2029 64 2097 08 2166 58 2234 O1 2303 S 15 12 E 55 45 59 S 14 56 E 782 O0 46 S S 14 6 E 854 42 46 2 S 13 53 E 926 20 47 8 S 15 47 E 999 27 47 1 S 15 50 E 1072 64 46 47 S 15 31 E 1145 08 46 47 S 15 23 E 1218 58 46 48 S 15 9 E 1291 O1 46 43 S 14 47 E 1364 711 22 93 87 85 43 67 63 52 37 29 0 22 0 41 0 64 0 6o 0 93 0 34 0 21 0 18 0 37 0 55 699 76 S 134 62 E 712 59 S 10 53 E 769 838 908 978 1049 1119 1189 1259 1330 O1S 153 65 S 171 53 S 188 71S 207 17 S 227 43 S 246 71S 266 99 S 285 44 S 304 28 E 784 34 E 855 61E 927 10 E 1000 17 E 1073 88 E 1146 28 E 1219 48 E 1291 30 E 1364 13 S 11 16 E 97 S 11 33 E 90 S 11 44 E 38 S 11 57 E 48 S 12 13 E 33 S 12 26 E 15 S 12 37 E 93 S 12 46 E 80 S 12 53 E 3000.00 2477.87 2371 87 46 21 3100.00 2546.89 2440 3200.00 2616.01 2510 3300.00 2685.37 2579 3400,00 2754.75 2648 3500.00 2824.16 2718 3600.00 2893.71 2787 3700.00 2963.47 2857 3800.00 3032.81 2926 3900.00 3102.27 2996 89 46 23 O1 46 12 37 46 2 75 46 6 16 45 56 71 45 51 47 45 54 81 46 13 27 45 48 S 14 36 E 1436.80 S 15 35 E 1509.16 S 17 29 E 1581.35 S 16 58 E 1653.31 S 16 52 E 1725 25 S 16 49 E 1797 18 S 16 51E 1868 97 S 16 51 E 1940 56 S 16 55 E 2012 54 S 17 2 E 2084 42 0 32 2 63 0 49 0 20 0 13 0 o7 0.53 0.62 O. 38 0.42 1400 58 S 322.71 E 1437.28 S 12 58 E 1470 1539 1608 1677 1746 1815 1883 1952 2021.40 S 508 54 S 341 17 E 1509.60 S 13 4 E 67 S 362 49 S 383 38 S 404 28 S 425 07 S 446 65 S 466 58 S 487 24 E 1581.71 S 13 14 E 53 E 1653 58 S 13 25 E 47 E 1725 46 S 13 33 E 34 E 1797 34 S 13 41 E 10 E 1869 09 S 13 48 E 89 E 1940 65 S 13 55 E 82 E 2012 60 S 14 2 E 79 E 2084 45 S 14 8 E COMPUTATION DATE' 27-JUL-93 PAGE 2 ARCO ALASKA, INC. 1Y-24 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY- 16-JUL-93 KELLY BUSHING ELEVATION' 106.00 FI- ENGINEER' JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3172 20 3066.20 45 26 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3242 O0 3313 O0 3385 O0 3457 O0 3529 O0 3600 O0 3671 O0 3741 O0 3811 65 3136.65 45 4 53 3207.53 44 33 15 3279.15 44 9 19 3351,19 43 43 38 3423.38 44 15 39 3494.39 44 53 11 3565.11 45 8 65 3635.65 45 11 99 3705.99 45 25 S 17 4 E 2155 83 S 17 10 E 2226 S 16 27 E 2297 S 14 21E 2366 S 14 16 E 2436 S 13 52 E 2505 S 13 15 E 2575 S 13 28 E 2646 S 13 32 E 2717 S 13 41E 2788 72 19 97 32 52 92 60 48 55 0.79 0 26 2 73 0 55 0 46 1 78 0 56 0 19 0 35 0 51 2089.74 S 529 77 E 2155 84 S 14 14 E 2157 56 S 550 2225 2292 2359 24.26 2495 2563 2632 2701 O1S 571 38 S 589 59 S 606 68 S 623 18 S 639 96 S 656 89 S 672 98 S 689 65 E 2226 35 E 2297 51E 2366 64 E 2436 59 E 2505 86 E 2575 21E 2646 76 E 2717 46 E 2788 72 S 14 19 E 19 S 14 24 E 97 S 14 25 E 32 $ 14 25 E 52 S 14 25 E 92 S 14 23 E 60 S 14 21E 48 S 14 20 E 55 S 14 19 E 5000.00 3882 28 3776 28 45 20 5100.00 3952 5200.00 4021 5300.00 4091 5400.00 4160 5500.00 4230 5600.00 4299 5700.00 4369 5800.00 4439 5900.00 4508 25 3846 25 45 47 91 3915 91 45 53 43 3985 43 46 1 87 4054 87 46 2 32 4124 32 46 0 81 4193 81 45 57 35 4263.35 45 52 07 4333.07 45 43 89 4402.89 45 44 S 13 54 E 2859 67 S 16 9 E 2931 S 16 13 E 3002 S 16 15 E 3074 S 16 17 E 3146 S 16 26 E 3218 S 16 37 E 3290 S 16 43 E 3362 S 16 50 E 3433 S 16 53 E 3505 11 81 66 58 50 36 17 80 33 1 21 0 4O 0 19 0 25 0 24 0 15 0 25 0 18 0 55 0 11 2771 09 S 706 28 E 2859 68 S 14 18 E 2840 2908 2977 3047 3116 3185 3253 3322 3391 05 S 724 95 S 744 98 S 764 06 S 785 11S 8O5 05 S 825 90 S 846 55 S 867 06 S 887 92 E 2931 92 E 3002 98 E 3O74 13 E 3146 37 E 3218 80 E 3290 40 E 3362 06 E 3433 81E 3505 11 S 14 19 E 82 S 14 22 E 66 S 14 24 E 58 S 14 27 E 50 S 14 29 E 37 S 14 32 E 18 S 14 35 E 82 S 14 38 E 35 S 14 40 E 6000 O0 4578 76 4472.76 45 33 6100 6200 6300 6400 6500 6600 67OO 6800 6900 O0 4648 O0 4720 O0 4791 O0 4864 O0 4936 O0 5009 O0 5082 O0 5156 O0 .5230 89 4542.89 45 22 05 4614 05 44 3 96 4685 96 43 59 04 4758 04 43 47 43 4830 43 43 25 24 4903 24 43 7 67 4976 67 42 27 67 5050 67 42 6 78 5124 78 42 25 S 17 7 E 3576 80 S 17 23 E 3648 S 16 46 E 3718 S 16 57 E 3787 S 17 14 E 3856 S 16 25 E 3925 S 16 21E 3994 S 16 33 E 4062 S 17 7 E 4129 S 16 15 E 4196 O0 18 61 85 77 29 13 33 40 0 . 42 O. 52 0.31 O. 23 O. 42 1.47 0.83 O. 62 0.51 1.79 3459 48 S 908 70 E 3576 84 S 14 43 E 3527 3594 3661 3727 3793 3859 3924 3988 4052 56 S 929 73 S 950 25 S 970 50 S 990 45 S 1011 28 S 1030 38 S 1049 78 S 1068 98 S 1088 85 E 3648 42 E 3718 54 E 3787 91E 3856 17 E 3925 30 E 3994 54 E 4062 92 E 4129 56 E 4196 05 S 14 46 E 25 S 14 49 E 70 S 14 51E 96 S 14 53 E 91 S 14 56 E 44 S 14 57 E 30 S 14 58 E 52 S 15 0 E 62 S 15 2 E 7000 O0 5304 52 5198.52 42 24 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 5378 O0 5452 O0 5527 O0 5602 O0 5680 O0 5757 O0 5834 O0 5918 00 6004 59 5272.59 42 1 98 5346.98 41 55 15 5421.15 42 34 45 5496.45 39 43 14 5574.14 38 30 10 5651.10 40 40 54 5728.54 36 29 72 5812.72 31 3 59 5898.59 30 35 S 15 57 E 4263 93 S 16 25 E 4331 S 16 54 E 4397 S 15 58 E 4464 S 14 57 E 4530 S 14 27 E 4593 S 13 57 E 4657 S 16 25 E 472O S 19 10 E 4774 S 19 51E 4825 08 87 89 66 61 45 67 44 46 0 50 0 34 3 12 1 19 1 47 1 59 1 30 9 99 0 79 0 69 4117 96 S 1107 02 E 4264 16 S 15 3 E 4182 4246 4310 4374 4435 4496 4557 4609 4657 47 S 1125 51S 1144 77 S 1164 18 S 1181 13 S 1197 90 S 1213 95 S 1229 14 S 1246 37 S 1264 76 E 4331 88 E 4398 11E 4465 58 E 4530 35 E 4593 48 E 4657 93 E 472O 75 E 4774 05 E 4825 33 S 15 4 E 14 S 15 5 E 19 S 15 7 E 96 S 15 7 E 91 S 15 6 E 75 S 15 6 E 98 S 15 6 E 78 S 15 8 E 85 S 15 11E COMPUTATION DATE: 27-JUL-93 PAGE 3 ARCO ALASKA, INC. 1Y-24 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 16-JUL-93 KELLY BUSHING ELEVATION: 106.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 8000.00 6090.99 5984.99 29 57 S 18 23 E 4875.65 8100.00 6177.98 6071.98 29 10 S 17 41 E 4924.89 8200.00 6265.72 6159.72 28 11 S 15 33 E 4972.79 8300.00 6353.87 6247.87 28 11 S 15 33 E 5020.01 8375.00 6419.97 6313.97 28 11 S 15 33 E 5055.43 0.70 4704.97 S 1280.45 E 4876.09 S 15 13 E 0.98 4751.90 S 1295.65 E 4925.37 S 15 15 E 0.00 4797.81 S 1309.45 E 4973.29 S 15 16 E 0.00 4843.31 S 1322.10 E 5020.52 S 15 16 E 0.00 4877.44 S 1331.59 E 5055.94 S 15 16 E COMPUTATION DATE: 27-JUL-93 PAGE 4 ARCO ALASKA, INC. 1Y-24 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 16-JUL-g3 KELLY BUSHING ELEVATION: 106.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 8375 0 O0 -106 O0 0 0 N 0 0 E O0 981 O0 1789 O0 2477 O0 3172 O0 3882 O0 4578 O0 5304 O0 6090 O0 6419 O0 875 86 1683 87 2371 20 3066 28 3776 76 4472 52 5198 99 5984 97 6313 O0 21 23 S 5 9 E 140 86 45 44 S 15 12 E 711 87 46 21 S 14 36 E 1436 20 45 26 S 17 4 E 2155 28 45 20 S 13 54 E 2859 76 45 33 S 17 7 E 3576 52 42 24 S 15 57 E 4263 99 29 57 S 18 23 E 4875 97 28 11 S 15 33 E 5055 0 O0 27 22 80 83 67 80 93 65 43 0 oo 2 0 0 0 1 0 0 0 0 o O0 N 52 142 22 699 32 1400 79 2089 21 2771 42 3459 50 4117 70 4704 O0 4877 0 O0 E 56 S 8 76 S 134 58 S 322 74 S 529 09 S 706 48 S 908 96 S 1107 97 S 1280 44 S 1331 90 E 142 62 E 712 71E 1437 77 E 2155 28 E 2859 70 E 3576 02 E 4264 45 E 4876 59 E 5055 0 O0 N 0 0 E 84 S 3 34 E 59 S 10 53 E 28 S 12 58 E 84 S 14 14 E 68 S 14 18 E 84 S 14 43 E 16 S 15 3 E 09 S 15 13 E 94 S 15 16 E COMPUTATION DATE' 27-JUL-93 PAGE ARCO ALASKA, INC. 1Y-24 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 16-JUL-93 KELLY BUSHING ELEVATION' 106.00 FT ENGINEER' JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 106 O0 206 O0 306 O1 406 11 506 58 607 60 710 O1 814 32 919 90 0 O0 -106.00 106 O0 206 O0 306 O0 406 O0 506 O0 606 O0 706 O0 806 O0 906 O0 0 0 N 0 0 E 0.00 0 10 S 27 53 E 100.00 0 15 S 5I 21E 200.00 1 12 S 20 11E 300.00 3 56 S 4 37 E 400.00 6 47 S 3 32 E 500.00 10 3 S 2 6 E 600.00 14 48 S 1 46 E 700.00 17 39 S 2 40 E 800,00 19 45 S 3 57 E 0 O0 0 25 0 52 1~ 43 5 61 15 06 29 O0 50.42 79.36 112.57 0 O0 0 24 0 18 2 72 3 67 2 O1 4 15 4 65 1 89 2 37 0.00 N 0.23 S 0.43 S 1.22 S 5.40 S 14.98 S 29.20 S 51.15 S 80.74 S 114.54 S 0 O0 E 0 13 E 0 39 E 0 97 E 1 56 E 2 23 E 2 92 E 3 58 E 4 71E 6 0 O0 N 0 0 E 0 0 1 5 15 29 51 80 61 E 114 26 S 30 2 E 58 S 41 49 E 56 S 38 18 E 62 S 16 5 E 14 S 8 27 E 34 S 5 43 E 27 S 4 0 E 88 S 3 20 E 73 S 3 18 E 1026.93 1006 O0 1136.41 1106 1248.46 1206 1363 73 1306 1482 98 1406 1608 02 1506 1739 92 1606 1880 O1 1706 2023 13 1806 2166 86 1906 900 O0 22 19 O0 1000 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 O0 1800 S 5 30 E O0 25 33 S 6 31E O0 28 5 S 8 30 E O0 31 34 S 11 59 E O0 34 46 S 12 58 E O0 38 53 S 14 8 E O0 42 32 S 15 47 E O0 45 29 S 15 36 E O0 45 44 S 15 11 E O0 46 1 S 14 25 E 150 16 194 21 244 34 301 48 366 38 441 39 527 35 625 40 727 78 831 O1 3 53 2 76 2 68 2 43 3 63 2 67 3 06 0 69 0 34 0 78 152 54 S 196 246 303 366 439 522 616 715 815 81S 14.53 E 197 90 S 21.04 E 247 28 S 31.24 E 304 68 S 45.29 E 369 56 S 63.03 E 444 64 S 85.13 E 529 99 S 111.95 E 627 75 S 138.95 E 729 52 S 165.47 E 832 9.82 E 152 86 S 3 41 E 35 S 4 13 E 8O S 4 52 E 89 S 5 53 E 47 S 7 2 E 06 S 8 10 E 52 S 9 15 E 06 S 10 17 E 11 S 10 59 E 14 S 11 28 E 2310 92 2006 O0 1900 O0 46 4 2457 2603 2749 2895 3040 3185 3329 3473 3617 04 2106 45 2206 52 2306 61 2406 75 2506 54 2606 72 2706 87. 2806 63 2906 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 OO 280O O0 47 6 O0 46 47 O0 46 45 O0 46 45 O0 46 20 O0 46 13 O0 46 3 O0 45 59 O0 45 46 S 13 57 E S 15 57 E 1041 S 15 30 E 1148 S 15 18 E 1254 S 14 48 E 1361 S 14 34 E 1466 S 17 33 E 1570 S 16 56 E 1674 S 16 51E 1778 S 16 53 E 1881 934 71 23 14 60 09 28 93 68 41 60 0 94 0 36 0 20 0 23 0 52 0 3O 0 27 0 O1 0 51 0 51 916 16 S 190 49 E 935 76 S 11 45 E 1018 1121 1224 1327 1429 1529 1628 1728 1827 92 S 218 86 S 247 51S 275 35 S 303 12 S 330 71S 359 96 S 389 31S 419 17 S 449 56 E 1042 56 E 1148 82 E 1255 48 E 1361 12 E 1466 10 E 1571 76 E 1674 91E 1778 77 E 1881 10 S 12 6 E 85 S 12 27 E 19 S 12 42 E 60 S 12 53 E 75 S 13 0 E 30 S 13 13 E 94 S 13 27 E 58 S 13 39 E 72 S 13 50 E 3761.28 3006.00 2900.00 46 9 3905 35 3106.00 3000.00 45 46 4048 4189 4329 4467 4607 4749 4891 5033 05 3206.00 3100.00 45 12 43 3306 O0 3200.00 44 40 02 3406 O0 3300.00 43 59 49 3506 O0 3400.00 43 48 92 3606 O0 3500.00 44 52 45 3706 O0 3600.00 45 8 47 3806 O0 3700.00 45 23 80 3906 O0 3800.00 45 32 S 16 56 E 1984 63 S 17 3 E 2088 S 17 6 E 2189 S 16 46 E 2289 S 14 20 E 2387 S 14 12 E 2482 S 13 18 E 2581 S 13 31E 2681 S 13 40 E 2782 S 14 44 E 2883 25 94 77 15 93 51 65 48 75 0.10 0,44 0.30 1 97 0 5O 1 38 0 42 0 21 0 39 2 36 1925.86 S 479.69 E 1984.70 S 13 59 E 2025 07 S 509.91 E 2088 28 S 14 8 E 2122 38 S 539.80 E 2189 95 S 14 16 E 2217 89 S 569.23 E 2289 77 S 14 24 E 2311 93 S 594.51 E 2387 1S S 14 25 E 2404 77 S 618.11 E 2482 94 S 14 25 E 2500 62 S 541.14 E 2581 51 S 14 23 E 2598 05 S 664.38 E 2681 65 S 14 21 E 2696 08 S 688.03 E 2782.48 S 14 19 E 2794.43 S 712.23 E 2883.76 S 14 18 E COMPUTATION DATE: 27-JUL-93 PAGE 6 arco ALASKA, INC. 1Y-24 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 16-JUL-93 KELLY BUSHING ELEVATION: 106.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET Of SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN 5177 15 4006 O0 3900 O0 45 52 5320 5464 5608 5752 5895 6038 6180 6319 6458 98 4106 99 4206 91 4306 61 4406 86 4506 88 4606 44 4706 50 4806 04 4906 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 O0 46 O0 46 0 O0 45 56 O0 45 48 O0 45 44 O0 45 29 O0 44 8 O0 43 57 O0 43 37 6595 56 5006 O0 4900 O0 43 8 6731 6866 7002 7136 7271 7404 7533 7663 7785 59 5106 50 5206 01 5306 89 5406 33 5506 62 5606 19 5706 89 5806 16 5906 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 42 19 O0 42 12 O0 42 23 O0 42 0 O0 42 23 O0 39 4O O0 39 17 O0 38 53 O0 31 3 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEG MIN FEET S 16 13 E 2986 41 S 16 17 E 3089 S 16 22 E 3193 S 16 37 E 3296 S 16 45 E 3399 S 16 53 E 35O2 S 17 15 E 3604 S 16 45 E 3704 S 17 1E 3801 S 17 13 E 3896 75 33 76 88 37 51 58 14 91 S 16 19 E 3991 26 S 16 36 E 4083 S 17 0 E 4173 S 15 57 E 4265 S 16 33 E 4355 S 16 26 E 4445 S 14 57 E 4533 S 14 57 E 4614 S 15 22 E 4698 S 18 56 E 4766 41 87 28 75 54 61 41 55 81 DEG/IOO o 15 o 16 o 14 0 24 o 09 0 15 o.41 0.58 0.34 0.98 0 74 0 45 1 38 0 51 0 19 2 38 1 61 3 49 4 37 0 95 FEET FEET FEET DEG MIN 2893 20 S 740 35 E 2986 42 S 14 21 E 2992 3091 3191 3290 3388 3485 3581 3674 3765 47 S 769 95 S 798 18 S 827 04 S 857 22 S 886 99 S 916 70 S 946 20 S 974 80 S 1002 21E 3089 26 E 3193 63 E 3296 26 E 3399 95 E 3502 89 E 3604 50 E 3704 49 E 3801 83 E 3897 75 S 14 25 E 33 S 14 29 E 76 S 14 32 E 89 S 14 36 E 39 S 14 40 E 55 S 14 44 E 65 S 14 48 E 23 S 14 51E 03 S 14 55 E 3856 37 S 1029 45 E 3991 41 S 14 57 E 3944 4031 4119 4206 4292 4377 4455 4536 4601 79 S 1055 38 S 1082 26 S 1107 15 S 1132 18 S 1158 04 S 1182 26 S 1202 65 S 1223 90 S 1244 61E 4083 10 E 4174 39 E 4265 76 E 4356 73 E 4445 34 E 4533 63 E 4614 92 E 4698 26 E 4767 58 S 14 59 E 08 S 15 2 E 51 S 15 3 E O1 S 15 4 E 83 S 15 6 E 91 S 15 7 E 72 S 15 6 E 85 S 15 6 E 14 S 15 8 E 7901 63 6006 O0 5900 O0 30 34 8017 31 6106 O0 6000 O0 29 48 8132 04 6206 O0 6100 O0 28 48 8245 70 6306 O0 6200 O0 28 11 8359 15 6406 O0 6300 O0 28 11 8375 O0 6419 97 6313 97 28 11 S 19 50 E 4826 28 S 18 10 E 4884 25 S 17 16 e 4940 40 S 15 33 E 4994 37 S 15 33 E 5047 94 S 15 33 E 5055 43 O. 80 I .16 I .47 O. O0 O. O0 O. O0 4658 15 S 1264 33 E 4826 68 S 15 11 e 4713 15 S 1283 15 E 4884 70 S 15 14 E 4766 72 S 1300 32 E 4940 89 S 15 16 E 4818 60 S 1315 23 E 4994 87 S 15 16 E 4870 23 S 1329 58 E 5048 46 S 15 16 E 4877 44 S 1331 59 E 5055 94 S 15 16 E COMPUTATION DATE: 27-JUL-93 PAGE 7 ARCO ALASKA, INC. 1Y-24 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING SHOE 7" CASING SHOE TOP KUPARUK C GCT LAST READING PBTD 5" LINER BOTTOM TD DATE OF SURVEY: 16-JUL-93 KELLY BUSHING ELEVATION: 106.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 570' FNL A 1762' FWL, SECl TllN r9E MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4599 O0 7566 O0 7765 O0 8199 99 8282 O0 8372 O0 8375 O0 3599 68 5731 22 5888 75 6265 72 6338 O0 6417 33 6419 97 3493 68 5625 22 5782 75 6159 72 6232 OO 6311 33 6313 97 2494.50 S 4475.53 S 4592.03 S 4797.80 S 4835.12 S 4876.08 S 4877.44 S 639 70 E 1208 05 E 1240 91E 1309 46 E 1319 82 E 1331 21E 1331 59 E ARCO ALASKA, INC. 1Y-24 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING SHOE 7" CASING SHOE TOP KUPARUK C PBTD $" LINER BOTTOM TD COMPUTATION DATE: 27-JUL-93 PAGE 8 DATE OF SURVEY: 16-JUL-93 KELLY BUSHING ELEVATION: 106.00 FT ENGINEER: JEFF FORMICA ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 570~ FNL ~ 1762' FWL, SEC1 TllN R9E MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4599 O0 7566 O0 7765 O0 8282 O0 8372 O0 8375 O0 3599 68 5731 22 5888 75 6338 O0 6417 33 6419 97 3493 68 5625 22 5782 75 6232 O0 6311 33 6313 97 2494 50 S 4475 53 S 4592 03 S 4835 12 S 4876 O8 S 4877 44 S 639 70 E 1208 05 E 1240 91E 1319 82 E 1331 21E 1331 59 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 8375.00 6419.97 6313.97 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 5055.94 S 15 16 E DIRECTIONAL SURVEY COMPANY ARCO ALASKA, INC. FIELD KUPARUK RIVER WELL 1Y-24 COUNTRY USA RUN ONE DATE LOGGED 16 - JUL - 93 DEPTH UNIT FEET REFERENCE 9331 4 All irfferpretatlons are opinions based on Inference,, from electrical or other me&surement~ and we canr~ot, and do not guarantee the accuracy or correctness of any interpretations, and we shall not. except in the case of gross or wilfull negligence on our part. be liable or responsible for any loss. costs, damages or expenses incurred or sustained by anyone resulting from any interpretation made by any of our officem, agents or employees. These Interpretations are also subject to our (Deneral Terms and Conditions as set out In our current price Schedule. .. HELL: 1Y-24" (570' FNL, 1762' FILL, SEC 1, T11N, ROE, tM) HORIZONTAL PROJECTION NORTH 2000 FIEF 93314, 1000 -1000 -2000 -3000 -4000 -5000 sou'n4 -6000 -3000 -2000 -1000 0 SCALE = I / 1000 IN/FT :::': '::~'FI"'F";'"~ ...... ~ ..... :"~'::'i:~:';':::~: '~::r :!:..!.; ..... : ............. i. · i.! ~ : i..i...!..-!- ;..i.-.i...i-., ..... !..: i...! ..... !..!..!...i .i..~.i..i ...... i.i..!...i ...i.~.i...~ ...... i...i...i...i ...i.i.i...:..~ . : :.,.: ~ .i.. ~ ...... : . . ~ ': 'i;::;; , i:; ' '' ~ ' ' '::' '' : ::.; .::: ::: :::: .::: :::: : ~. : :::..::.::_::...: ::.:. .::.. :-.: :.::,.::: :: · :::: : .... :: .-i~!i !..i-.!.i ...i.-¢.i.i --;i-i-.-i ..-i..!.--i~--i-!-i-.!. ;i;i...!.!..!.i ..... i.-i.i-i: !..i!..i...i:ix. : ~; ~ .......... ~ ~... ................................... ::. i i ; i i i ! ; i '; ! i'~ ! : : ! ; ~ : ; ; !'; ! ! ; ;'~'~ i :': ~' ! ! ! ;' : i i i : ' : ! : : : ! : ' ' ' ........ i i~: i'!ii ..... !...!.i..! -!-! ~-i. -~-;.!i 'ili i:~'tlO00'i'!"i"i''i!"il i; i"i' i~:: ':i';i ! :;: ....... "'-- i :,! ! ! ! ! ! i~ !i ::!: :!i ; !,!~i ! i !! ! ~: i! ~ ~ :: :! . : -:' ~ ......... =: .... : ' i-: -: i ---! .... ;-.:-i--, i ..... ; i.-! i--i--: ! !-.; ?\' ' i-! i i-..!-, i . * ; i * ; .i ;.i : : : : · i ....... ' .... : ! : ; ; i i ; -! : · i i , : i -i i i ~ ! i ! i ~ ~ ; ~ ~'i ! i i i ~ ; ! . i i ~ , · ; , ~ ! · ! i : I : ! · ; , i , }..i.; i.- .; i ;.: ; ~..} ~ i i i.! .-i : ;.} i i i i ; i ; .¢ : : ~ ; i ; ; : ! : :.: :.i ; , ; ~ : : : . : . . : . . : ; : . :. ~.~ .~.:..~..~ ..... i. :.: ........... :.; ~ ;. ; : ; :. ; i.; : . i ~ : ~ .; ! : . : i : ~ .:. ; : : : ; ; .... : : ....... ~ : ~ ~ ;:! i'! !~ i !~":":i: ;il; ; ::~ i !; ~;' ~:713 5: ' :i ': : : :.:: .... ::: ...... : ~ ...................... :: ;,.~; .... ~.~ .ii~i ;:,, i!ii i;,: .,:; ~; .... : ..... -! ; : ! !-i i ; ..... i--!-~ ;--: ! ;--!- ! i-i ;. i ; ! ;--;-: ; :- ! ; ; i- - ; : - : : : - : : : : . ......... --! ..... !.-: ;---;---;--.i ...... L-;--;.-: ..... i.i ..... ; :..-;---;.-; ...... !..i...i..; ;...i-!!-- . :-~ : ...... ;~ ....... ; ....... : : ..... : ................. · ::': ..:: : . ~ i.:. .i;:i. ;:~!: ........... i:i! ,:~ ,.,~ , !;~ i! ,:;! ,:;, : ~ !'~ < !"i'"i ..... i'"!"~ i L! ! .... ! ! i"i''i'i'! ~ i'; i i' ; r* i ';':'i : ":': i ....... ; · ! · : ' ! ...... .... .:.;: .:..;...: ..... i...J .... i...;.:.J i...:.i.J ::...;...;. :.;i.; '':'': .... : ...... ::: ..... : .... :' ':': ..... · . ; ............. ; .................. :;i..:!. , ,; ,.,; '~;; ....... ; ! 1000 2000 3000 4000 5000 WEST EAST WELL: iY-24 ~ (570" FNL, 1762' FWL, SEC 1, T11N, RgE, UM) VERTICAL PROJECTION -1000 0 0 1000 2000 3000 4000 5000 6000 7000 . . . i : , ! ! . i ~ ~ i ! ! ~ ~ : i'-_: ~ ! ~ i i . ! : : : : : ~ : ~ . ~ : ! i i i i i, ,. ; ~ : ; : : i i i i i--i--i i.i.- ~.i i i : i.~.. ~ ~ : ~.. ~ ~ : : : i.: ~-: : : i ~ : : ~ .! ~ : : .: : : : · ~ ..... ' : i ! : i-.i i--i ...... i--i--:--! .... i ! i-~.--'-!--;.-i--i. -!-:':i:-~--i i.i...i-i,..~ i ~.i ..... !.i-.i : -i--~ : i-- ! !..i,:.i.i ~ ;.~ ; , · : .... · . : !::: :. : :!~ : i..~: i:.. !-! · :, :;!i[..i..!-.f.-; ..;-:;.i-.i.i.;i. i.i-.~i .;.;.;-:, ;::i .i;~.: .... · ;.i ;.i ....... :,:: .... : .... :~! i:i :.i.i--i...i.i.i-.;.~.;..i.-.!;il.. ::.:i ~i:: .... ~.:~..! ii.:i !:i: !i:.~ .i:.: i . :.: .......... }}:: ~i'!"'/'"~b :.-i-}-i .... i.i.il ,.} !--! !- ~--}- !- !--.i .i--i--!~ S~,~Oi..i-:}i ..VERii~E SECT]ON i : ~.i i.i i i _i..i !...i...i~i i i.. !..i.i.i ~ Li ! ~ .i ~.i i. : ~ ...:. ~::,q :.: ..i . ..i ..... i i i. : i ! ..... : : . i i : i ~' :-::::::::: :"::::::::-: ::: "::::: :i ..... i:: :: : .... : "~:::~.':~ :' :':":'::' .::"'::i:' 'i : -~; i~-:!..i---ii-.i i-~--, ....... i-..i 'i~ !. ,-!!--}-.!i !;~i:!i'~ ,'.!.~,.~: ii'il i i~:::::!:: : .: : :i::!': ' :! · ~!! '- i: ':i :i~"!~..;~o°01: ' : : : I--~": i'!": ! ~ ! : ! ; i ~ ~ -: , ! i ~ ! i : i ~ ! ~ I !-! ~, ! : ! ' : : : ; ':' : '" : : ': ~ ; ~ :' -~-i i .... ~ i ! , I~ 837! : ...... ii!: i i i i' i i .: :.-:,::.: · ::: .... i +. ;- ::: : :. .': · , . i:i.:. i: !-: :i.. :. i:!. .' -:i!. ..... !:... i.. '.. : 5-7:,! -~i~! :::. '~! :' ; :~ ,.; ~.:! il, : ..... ~2_ ..................... : .:. ::.. : :~ ~ :. ::. · -- :-.:i i---F~-~ !-:-:--: .... :-:!: i::-.~i-i:-: :.:i:.:~2.}:. :. i. -i.:.: -.~ ...... · , : ..... : ..... :..:...: ::.:: :.:.. ::.: :.:: . .. :.:.. :: . : . :~: ui.~i.L..i..L..:..l..i.Li..;..i..i..:;, ii..i: : : i : i.i..i..Li ! .i i! i : i.i i .! i : ~ ! i~.! ....... ...... ,::-. :.:; :::: .::. ,.:' :: . :::.1.::: ::: :-.; ; .... L.i ..... i-..;...¢..-i-. :~..: : :. ...... i ~.i-.i. i.-.; : : .i i : ~ ........ : ,.. i ~.: ..... : ............ ! :J !:i!-:~:.! : :':. !i. .:. : .. _ ................................................................... · ~ i · i i i.-i ...... i i--.!--i ..... i i.i i .... i..i ;.i ~ : i ;...i..i i .... i : : i .:..~ i..i .... ,.r . : : .......... ' : ' ! !'; ! i"!'"i'"i'"!'"! .... ~ i": ! '!"i"~'! '! i':'~ 'i i':'~": i : ! .... i : .......... ! : ~ '' ! ......... . . :! iJi~ : .. .::: : :: .: .. 5': .... "~'"':~'{'!'~':'! ...... :"':"~' ~" .... :'~ ...... i"~'!i~":'!! "'~' '~ ........ ~: ..... : .......... 166 00 PROJECTION ON VERTICAL PLANE 346.00 166.00 SCALED IN VERTICAL DEPTHS HORIZ SCALE = I / 1000 IN/FT ARCO Alaska, Inc. Date: October 22, 1993 Transmittal Cf: 8903 'RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 · P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. receipt and return one signed copy of this transmittal. '1Y-27 ¢J'5 -'7~¢ / 1Y.27 .~1. Y-27 f Y-18 ~[~ ~[0~ Y-18 Y-18 I Y-31 ~ .cio Y-31 Y-31 I Y,28 ¢j~ .~o~ '11Y'28 L1Y-28 IiY'21 0[-5 --to'L Y-21 Y-21 Y-19 ' Y-19 ~l'~ "t °'~' Y-19 Cl ~-'2~ --1Y-24 Il Y-34 c~-5.-cl \ Y-34 ¢'CDR Enhancement 5' 8-23-93 LWD/Depth Corrected ¥'CDN LWD/Depth Corrected~--~'~'8-23-93 ,/CDR LWD/Depth Corrected a-~"8-23-93 ¢-CDN LWD/Depth Corrected z,¢5"9-08-93 ~CDR Enhancement ~ 9-08-93 LWD/Depth Corrected ¢'CDR LWD/Depth Corrected ,/'CDR LWD/Depth Corrected ,/'CDR Enhancement LWD/Depth Corrected v"HLDT Corrected Casedhole Density ¢'CDR Enhancement .3' 9-08-93 LWD/Depth Corrected ¢'CDR LWD/Depth Corrected a-t~ 9-08-93 ~::::;DN LWD/Depth Corrected ~-~ 9-08-93 ,,'CDR Enhancement , 5 9-08-93 LWD/Depth Corrected ~'CDR LWD/Depth Corrected-~-~ 9-08-93 ¢'CDN LWD/Depth Corrected 4_,~s 9-08-93 ,,/CDN LWD/Depth Corrected .?..t-5 9-09-93 ~CDR LWD/Depth Corrected ~z-r5 9-09-93 ,/'CDR Enhancement ~ 9-09-93 LWD/Depth Corrected ¢q'DTP Depth Corrected ,,/CDN LWD/Depth Corrected · .~CDR LWD/Depth Corrected 9-08-93 8-26-28-93 8-26-28-93 10-08-93 8-24-93 7-2-5-93 7-2-5-93 Please acknowledge 8858-10012 8850-10018 8870-9990 8280-9180 8500-9150 8290-9160 6910-7830 7100-7700 7000-7700 7650-8250 7280-8250 7260-8250 6900-7450 6670-7640 6650-7590 6900-7610 6900-7660 7050-7500 7450-8220 6250-8640 6250-8640 c~¥ ~ q,\ 1 Y-34 ,c/CDR Enhanced LWD/Depth' Corrected 5' 7-2-5-93 7200-8600 Receipt Acknowledged' DISTRIBUTION' D&M Drilling NSK State of Alaska (+Sepia) ..1 Bob Ocanas ARCO Alaska, Inc. Date: August 13, 1993 Transmittal #: 8836 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. receipt and return one signed copy of this transmittal. 1Y-24~/5-??"' HLDT/CNTG 8-06-93 ct'5-~ 1H-21 CDR Enhancement 5-25-93 LWD/Depth Corrected Cna LWD/Depth m~,.,~o,,+o,4 ~ ~"'3 CDR LWD/Depth Corrected 5-25-93 CDN LWD/Depth Corrected 5-25-93 CDR LWD/Depth Corrected 1-19-92 CDR LWD/Depth Corrected 5-27-93 CDR LWD/Depth Corrected 7-14-93 CDN LWD/Depth Corrected 7-14-93 Please acknowledge 7543-8232 4674-8317 ~: 42995 4665-8319 4665-8319 3180-10345 3669-13O18 35O8-6O36 3508-6036 Receipt Acknowledged' DISTRIBUTION: D&M NSK Date' R[CEIVED Drilling Catherine Worley(Geology) AUG ~ 7 1993 Alaska Oi~ & Gas Cons. Commission Anchorage -'State. of Alaska, (+Sepia) ARCO Alaska, Inc. Date: August 13, 1993 Transmittal #: 8831 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. and return one signed copy of this transmittal. 1H-14 c;E~ ad LIS Tape and Listing' 5-24-93 CDR in 4 Bit Runs, QRO Processed Resistivity 1Y-24 o~- ~'b LIS Tape and Listing' 8-05-93 ~d 3 passes CNTG/HLDT Please acknowledge receipt 93185 93318 Receipt Acknowledged: DISTRIBUTION: Bob Ocanas .-State of Alaska Date: ARCO Alaska, Inc. Date: August 6, 1993 Transmittal #' 8824 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Records Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1Y-24 Sub-Surface Directional 7-16-93 93314 Survey Receipt Acknowledged' DISTRIBUTION' D&M State of Alaska (2 copies) '%. ARCO Alaska, Inc. Date: July 30, 1993 Transmittal #: 8816 RETURN TO: ARCO Alaska, Inc. ATTN: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and 'return one signed copy of this transmittal. 1 Y-24 ~: 3,.'"7'"'Z..~ Cement Bond Log CBT 1Y-24 Cement Evaluation Log CET 1Y-34 I Cement Evaluation Log ~ 3 ~' CET 7" Casing Section 1Y-34 Cement Bond Log CET 7" Casing Section Receipt 'Drilling 7-16-93 7-16-93 7-15-93 7-15-93 Date: State of ~]~ska(+se~_ Please acknowledge 615O-823O 615O-8254 7300-8313 7300-8290 NSK ARCO Alaska, Inc. Date: July 23, 1993 Transmittal #: 8812 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. r),-~29 ~"{ 'J'TLIs Tape and Listing: 10-18-92 92622 ~ ~ ,~'~.~ ~..,,,~."V7Bit Runs of CDR. Corrected HLDT _ -07 '~'[" LIS Tape and Listing: .9-18-93 92563 .,/,At-' ..~,,//\ 3 Bit Runs of CDR. Corrected HLDT ~'~1'1~J-21 S'f .. LIS Tape and Listing: 3-27-93 93132 U~.~' _/,,~ .3-t~ CDR/ODN & QRO Enhanced Resistivity '~¢'.~¢1-32 'b~ ,. LIS Tape and Listing: 11-17-92 ' 92686 ~""~\"\CDR Runs 1 & 2, Averaged Cased Hole HLDT r'"'t ;)_.)'PY-~ LIS Tape and Listing: 6-26-93 93292 ~ ~4\~ DTE/SDN & CNTH ~rC/~ ~ I' LIS Tape and Listing: '6-9-93 93263 ~0 J..,, ~ CDR/CDN & GR CBT in LDWG Format ~.".1W-:-22 %-I' LIS Tape and Listing: 5-29-93 93244 ~(~,¢__-- ,[..,,~ \~CDR/ODN in 1 Bit Run, GR from CBT ¢[),./t.~-17 ~ ~. /LIS::Tape and Listing: 5-23-93 93241 ~ ~,,\ i .,,, 4., CDR Runs 1 & 2, CDN Run 2, QRO Processed ~"~".~<12 4::J' ~' "LiS Tape and Listing: 5-18-93 93239 ~..~--.-/ 'l CNTG/HLDT & Arithmetic Average .... Receipt Ackn~_~ ./ 'l?_-/'-///'~,~.---"/Date: · ' Ancho"rage , DISTRIBUTION: Bob Ocanas State of Alaska ARCO Alaska, Inc. Date: July 09, 1993 Transmittal #: 8794 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage. AK 99510-0360 Transmitted below are the following open hole items. receipt and return one signed copy of this transmittal. 1Y-24 0~,.b,q,).' 1Y-24 1Y-24 ~1Y-24 HLDT-Corrected Casedhole Density ,, Cyberlook ,-Litho Density-Neutron 2" & 5" Raw Data i Lltho Densit~Neutron 2" & 5" Porosity Dual induction-SFL-GR .,,,,- ' (5: & 2: Phasor Processed) 4-26-93 6-26-93 6-26-93 6-26-93 6-26-93 Please acknowledge 7500-10300 7670-8306 7561-8332 7561-8332 7561-8358 Receipt Acknowledged: DISTRIBUTION' D&M Date: RECEIVED "" 1~ 199;~ dUL. Alaska Oil & Gas Cons. Commission ,~nchorage Drilling VendorPackage(Johnston) NSK State of Alaska(+Sepia) Catherine Worley(Geology) ARCO Alaska, Inc. Date: June 25, 1993 Transmittal #: 8776 RETURN TO: ARCO Alaska, Inc. A'FI'N: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. ~5''7~' 1Y-24 /Ultrasonic Imager/ Cement and Corrosion ~11Y'2~, O.cement B°nd L°g (CBT) 1Y-2 o~¢.j.7 Cement Bond Log (CBT) Y-2 Cement Evaluation Log (CET) Y-23 Cement Evaluation Log (CET) 6-16-93 6-17-93 6-17-93 6-17-93 6-17-93 Receipt Acknowledge: Date: Please acknowledge 200-4575 735O-7386 5650-6583 5650-6508 5650-738O Drilling State of Alaska(+sepia) NSK ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 May 17, 1993 A W McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1Y-24 ARCO Alaska, Inc. Permit No. 93-72 Surf Loc Btmhole Loc 570'FNL, 1762'FWL, Sec 1, TllN, R9E, UM 337'FNL, 2217'FEL, Sec 12, TllN, R9E, UM Dear Mr McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W J~hnsto Chairman BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section, w/o encl Dept of Environmental Conservation w/o encl .... STATE OF ALASKA ALAS. . OIL AND GAS CONSERVATION COMMISSI. PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill ~] lb Type of Well Exploratory r~ Stratigraphic Test r~ Development Oil X Re-Entry C] Deepen D Service D Development Gas ~ Single Zone X Multiple Zone [-] 2.. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska~ Inc. RKB 106'~ Pad 65' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360r Anchora~e~ AK 99510-0360 ADL 256461 ALK 2577 4. Location of well at surface 7, Unit or property Name 11. Type Bond (see 2o AAC 25.025) 570' FNL, 1762' FWL, Sec. 1, T11N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 30' FSL, 2312' FEL, Sec. 1, T11N, R9E, UM 1Y-24 #U-630610 At total depth 9. Approximate spud date Amount 337' FNL, 2217' FEL, Sec. 12, T11N, R9E, UM 6/1/93 $200,000 12. Distance to nearest 13, Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1Y-8 8401' MD 2217 ~ TD feet 28.7' ~ 200' MD feet 2560 6328' TVD feet 16, To be completed for deviated wells 17. Anticipated pressure (see 2O AAC 25.035(e)(2)) Kickoff depth 300 feet Maximum hole angle 45.49° Maximum~rface 2129 psig At total depth (TVD) 3444 psig 18, Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD linclude stage dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +_200 CF 12.25" 9.625" 36.0# J-55 BTC 4534' 41' 41' 4575' 3596' 520 Sx Permafrost E & HF-ERW 480 Sx Class G 8.5" 7" 26.0# L-80 BTCMOI' 8360' 41' 41' 8401' 6328' 190SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor :/-: " Surface~..,,~" ~ ~'~ Intermediate Production Liner Perforation depth: measured, true vertical 20. Attachments Filing fee X Property plat BI BOPSket~h X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot ~-1 Refraction analysis [~ Seabed report r-! 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~/~ ~ Title Area Drilling Engineer Date ,.~,--- ~' Commission Use Only Permit Number i APInumber ?,~'"7.2-. 50- 02-~-" ~- <~--- ,~ 7/ '/ ~ other requirements Conditions of approval Sample.~ required BI Yes ~ No Mud Icg required BI Yes [~ No Hydrogen sulfidemeasures ~--1 Yes ~1 No Oirectional survey required B Yes O No Required working pressure for BOPE 0 2M ~ 3M r"J 5M [] 1OM O 15M Other: .-.. ; .... Commissioner the commission Date '~ "~ C~, ,l.~mit in Form 10-401 Rev. 7-24-89 I I V ARCO ALASKA, Structure : Pod 1Y Well : 24 Field : Kuporuk River Unit Locofion : North Slope, Alosko iCreoted by : jones For: D STOLTZ }Dote plotted · 1-Moy-93 iPIot Reference is 24 Version #1. iCoordinotes (]re in feet reference slot #24. iTrue Verticol Depths ore reference wellheod.i i BAKER ~ HUGHES I INTEQ SURFACE LOCATION: 570' FNL, 1762' FWL SEC. 1, T11N, R9E .......... East 2500 250 500 750 ~ I I I [ I I I I 0 RKB ELEVATION: 106' 300 600 900 1200~ 1500_ 1800_ _ 2100_ _ 2400_ _ 2700_ _ ~- MAXIMUM ANGLE 45.49 DEG - 550~_ _ 5600_ _ _ 4200_ _ 4500_ _ 4800_ _ _ 54O0_ _ 5700_ _ - TARGET ANGLE 6300_ 40 DEC 660O i i i i i i i i i / $cele 1 : ~50.00 KOP TVD=300 TMD=300 DEP=O S 14.45 DEG E 3.00 4833' (TO TARGET) 9.00 15.00 BUILD 5 DEG / lOO' 21.00 27.00 55.00 B/ PERMAFROST 'rVD=1406 TMD=1480 DEP=555 39.00 45.00EOC TVD=1662 TMD=1816 DEP=571 MAY 1 0 ;,~95 Alaska Oil & Gas Cons, 6orm'nissio gncn0, age T/ UGNU SNDS 'P¢D=2606 TMD=5163 DEP=1531 T/ W SAK SNDS 1¥D=2956 TMD=3662 DEP=1887 B/ W SAK SNDS TVD=5596 TMD=4290 DEP=2535 9 5/8" CSG PT -P¢D=3596 TMD=4575 DEP=2538 K-5 TVD=4966 TMD=6530 DEP=3932 K-lO 'P¢D=3816 TMD=4889 DEP=2762 TARGET LOCATION: 30' FSL, 2312' FEL SEC. 1, TllN, R9E TARGET TVD=5876 TMD=7810 DEP=4833 SOUTH 4680 EAST 1206 BEGIN ANGLE DROP TVD=5607 TMD=7444 DEP=4585 DROP 1.5 DEG / 100' 43.50 TARGET -T/ KUP SNDS (EOD) TYD=5876 TMD=7§I0 DEP=4833, 40.50 T/ ZONE A 7VD=6059 TMD=8049 DEP=498L ~ B/ KUP SNDS TVD=6175 TMD=8201 DEP=5084 TI) - 7" CS6 PT TVD=6328 TMI)=8401 DEP=5212 --> lOOO 125o I I I I 1500 1804)2100 2406,2700 3300 3600 5900 4200 45 0 5100 5400 VerHcol Section on 165.55 ozimufh with reference 0.00 N, 0.00 E from slot #24 15oo 750 lOOO 125o 15oo _ _175o _ _2000 - O _2250 _ _2500 ~-- _ _2750 I _ _3000V _ _5250 _351:>0 _ _~750 _ _400O _ _4250 450O 4750 _ _5250 TD LOCATION: 337' FNL, 2217' FEL SEC. 12, T11N, RgE Scale1:50.00 EaSt --> 400 500 200 100 0 100 200 ~00 400 500 600 700 800 900 1000 1100 1200 1500 1400 15~10 4100 '.100 3300 500 ~3500 ~500 :1700 A900 ~700 3700 3900 ~4300 47OO 4900 5100 400 300 200 100 0 100 20~ 500 1700 ~700 1900 2100 4100 4300 27OO 2900 3100 400 500600 East Scale 1 : 50.00 -J -- L 200 ARCO ALASKA, In¢.tloo ~ " ~_o ~ Structure : Pod 1Y Well : 24 -~?,~00 Field : Kuparuk River Unit Location : North Slope, Alaska '~4100 4500 4700 ,2700 ~900 550O tg lOO _ _ 200 2,00 - _ 400 _ _ 500 700 1aa0 17OO 2OOO 700 800 900 1000 1100 1200 1300 1400 1500 1600 5700 ~ k~ 0:1 & G~' cons Armhora~e I , , . . . . . o . 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1Y-24 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point {4575')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth {8401') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the . Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. DRILLING FLUID PROGRAM Well 1Y-24 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.5 15-25 15-35 50-100' 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes' Weight up to TD 11.6 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2129 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1Y-24 is 1Y-8. As designed, the minimum distance between the two wells would be 28.7' @ 200' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 80-100 sec/qt to drill gravel beds. Casing Design / Cement Calculations 7-May-93 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg A MD: Production Csg A TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Mud Weight: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 1 Y-24 4,575 ft 3,596 ft 8,401 ft 6,328 ft 3,662 ft 7,810 ft 5,876 ft 11.6 ppg S e Page For Casing Choices 3,500 psi Maximum anticipated surface pressure Estimated BH pressure at top of target zone TVD surface shoe {(13.5'0.052)-0.11}*mVDshoe Anticipated Mud Weight = Top of Target Zone, TVD = 100 psi Overbalance = =t 3,596 ft 2,129 psiI 11.6 ppg 5,876 ft 3,544 psi 3444 psiI Surface lead: Surface tail: Top West Sak, TMD = 3,662 ft Design lead bottom 500 ft above the Top of West Sak = 3,162 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 990 cf Excess factor = 15% Cement volume required = 1,139 cf Yield for Permafrost Cmt = 2.17 Cement volume required =i 520 sxJ TMD shoe = 4,575 ft (surface TD - 500' above West Sak) * (Annulus area) = 443 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4340 cf/If Cmt required in casing = 35 cf Total cmt = 477 cf Excess factor = 15% Cement volume required = 549 cf Yield for Class G cmt = 1.15 Cement volume required =1 480 sxI Casing Design / Cement Calculations 7-May-93 Production tail' TMD = 8,401 ft Top of Target, TMD = 7,810 ft Want TOC 500' above top of target = 7,310 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 190 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 208 cf Excess factor = 15% Cement volume required = 239 cf Yield for Class G cmt = 1.23 Cement volume required =[ 190 sxI TENSION - Minimum Design Factors are: T(.ob)=l.5 end T(js)=1.8 Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =! Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft)= · Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ Production (Pipe Body) Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air - Buoyancy = Tension (Pipe Body) = Design Factor =! Production (Joint Strength) Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 564000 lb 4,575 ft 36.00 Ib/ft 164700.0 lb 28268.4 lb 136431.6 lb 4.1J 639000 lb 4,575 ft 36.OO Ib/ft 164700.0 lb 28268.4 lb 136431.6 lb 4.7] 604000 lb 8,401 ft 26.00 Ib/ft 218426.0 lb 38214.1 lb 180211.9 lb 3.4J 667000 lb 8,401 ft 26.00 Ib/ft 218426.0 lb 38214.1 lb 180211.9 lb 3.7J Casing Design / Cement Calculations 6-May-93 OD ID Ib/ft Grade I 9.625 8.681 47 L-80 2 9.625 8.835 40 L-80 3 9.625 8.921 36 J-55 4 10,750 9.950 45.5 J-55 Surface Casing Choices Metal X-Section Jt Strength Body Strength Collapse Burst 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 6870 psi 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 5750 psi 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 3520 psi 13.0062 sq. in. 931000 lb 715000 lb 2090 psi 3580 psi OD ID I b/ft I 7.000 6.276 26 2 7.000 6.276 26 Production Casing Choices Grade Metal X-Section Jt Strength L-80 7.5491 sq. in. 667000 lb J-55 7.5491 sq. in. 490000 lb Body Strength Collapse Burst 604000 ~b 5410 ~si 7240 ¢Psi 41 5000 lb 4320 psi 4980 psi KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC 5 6 4 5 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENAN(;;E ~ OPERATION , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"-2000 PSI BALL VALVE 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20"- 2000 PSI ANNULAR PREVENTER EDF 3/10/92 7 5 4 I3 13 5/8" 5000 PSI BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSi AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOWAND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE, 8. OPEN TOP PIPE RAMS AND CLOSE BO'I-rOM PIPE RAMS. TEST BO'I-rOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSi. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16"- 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8"- 5000 PSI SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8"- 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR 1Y-24CIvlT~S State: Well: Field: State Permit ,4~-a 1Y-24 Kuparuk River 93-72 Engineer:. Work Sheet: Date: hr. C~rr~n! Volt.ne 5/1 I/'33 Casing Type Casing Size Casing Length Hole Diameter Cement- Sacks Cement- Yield Cement- Cubic tt Cement- Cubic ft Cement- Sacks Cement-Yield Cement-Cubic tt Cement- Cubic ft Cement-Sacks -Inche~ - Feet -h'r_,hes 111 111 111 111 ~2 112 112 112 113 Cement- Yield113 Cement-Cubic It 113 Cement- Cubic ft 113 Cement- Cubic ftt Vol Cement- Fill Factor Conductor 16.000 80.000 24.000 0.000 0.000 0.000 200.000 0.000 0.000 0.000 0.000 200.000 1.432 Surface 9.625 4,534.000 12.250 520.000 2.170 1,128.400 1,128.400 480.000 1.150 552.000 552.000 0.000 0.000 0.000 0.000 1 ,G80.400 1,183 Lin~ 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 I~DIV/0! Cas'rog T..ui:,e Ca~ Size -Inches Casing Depth - Feet Hole Diameter-Inc~hes Cement-Secks 111 Cement-Yield ;1:I1 Cement- Cubic tt 111 Cement- Cubic ft 111 Cement- S o%-"'ks 112 Cement-Yield 112 Cement- Cubic ft 112 Cement-Cubic ~t 112 Cement-S ~-'ks 113 Cement-Yield :1:I3 Cement- Cubic It 113 Cement- Cubic tt 113 Cement- Cubic It / Vol Cement-Interval It Top of Cement- Feet Interrrp~diate 111 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/0! I~DIV/0! Intermediate 1:12 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/0! #DIV/0! Printed 5/13/93 Production 7.000 8,401.000 8.500 190.00 1.23 233.70 233.70 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 233.70 1,842.96 6,558,0 Measured Deplh, ~/';/ ~ /-L. 1:. ,' :,: ,,/,?,:., ,,/ State: Alaska Borough: Well: IY-24 Field: Kuparuk River St. Perm # 93-72 1Y-24KRUXLS Date 5/11/93 Engr: M. Minder Casing Interval Interval Size Bottom Top Length lA 9.625 3596 41 4534 2A 7 6328 41 8360 3A 0 0 0 0 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Description Description Description Tension Lbs Grade Thread Lbs 36 J-55 BTC 0 26 L-80 iTC MOD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o lB 2B 3B 4B 5B 6B 7B 8B 9B 1 OB Mud Hydraulic Collapse Weight Gradient Gradient ppg psi/ft psi/ft 10.5 0.546 0.446 11.6 0.603 0.503 0.0 0.000 -0.100 0.0 0.000 -0,100 0.0 0.000 -0,10o 0.0 0.000 -0.100 0,0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi BDF 2129 3520 1.7 2129 7240 3.4 0 0 #DrY/o! 0 0 #DIM/O! o 0 #DIV/O! 0 0 #DIV/0! 0 0 #DIV.~! 0 0 #DIV~! 0 0 #DIVI0! 0 0 #DiV/0! Tension Strength K/Lbs 1C 163.224 2C 217.36 3C 0 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 K/Lbs TDF 564 3.46 604 2.78 0 #DIV/O! 0 #DlV/O! 0 #DIV/O! 0 #DIV/O! 0 #DiVEi! 0 #DIV/O.I 0 #DIV/O.I 0 #DN/O! Collapse Collapse Pr-Bot-Psi 1604 3184 0 0 0 0 0 0 0 0 Resist. CDF 2020 1.259 5410 1.699 0 #DIV/O! 0 #DN/O! 0 0 #DIV/O! 0 #DIV/0! 0 #DIV/O.I 0 #DIV./O! 0 #DIV/O! ** CHECK LIST FOR NEW WELL PERMITS ::* ITEM APPROVE DATE ( 1 ) Fee (2) Loc [2 thru 8] (3) Admin [~-.. [9 thru 13] (5) BOPE ~, ~,,~',~ [23 thru 28] (6) Other A~/~C ~/j,~_/..~_.,~ [29 thru '31] (7) Contact /~/)r_ .:-//~,//~e [32] (8) Addl ~-~,~/~.~/.~;~: ~-'- geology' engineering' DWJ ~ MTM~ RAD]) RPCz~__~_~ BEW - JDH~ LG rev 12/92 jo/6.011 Company ./~ <_ ~ , 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located 'proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ . 10. 11. 12. 13. 14. 15. 16. 17. 18. !.9. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. Lease & Well YES NO Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease ntmber appropriate .......................................... Does well have a unique name & nunber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to .~,-:~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone nunber of contact to supply weekly progress data ...... Add i t i ona 1 requ i rements ............................................. REMARKS /, / / / INITIAL GEOL UN'IT "ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' ux MER I D I AB, I' SM " TYPE' Exp~__~, Redr i l l ..... Inj Rev o .--I -mz ~--~0 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. May 11,2003 4992 1 5" 18 lb. L-80 Liner ¡ g) - ð 7L ( 1b?~(~F1: Memory Multi-Finger ciiipe~~ ¡.) Log Results Summ~~ 2 f /n~3 .. A1aska Oil Ô G3$ CD:)S. CommiSSion Well: 1y~horag8 Field: Kuparuk State: Alaska API No.: 50-029-22371-00 Top Log IntvI1.: 7,678 Ft. (MD) Bot. Log IntvI1.: 8,024 Ft. (MD) . V C3 --CCJ t-:/ ",'''' J t?)~ 1':j1~ I:..} , II' Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: . ""'~' \,I\'~'iF'¡ ;;:~~".t~,\I. ~"_: ~; -". ~t, ç" '[ [\ (\ ',::i This caliper data is tied into Tubing Tail @ 7,681' (Driller's Depth). This log was run to assess the condition of the liner with respect to corrosive and mechanical damages. The caliper recordings indicate that the interval of 5" liner logged is in good to poor condition with respect to corrosive penetrations. Wall penetrations of 59% and 55% are recorded in pup joint 6.2 and joint 7 respectively. The damage appears in the form of General Corrosion with Isolated Pitting. The caliper recordings indicate pipe buckling in the liner from 7,950' - 8,024', and the buckling appears to be severe from 8,012' - 8,024'. The Field Engineer reported that the caliper tool sat down @ 8,024' while running in the hole, and would go no deeper after several attempts. The caliper tool was damaged during logging operations, with the damage being consistent with excessive bending forces applied to the tool. As a result of this damage, five of the caliper fingers did not record properly during the log, resulting in a loss of -20% circumferential coverage over the logged interval. A minimum recorded 1.0. of 3.82" is recorded in the area of buckled liner @ 8,023'. There are some indications of permanent pipe deformation over the bottom 10' of liner logged. No other significant 1.0. restrictions are recorded throughout the liner logged. Cross-sectional drawings of the most significant events are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS: Corrosion Corrosion Isolated Pitting Line Corrosion Line Corrosion ( 59%) ( 55%) ( 41%) ( 26%) ( 23%) Jt. Jt. Jt. Jt. Jt. 6.2 7 0.1 1 6 @ @ @ @ @ 7,995 Ft. (MD) 8,015 Ft. (MD) 7,685 Ft. (MD) 7,714 Ft. (MD) 7,949 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 13%) are recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS: Deposits in Buckled Liner Minimum 1.0. = 3.82" Jt. 329.3 @ No other significant I.D. restrictions are recorded throughout the interval logged. 8,023 Ft. (MD) I Field Engineer: N. Kesseru Analyst: M. Lawrence Witness: M. Cheney ProActive Diaqnostic Services¡ Inc. / P.O. Box 1369¡ Stafford, TX 77497' Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS(q)memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-231<1 ~~~X'f\~ clds. Well: Field: Company: Country: 1 Y-24 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Weight 1 8 ppf Grade & Thread L-80 Nom.OD 5 ins Penetration and Metal Loss (% wall) _ penetration body 10 ~¡!I!î!iJ metal loss body o o to 1% 1 to 10% 1 0 to 20 to 40 to over 20% 40% 85(Yr) 85% Number of joints analysed (total = 10) pene. 0 2 2 3 3 0 loss 0 9 1 0 0 0 Damage Configuration ( body ) 10 0.... isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 8) 323 0 o 'l PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Rngers: Analyst: Nom.lD 4.408 ins Nom. Upset Sins _ penetration body o o Bottom of Survey = 7 Analysis Overview page 2 May 11, 2003 MFC 24 No. 99812 1.69 24 M. Lawrence Upper len. 1.2 ins Lower len. 1.2 ins Damage Profile (% wall) :'~l metal loss body 50 100 10 0.29 0.24 .- j 0.19 1.,1 ¿ .J: ã. 41 Q .. i£: 0.14 0.09 0.04 0.1 cIrls \i c. _;r Well: Field: Company: Country: Survey Date: Percent Probability of Hole 20 50 1 Y-24 Kuparuk ConocoPhillips Alaska Inc. USA May 11,2003 '00 , \. \. \. " " """"""'''\''''''''''"'' \. \. , \. , "- \.. 'I. \. '\ o '\ '\ '\ \, 0 ... , " " \, I '0 \~ , ... , , ...., 0....\ Ò>.. ',C- '\ ,~~~ PDS Caliper Statistical Evaluation Report Tool: Tool Size: Tubing 1.0.: Tubing 0.0.: Wall Thickness: ~O/:':/a~l-'i~ness ~a':ety J-:or un~ "" Average Rank 10 MFC 24 No. 99812 1.69 inches 4.408 inches 5 inches 0.296 inches Standard Deviation of 0.013 Maximum Probable Penetrati on * 0.192 inches (&4.8 % Wall Thickness) Percent Probability of Recording a Hole* 23.9% . Derived from data with average rank value less than or equal to 2U. 100 ( i PDS REPORT JOINT TABULATION ~HEET Pipe: 5. in 18.0 ppf L-80 Well: lY-24 Body Wall: 0.296 in Field: Kuparuk Upset Wall: 0.296 in Company: ConocoPhillips Alaska, Inc. NominaII.D.: 4.408 in Country: USA Survey Date: May 11,2003 Joint Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 .1 7681 0 0.12 41 6 4.17 PUP Isolated pitting. Lt. Deposits. 1 7700 0.03 0.08 26 5 4.33 Line corrosion. Lt. Deposits. 2 7743 0 0.03 11 3 4.31 Shallow pitting. 3 7784 0 0.03 10 9 4.39 4 7829 0 0.06 21 9 4.40 Isolated pitting. 5 7871 0.05 0.06 19 4 4.37 Line shallow corrosion. 6 7913 0 0.07 23 8 4.36 Line corrosion. 6.1 7957 0 0.03 9 3 4.38 PUP Slight Buckling. 6.2 7979 0 0.18 59 10 4.32 PUP Corrosion. Buckling. Lt. Deposits. 7 8000 0 0.16 55 13 3.82 Corrosion. Buckling. Deposits. I Penetration Body " Metal Loss Body Page 1 clds. PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 Y-24 Kuparuk ConocoPhillips Alaska¡ Inc. USA 5 ins 18 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: May 11¡ 2003 MFC 24 No. 99812 1.69 24 M. Lawrence Cross Section for Joint 6.2 at depth 7994.64 ft Tool speed = 52 Nominal 10 = 4.408 Nominal 00 = 5.000 Remaining wall area = 92 % Tool deviation = 28 0 Finger 1 5 Penetration = 0.176 ins Corrosion 0.18 ins = 59% Wall Penetration HIGH SIDE = UP Cross Sections page 1 clr3s. PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 Y-24 Kuparuk ConocoPhillips Alaska, Inc. USA 5 ins 18 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: May 11, 2003 MFC 24 No. 99812 1.69 24 M. Lawrence Cross Section for Joint 7 at depth 8014.88 ft Tool speed = 48 Nominal 10 = 4.408 Nominal 00 = 5.000 Remaining wall area = 96 % Tool deviation = 42 0 ,-~~~-> Finger 19 Penetration = 0.163 ins Corrosion 0.16 ins = 55% Wall Penetration HIGH SIDE = UP Cross Sections page 2 cIds -1\j ... ~ PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 Y-24 Kuparuk ConocoPhillips Alaska, Inc. USA 5 ins 18 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: May 111 2003 MFC 24 No. 99812 1.69 24 M. Lawrence Cross Section for Joint 7 at depth 8023.27 it Tool speed == 40 NominallD = 4.408 Nominal OD = 5.000 Remaining wall area == 97 % Tool deviation = 34 0 Finger 19 Projection = -0.5 ins Deposits in Buckled Liner Minimum I.D. == 3.82 ins HIGH SIDE == UP Cross Sections page 3 MICROFilMED Date ' 3/ DI /;i;:~:'~i:8 C~! f~ J~\~J ? C l~:J'; ,- .... ...~... ~~-.--I"i ¡;.....,.".. -. :.~..~. :11-...;' ~ '~ ARCO ALASKA, INC. 1Y-24 KUPARUK RIVER NORTH SLOPE ALASKA 50-029-22371-00 95036 COMPANY NAME WELL NAME FIELD NAME BOROUGH STATE API NUMBER REFERENCE NO ****************************** * * * ALASKA COMPUTING CENTER * * * ****************************** *----------------------------* *------- SCHLUMBERGER -------* *----------------------------* ****************************** '\ I f¡ Ô\, \ ,./ I 1\ " ~r, ,I..) . ~t~/ r, '-I -) r'-. \\J i ¡( . 1: ~ I i. LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-1996 16:16 PAGE: 1 ..*. REEL HEADER .... SERVICE NAME EDIT DATE 96/01/19 ORIGIN FLIC REEL NAME 95036 CONTINUATION # PREVIOUS REEL COMMENT ARCO ALASKA INC, 1Y-24, KUPARUK RIVER UNIT, 50-029-22371-00 ...* TAPE SERVICE NAME DATE ORIGIN TAPE NAME CONTINUATION # PREVIOUS TAPE COMMENT HEADER .*.* EDIT 96/01/19 FLIC 95036 1 ARCO ALASKA INC, 1Y-24, KUPARUK RIVER UNIT, 50-029-22371-00 TAPE HEADER KUPARUK RIVER CASED HOLE WIRELINE LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 1Y-24 500292237100 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 19-JAN-96 95036 G.JOHNSON R.SMITH 1 11N 9E 570 1762 107.00 107.00 66.00 # WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LBjFT) ------------- --------- ---------- -------------- 1ST STRING 7.00Ø 7568.0 26.00 2ND STRING 6.125 5.00Ø 8372.0 18.0Ø 3RD STRING 3.50Ø 7681.0 9.20 PRODUCTION STRING # CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) 1 FILE HEADER FILE NUMBER: EDITED CURVES HEADER "'''''''''' EDIT .001 FLIC 001C01 96/01/19 1024 LO "'''''''''' FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE The depth adjustments shown above reflect cased hole GR to open hole DTE GR and cased hole SIGM to open hole GR. AI I other TDTP curves were carried with the SIGM shifts. $ $ REMARKS: # ----------EQUIVALENT UNSHIFTED DEPTH---------- BASELINE DEPTH GRCH TDTP -------------- ------- ------- 88888.0 88888.5 88888.5 8106.0 8106.5 8106.5 8101. 0 8102.0 8102.0 8070.5 8070.5 8070.0 8070.5 8064.5 8065.5 8065.5 8028.0 8029.5 8029.5 8004.5 8006.0 8006.0 7958.0 7959.0 7959.0 7899.0 7900.5 7900.5 7869.5 7871. 5 7871. 5 7841. 0 7842.0 7842.0 7832.0 7834.0 7834.0 7801.5 7803.5 7803.5 7784.0 7785.0 7785.0 7738.0 7739.0 7739.0 7718.5 7719.5 7717.5 7719.0 7665.5 7666.5 7666.5 7624.0 7625.5 7625.5 7584.5 7586.0 7586.0 100.0 101.5 101. 5 $ # BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: DTE LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: SCHLUMBERGER WELL SERVICES 2 PAGE: 19-JAN-1996 16:16 LIS Tape Verification Listing Schlumberger Alaska Computing Center LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-1996 16:16 PAGE: 3 Depth shifted PASS NUMBER: DEPTH INCREMENT: # FILE SUMMARY LDWG TOOL CODE and clipped curves for each pass in separate fi les. 1 0.S000 START DEPTH STOP DEPTH -------------- ----------- ---------- GRCH TDTP $ 8130.0 8143.0 7140.0 7140.0 # CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: # ----------EQUIVALENT UNSHIFTED DEPTH---------- BASELINE DEPTH -------------- # $ REMARKS: This fi Ie contains TDTP Pass #l(Base pass #1). No pass to pass shifts were applied to this data. $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 ø 66 ø ------------------------------ LIS Tape Verification Listing 19-JAN-1996 16:16 PAGE: 4 Schlumberger Alaska Computing Center ** SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 5ØØ715 øø øøø øø ø 1 1 1 4 68 øøøøøøøøøø SIGM TDTP CU 5ØØ715 øø øøø øø ø 1 1 1 4 68 øøøøøøøøøø TPHI TDTP PU-S 5ØØ715 øø øøø øø ø 1 1 1 4 68 øøøøøøøøøø SBHF TDTP CU 5Ø0715 øø øøø øø ø 1 1 1 4 68 øøøøøøøøøø SBHN TDTP CU 5ØØ715 øø øøø øø ø 1 1 1 4 68 øøøøøøøøøø SIGC TDTP CU 5ØØ715 øø øøø øø ø 1 1 1 4 68 øøøøøøøøøø SIBH TDTP CU 50Ø715 øø øøø øø ø 1 1 1 4 68 øøøøøøøøøø TRAT TDTP 5ØØ715 øø øøø øø ø 1 1 1 4 68 øøøøøøøøøø LCØ1 TDTP 5ØØ715 ØØ Øøø ØØ ø 1 1 1 4 68 ØØØØøøØøøø SDSI TDTP CU 5ØØ715 øØ Øøø ØØ Ø 1 1 1 4 68 ØøØØØøØøøØ BACK TDTP CPS 5ØØ715 øø ØØø ØØ ø 1 1 1 4 68 ØØØØØøøØøØ FBAC TDTP CPS 5ØØ715 øø Øøø øØ ø 1 1 1 4 68 ØøØØØøøøøø TCAN TDTP CPS 5ØØ715 Øø ØØø ØØ ø 1 1 1 4 68 ØøØØøØøøøø TCAF TDTP CPS 5Ø0715 øø øøø øø ø 1 1 1 4 68 øøøøøøøøøø TCND TDTP CPS 5ØØ715 øø Øøø øø Ø 1 1 1 4 68 ØøøøøøØøøø TCFD TDTP CPS 5ØØ715 øø Øøø Øø ø 1 1 1 4 68 øØøøøøØøøø TSCN TDTP CPS 5ØØ715 øø ØØø øø ø 1 1 1 4 68 øøøøøøØøøø TSCF TDTP CPS 5ØØ715 øø Øøø Øø ø 1 1 1 4 68 øøøøøøØøøø INND TDTP CPS 5Ø0715 øø Øøø Øø ø 1 1 1 4 68 øøØøøøØøøø INFD TDTP CPS 5ØØ715 øø Øøø øø ø 1 1 1 4 68 øøøøøøØøøø GRCH TDTP GAP I 5ØØ715 Øø ØøØ Øø Ø 1 1 1 4 68 øØØØøøØøøø TENS TDTP LB 5ØØ715 Øø Øøø Øø Ø 1 1 1 4 68 ØØØØØØØØøø CCL TDTP V 5ØØ715 Øø Øøø Øø Ø 1 1 1 4 68 ØØØØØøØØØØ GR DTE GAPI 5ØØ715 Øø ØØØ ØØ ø 1 1 1 4 68 ØØØØØøØøØØ --------------------------------------------------------------------------------------- ** DATA ** DEPT. 815Ø.ØØØ SIGM.TDTP -999.250 TPHI.TDTP -999.25Ø SBHF.TDTP -999.25Ø SBHN.TDTP -999.25Ø SIGC.TDTP -999.250 SIBH.TDTP -999.25Ø TRAT.TDTP -999.25Ø LCØ1.TDTP -999.25Ø SDSI.TDTP -999.250 BACK.TDTP -999.25Ø FBAC.TDTP -999.25Ø TCAN.TDTP -999.25Ø TCAF.TDTP -999.250 TCND.TDTP -999.25Ø TCFD.TDTP -999.25Ø TSCN.TDTP -999.25Ø TSCF.TDTP -999.250 INND.TDTP -999.25Ø INFD.TDTP -999.25Ø GRCH.TDTP -999.25Ø TENS.TDTP -999.250 CCL.TDTP -999.250 GR.DTE 99.316 DEPT. 7141.5ØØ SIGM.TDTP 33.789 TPHI . TDTP 52.Ø56 SBHF.TDTP 56.7ØØ SBHN.TDTP 64.334 SIGC.TDTP Ø.879 SIBH.TDTP 123.811 TRAT.TDTP 1. 782 LCØ1.TDTP 3.158 SDS!. TDTP Ø.949 BACK.TDTP 135.226 FBAC.TDTP 24.805 TCAN.TDTP 12381.740 TCAF.TDTP 3597.069 TCND.TDTP 13668.Ø25 TCFD.TDTP 3190.137 TSCN.TDTP 1422.329 TSCF.TDTP 450.324 INND.TDTP 2186.682 INFD.TDTP 318.334 GRCH.TDTP 43.813 TENS.TDTP 930.000 CCL.TDTP 0.000 GR.DTE -999.250 ** END OF DATA ** 8112.0 8104.0 8100.S 8096.0 8114.0 88889.S 88889.S 8132.0 8128.S 8124.0 8121.0 811S.S ------- ------- 88888.0 8130.S 8126.S 8122.S 8118.S 8114.S 8112.S 8110.S 8102.5 8098.5 8094.5 -------------- BASELINE DEPTH # CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 ----------EQUIVALENT UNSHIFTED DEPTH---------- GRCH TDTP 7140.0 7140.Ø 8130.Ø 8143.Ø ---------- ----------- STOP DEPTH START DEPTH separate fi les. and clipped curves for each pass in 2 ø.Søøø 2 HEADER ..."''''''' EDIT .ØØ2 FLIC 001CØl 96/Ø1/19 1024 LO # GRCH TDTP $ -------------- FILE HEADER FILE NUMBER: EDITED CURVES Depth shifted PASS NUMBER: DEPTH INCREMENT: # FILE SUMMARY LDWG TOOL CODE .......... FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE "'''''''''' FILE TRAILER "'."'''' FILE NAME : EDIT .0Ø1 SERVICE : FLIC VERSION : ØØ1C01 DATE : 96/Ø1/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE S PAGE: 19-JAN-1996 16:16 LIS Tape Ve~ification Listing Schlumberger Alaska Computing Center 6 PAGE: 19-JAN-1996 16:16 7908.5 7904.0 7916.5 7920.0 7948.0 7944.5 7940.0 7936.5 7932.0 7928.0 7924.5 7952.5 7956.0 7976.0 7972.5 7968.0 7964.5 7960.5 7984.0 7988.5 8024.0 8020.5 8015.5 8011.5 8008.0 8004.0 8001.0 7996.5 8029.Ø 8044.5 8040.0 8036.0 8033.5 8049.0 8053.0 8076.0 8071. 5 806S.0 8064.5 8060.5 8056.0 7914.5 8074.5 8070.5 8066.5 8062.5 S058.5 S054.5 8052.5 S0S0.5 8048.5 8046.5 8044.5 8042.5 8038.5 8034.5 8030.5 8028.5 8026.5 8024.5 8022.5 8018.5 8014.5 8010.5 8006.5 8002.5 7998.5 7994.5 7988.5 7986.5 7984.5 7982.5 7980.5 7974.5 7970.5 7966.5 7962.5 7958.5 7956.5 7954.5 7952.5 7950.5 7948.5 7946.5 7942.5 7938.5 7934.5 7930.5 7926.5 7922.5 7920.5 791S.5 7916.5 7914.5 7912.5 7906.5 7902.5 7918.0 7922.5 7950.5 7954.0 7957.5 7981.5 7986.0 7990.5 8026.5 8031. 0 8047.0 8050.5 8054.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7 PAGE: 19-JAN-1996 16:16 7761. ø 7764.5 7768.0 7787.5 7784.0 7779.5 7776.0 7792.5 7797.0 7805.0 7809.5 7825.5 7830.0 7833.5 7848.5 7844.5 7841.0 7837.0 7851.5 7856.0 7860.0 7877.5 7873.5 7868.5 7864.5 7881.0 7889.0 7885.5 7893.0 7896.5 7900.5 7758.5 7898.S 7896.S 7894.S 7892.S 7890.S 7888.S 7886.5 7882.5 7880.5 7878.5 7876.5 7874.5 7870.5 7866.S 7862.5 7860.5 7858.5 7856.5 7854.5 7852.5 7850.5 7848.5 7846.5 7842.5 7838.5 7834.5 7832.5 7830.5 7828.5 7826.5 7824.5 7822.S 7820.5 7816.5 7812.5 7808.5 7806.5 7804.5 7802.5 7800.5 7794.5 7792.5 7790.5 7788.5 7786.5 7782.5 7778.5 7774.5 7768.5 7766.5 7764.5 7762.5 7760.5 7758.5 7756.5 7762.0 7766.5 7770.0 7790.0 7794.5 7802.5 7807.0 7823.5 7819.5 7815.0 7810.5 7826.5 7829.5 7834.0 7850.0 7854.5 7863.0 7858.5 7879.0 7882.5 7890.5 7894.0 7898.5 LIS Tape Ve~ification Listing Schlumberger Alaska Computing Center 8 PAGE: 19-JAN-1996 16:16 7556.5 7552.5 7549.0 7561.0 7564.0 7569.0 7572.5 7588.5 7596.0 7592.0 7643.0 7648.0 7652.0 7684.0 7660.0 7655.5 7688.5 7692.0 7704.0 7717.0 7708.5 7744.5 7740.0 7737.0 7733.0 7729.5 7725.0 7756.5 7558.0 7754.5 7752.5 7748.5 7742.5 7738.5 7734.5 7730.5 7728.5 7726.5 7724.5 7722.5 7720.5 7716.5 7714.5 7708.5 7706.5 7704.5 7702.5 7700.5 7696.5 7692.5 7690.5 7688.5 7686.5 7684.5 7682.5 7658.5 7654.5 7652.5 7650.5 7648.5 7646.5 7644.5 7642.5 764Ø.5 7616.5 7612.5 7608.5 7594.5 759Ø.5 7588.5 7586.5 7584.5 7572.5 7570.5 7568.5 7566.5 7564.5 7562.5 7560.5 7558.5 7556.5 7554.5 7550.5 7546.5 7563.0 7567.0 7571.5 7587.0 7575.0 7590.5 7642.5 7618.5 7615.0 7610.5 7646.0 7650.5 7654.0 7686.0 7690.5 7702.0 7698.0 7694.5 7706.5 7710.0 7722.5 7718.0 7726.5 7730.0 7754.S 7750.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9 PAGE: 19-JAN-1996 16:16 7375.5 7380.0 7383.0 7388.0 7392.0 7410.5 7405.0 7401. ø 7398.0 7418.5 7437.5 7444.5 7441. 0 7449.0 7452.5 7456.5 7460.0 7468.0 7476.5 7472.5 7480.0 7529.0 7520.5 7512.5 7509.0 7505.0 7500.0 7536.5 7540.5 7545.0 7374.0 7370.5 7544.5 7542.5 7540.5 7538.5 7536.5 7534.5 7532.5 7526.5 7518.5 7510.5 7506.5 7502.5 7498.5 7480.5 7478.5 7476.5 7474.5 7470.5 7468.5 7466.5 7464.5 7458.5 7456.5 7454.5 7452.5 7450.5 7448.5 7446.5 7444.5 7442.5 7438.5 7436.5 7434.5 7432.5 7428.5 7424.5 7416.5 7414.5 7412.5 7406.5 7402.5 7398.5 7394.5 7392.5 7390.5 7388.5 7386.5 7384.5 7382.5 7380.5 7378.5 7376.5 7374.5 7372.5 7368.5 7378.0 7382.5 7386.0 7390.0 7394.5 7414.5 7434.5 7430.5 7426.0 7418.0 7439.0 7447.0 7450.5 7454.0 7458.5 7466.5 7470.0 7478.0 7482.5 7534.5 7538.0 7542.5 7546.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7364.5 7366.Ø 736Ø.5 7362.5 7356.5 7358.Ø 7352.5 7354.Ø 735Ø.5 7351. 5 7348.5 7350.5 7346.5 7348.5 7344.5 7346.Ø 7342.5 7344.5 7338.5 7341.0 7334.5 7336.0 7330.5 7332.0 7326.5 7328.5 7322.5 7324.0 7318.5 7320.5 7310.5 7312.5 7308.5 7310.Ø 7306.5 7308.0 7304.5 7306.5 7298.5 7300.0 7294.5 7295.5 7290.5 7292.0 7286.5 7288.5 7282.5 7283.0 7278.5 728Ø.5 7276.5 7278.5 7274.5 7276.5 7272.5 7274.Ø 7270.5 7272.Ø 7268.5 727Ø.5 7266.5 7268.5 7258.5 726Ø.5 7256.5 7258.5 7254.5 7255.5 7252.5 7254.Ø 7246.5 7248.5 723Ø.5 7233.5 7226.5 7229.Ø 722Ø.5 7222.5 7218.5 7221. Ø 7216.5 7219.Ø 7214.5 7216.5 7212.5 7214.5 721Ø.5 7212.0 7206.5 7208.5 7202.5 7204.5 7198.5 7200.0 7178.5 7180.0 7174.5 7176.5 100.0 102.0 102.0 $ # REMARKS: This fi Ie contains Borax pass #1 of the TDTP. The depth correction shown above reflect Borax pass #1 GRCH to base pass #1 GRCH and Borax pass #1 SIGMA to base pass 10 PAGE: 19-JAN-1996 16:16 LIS Tape Verification Listing Schlumberger Alaska Computing Center LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-1996 16:16 PAGE: 11 #1 SIGMA. All other TDTP curves were carried with the SIGMA shifts. $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 66 ø 2 66 ø 3 73 92 4 66 1 5 66 6 73 7 65 8 68 Ø.5 9 65 FT 11 66 11 12 68 13 66 ø 14 65 FT 15 66 68 16 66 1 ø 66 1 ------------------------------ ** SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER :It LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 5ØØ715 øø øøø øø ø 2 1 1 4 68 øøøøøøøøøø SIGM TDTP CU 5ØØ715 øø øøø øø ø 2 1 1 4 68 øøøøøøøøøø TPHI TDTP PU-S 5ØØ715 øø øøø øø ø 2 1 1 4 68 øøøøøøøøøø SBHF TDTP CU 5ØØ715 øø øøø øø ø 2 1 1 4 68 øøøøøøøøøø SBHN TDTP CU 5ØØ715 øø øøø øø ø 2 1 1 4 68 øøøøøøøøøø SIGC TDTP CU 5ØØ715 øø øøø øø ø 2 1 1 4 68 øøøøøøøøøø SIBH TDTP CU 5ØØ715 øø øøø øø ø 2 1 1 4 68 øøøøøøøøøø TRAT TDTP 5ØØ715 øø øøø øø ø 2 1 1 4 68 øøøøøøøøøø LCØ1 TDTP 5ØØ715 øø øøø øø ø 2 1 1 4 68 øøøøøøøøøø SDSI TDTP CU 5ØØ715 øø øøø øø ø 2 1 1 4 68 øøøøøøøøøø BACK TDTP CPS 5ØØ715 øø øøø øø ø 2 1 1 4 68 øøøøøøøøøø FBAC TDTP CPS 5ØØ715 øø øøø øø ø 2 1 1 4 68 øøøøøøøøøø TCAN TDTP CPS 5ØØ715 øø øøø øø ø 2 1 1 4 68 øøøøøøøøøø TCAF TDTP CPS 5ØØ715 øø øøø øø ø 2 1 1 4 68 øøøøøøøøøø TCND TDTP CPS 5ØØ715 øø øøø øø ø 2 1 1 4 68 øøøøøøøøøø TCFD TD TP CPS 5ØØ715 øø øøø øø ø 2 1 1 4 68 øøøøøøøøøø TSCN TDTP CPS 5ØØ715 øø øøø øø ø 2 1 1 4 68 øøøøøøøøøø HEADER "'..."'''' EDIT .003 FLIC 001C01 96/01/19 1024 LO "'''''''''' FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE "'*"'* FILE TRAILER **"'''' FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE ** DATA ** DEPT. 8144.5Ø0 SIGM.TDTP 4Ø.83Ø TPHI.TDTP 88.382 SBHF.TDTP 5Ø.154 SBHN.TDTP 56.255 SIGC.TDTP 0.Ø00 SIBH.TDTP 97.976 TRAT.TDTP 2.178 LC01.TDTP 4.405 SDSI.TDTP 0.898 BACK.TDTP 124.838 FBAC.TDTP 33.Ø28 TCAN.TDTP 55201. 414 TCAF.TDTP 12244.564 TCND.TDTP 14994.383 TCFD.TDTP 3093.ØØ7 TSCN.TDTP 1531.922 TSCF.TDTP 347.786 INND.TDTP 2184.821 INFD.TDTP 3ØØ.734 GRCH.TDTP -999.250 TENS.TDTP 1340.000 CCL.TDTP 0.Ø00 DEPT. 7142.Ø00 SIGM.TDTP 33.469 TPHI.TDTP 48.509 SBHF.TDTP 63.317 SBHN . TDTP 75.625 SIGC.TDTP 0.656 SIBH.TDTP 159.920 TRAT.TDTP 1.718 LC01 . TDTP 3.088 SDSI.TDTP 0.972 BACK.TDTP 152.591 FBAC.TDTP 26.331 TCAN.TDTP 10667.773 TCAF.TDTP 3205.881 TCND.TDTP 10633.871 TCFD.TDTP 2582.303 TSCN . TDTP 1149.762 TSCF.TDTP 372.341 INND.TDTP 1850.385 INFD.TDTP 259.646 GRCH.TDTP 50.094 TENS.TDTP 985.000 CCL.TDTP 0.000 ** END OF DATA ** --------------------------------------------------------------------------------------- ---------------------------------------------------------------------'------------------ NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER . LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- TSCF TDTP CPS 5ØØ715 ØØ ØØØ ØØ Ø 2 1 1 4 68 Ø0ØØØØØØøø INND TDTP CPS 5ØØ715 øø ØøØ Øø ø 2 1 1 4 68 øøøøøØøøøø INFD TDTP CPS 50Ø715 øø ØØø ØØ ø 2 1 1 4 68 Øøøøøøøøøø GRCH TDTP GAP I 5ØØ715 øø 0ØØ øØ ø 2 1 1 4 68 ØØØØ00ØØØØ TENS TDTP LB 50Ø715 øø ØØø Øø ø 2 1 1 4 68 Øøøøøøøøøø CCL TDTP V 5ØØ715 0Ø øØø øø ø 2 1 1 4 68 ØØØØØ0ØØ00 12 PAGE: 19-JAN-1996 16:16 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8039.5 8113.5 88888.0 8130.5 8126.5 8118.5 8114.5 8112.5 8110.5 81Ø0.5 8098.5 8096.5 8094.5 8092.5 8090.5 8088.5 8086.5 8084.5 8080.5 8078.5 8076.5 8074.5 8072.5 8064.5 8060.5 8056.5 8054.5 8052.5 8050.5 8048.5 8046.5 8044.5 8042.5 8040.5 8038.5 8042.5 8044.0 8046.0 8047.5 8050.0 8051.0 8053.5 8055.5 8073.5 8065.5 8062.Ø 8057.5 8075.5 8077.0 8080.0 8085.0 8081.5 8088.0 8089.5 8091.0 8093.5 8095.0 8098.0 8099.5 81Ø1.5 8111.5 88889.0 8131.5 8127.0 8119.0 8114.5 88889.0 ------- ------- -------------- # CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 ----------EQUIVALENT UNSHIFTED DEPTH---------- GRCH TDTP BASELINE DEPTH # 7121. 0 7121.0 813Ø.Ø 8143.0 GRCH TDTP $ ---------- ----------- -------------- STOP DEPTH START DEPTH SFILE HEADER FILE NUMBER: EDITED CURVES Depth sh i fted PASS NUMBER: DEPTH INCREMENT: # FILE SUMMARY LDWG TOOL CODE and clipped curves for each pass in separate fi les. 3 Ø.5Ø0Ø 3 13 PAGE: 19-JAN-1996 16:16 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14 PAGE: 19-JAN-1996 16:16 7831.5 7847.5 7868.5 7864.0 7852.0 7876.5 7880.0 7884.5 7889.0 7928.5 7924.0 7904.0 7900.5 7896.5 7892.0 7931.5 7935.5 7956.0 7952.5 7947.5 7944.0 7940.0 7972.0 8008.0 8003.5 8000.5 7996.5 7992.0 7988.0 7983.5 7979.5 7975.0 8024.0 8029.5 8035.5 8033.5 7845.5 7837.5 7834.0 8034.5 8030.5 8028.5 8026.5 8024.5 8022.5 8020.5 8016.5 8006.5 8002.5 7998.5 7994.5 7990.5 7986.5 7982.5 7978.5 7974.5 7972.5 7970.5 7968.5 7954.5 7950.5 7946.5 7942.5 7938.5 7936.5 7934.5 7932.5 7930.5 7928.5 7926.5 7922.5 7902.5 7898.5 7894.5 7890.5 7888.5 7886.5 7884.5 7882.5 7880.5 7878.5 7876.5 7874.5 7872.5 7868.5 7866.5 7862.5 7850.5 7848.5 7846.5 7844.5 7836.5 7832.5 7830.5 7850.0 7874.5 7870.0 7878.5 7882.0 7886.5 7890.0 7930.0 7934.5 7937.5 7969.5 7974.0 8022.5 8018.0 8026.0 8030.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15 PAGE: 19-JAN-1996 16:16 7564.0 7584.0 7580.0 7575.5 7571.5 7568.5 7644.5 7683.5 7667.5 7664.0 7660.0 7655.5 7652.0 7648.0 7688.0 7700.0 7695.5 7692.0 7768.5 7763.5 7760.0 7752.0 7747.5 7731. 5 7729.0 7721.0 7717.5 7713.0 7708.0 7772.0 7808.0 7804.5 7800.0 7788.0 7782.5 7779.5 7776.0 7813.0 7829.0 7566.0 7826.5 7824.5 7820.5 7816.5 7812.5 7810.5 7808.5 7806.5 7802.5 7798.5 7786.5 7782.5 7778.5 1774.5 1772.5 1770.5 7768.5 7766.5 7762.5 7758.5 7750.5 7746.5 7730.5 7726.5 7718.5 7714.5 7710.5 7706.5 7704.5 7700.5 7698.5 7694.5 7690.5 7688.5 7686.5 7684.5 7682.5 7666.5 7662.5 7658.5 7654.5 7650.5 7646.5 7644.5 7642.5 7640.5 7636.5 7632.5 7582.5 7578.5 7574.5 7570.5 7566.5 7564.5 7562.5 7642.0 7637.5 7634.0 7645.5 7685.5 7690.0 7705.5 7702.0 7174.0 7769.5 7810.0 7826.0 7823.0 7818.5 7814.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16 PAGE: 19-JAN-1996 16:16 7354.0 7367.0 7363.0 7371.5 7374.5 7386.5 7391.0 7400.5 7425.0 7420.0 7416.5 7428.5 7434.0 7437.5 7441. ø 7448.0 7445.0 7492.0 7488.5 7484.0 7556.0 7551.0 7548.0 7545.0 7539.5 7536.0 7353.5 7560.5 7554.5 7550 . 5 7546.5 7542.5 7538.5 7534.5 7528.5 7524.5 7504.5 7500.5 7496.5 7492.5 7490.5 7486.5 7482.5 7476.5 7472.5 7468.5 7464.5 7446.5 7442.5 7440.5 7438.5 7436.5 7434.5 7432.5 7430.5 7428.5 7426.5 7424.5 7422.5 7418.5 7414.5 7408.5 7404.5 7400.5 7398.5 7396.5 7392.5 7390.5 7388.5 7386.5 7380.5 7376.5 7374.5 7372.5 7370.5 7368.5 7366.5 7362.5 7360.5 7356.5 7354.5 7352.5 7362.0 7357.5 7370.0 7373.5 7381.5 7378.0 7389.5 7397.5 7394.0 7409.5 7406.0 7402.0 7425.5 7429.0 7433.5 7437.5 7442.0 7478.0 7473.5 7469.5 7466.0 7529.5 7526.0 7506.0 7501.5 7497.5 7494.0 7561. 5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17 PAGE: 19-JAN-1996 16:16 101.5 7191.5 7188.0 7203.5 7252.5 7248.0 7243.5 7239.5 7236.0 7232.5 7227.5 7219.5 7214.5 7211.0 7206.0 7260.0 7268.0 7276.5 7271. 5 7312.0 7309.0 7305.5 7301. 0 7296.5 7293.5 7289.5 7284.5 7317.0 7320.5 7324.0 7327.5 7348.0 7344.0 7340.5 7335.5 7350.5 # $ 7174.0 7169.5 101.0 7350.5 7348.5 7346.5 7342.5 7338.5 7334.5 7328.5 7326.5 7324.5 7322.5 7320.5 7318.5 7316.5 7314.5 7312.5 7310.5 7306.5 7302.5 7298.5 7294.5 7290.5 7286.5 7282.5 7280.5 7276.5 7274.5 7270.5 7268.5 7266.5 7264.5 7260.5 7258.5 7256.5 7252.5 7250.5 7246.5 7242.5 7238.5 7234.5 7230.5 7226.5 7218.5 7214.5 7210.5 7206.5 7204.5 7202.5 7200.5 7190.5 7186.5 7172.5 7168.5 100.0 7202.0 7205.5 7257.0 7253.5 7266.0 7261. 5 7269.5 7282.5 7277.5 7314.5 7318.0 7322.5 7326.5 7330.Ø 7350.Ø LIS Tape Verification Listing Schlumberger Alaska Computing Center LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-1996 16:16 PAGE: 18 REMARKS: This fi Ie contains Borax pass #2 of the TDTP. The depth correction shown above reflect Borax pass #2 GRCH to base pass #1 GRCH and Borax pass #2 SIGMA to base pass #1 SIGMA. AI I other TDTP curves were carried with the SIGMA shifts. $ # LIS FORMAT DATA S SSSS "'''' DATA FORMAT SPECIFICATION RECORD *'" "'* SET TYPE - 64EB "'* ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 66 ø 2 66 ø 3 73 92 4 66 1 5 66 6 73 7 65 8 68 Ø.5 9 65 FT 11 66 11 12 68 13 66 Ø 14 65 FT 15 66 68 16 66 1 Ø 66 1 ------------------------------ .. SET TYPE - CHAN .. --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 5ØØ715 øø øøØ ØØ Ø 3 1 1 4 68 øøøøøøøøøø SIGM TDTP CU 5ØØ715 øØ øøØ ØØ ø 3 1 1 4 68 ØØøøøøøøøø TPHI TDTP PU-S 5ØØ715 øø øøØ Øø ø 3 1 1 4 68 øøøøøøøøøø SBHF TDTP CU 5ØØ715 øø øøø øø ø 3 1 1 4 68 øøøøøøøøøø SBHN TDTP CU 5ØØ715 øø øøø øø ø 3 1 1 4 68 øøøøøøøøøø SIGC TDTP CU 5ØØ715 øø øøø øø ø 3 1 1 4 68 øøøøøøøøøø SIBH TDTP CU 5ØØ715 øø øøø øø ø 3 1 1 4 68 øøøøøøøøøø TRAT TDTP 5ØØ715 øø øøø øø ø 3 1 1 4 68 øøøøøøøøøø LCØl TDTP 5ØØ715 øø øøø øø ø 3 1 1 4 68 øøøøøøøøøø SDSI TDTP CU 5ØØì15 øø øøø øø ø 3 1 1 4 68 øøøøøøøøøø BACK TDTP CPS 5ØØ715 øø øøø øø ø 3 1 1 4 68 øøøøøøøøøø FBAC TDTP CPS 5ØØ715 øø øøø øø ø 3 1 1 4 68 øøøøøøøøøø "'*"'''' FILE TRAILER "'''''''''' FILE NAME : EDIT .0Ø3 SERVICE : FLIC VERSION : Ø01C01 DATE : 96/Ø1/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE "'''' DATA "'''' DEPT. 8144.Ø00 SIGM.TDTP 39.588 TPHI.TDTP 83.542 SBHF.TDTP 45.658 SBHN.TDTP 54.409 SIGC.TDTP Ø.000 SIBH.TDTP 92.072 TRAT.TDTP 2.161 LC01.TDTP 4.252 SDSI.TDTP 1.424 BACK.TDTP 113.775 FBAC.TDTP 29.966 TCAN.TDTP 19283.73Ø TCAF.TDTP 443Ø.Ø21 TCND.TDTP 15608.672 TCFD.TDTP 3232.783 TSCN.TDTP 1689.Ø47 TSCF.TDTP 397.253 INND.TDTP 2316.5Ø9 INFD.TDTP 305.962 GRCH.TDTP -999.25Ø TENS.TDTP 1165.000 CCL.TDTP ø.øøø DEPT. 7122.ØØØ SIGM.TDTP -999.250 TPHI.TDTP -999.25Ø SBHF.TDTP -999.25Ø SBHN.TDTP -999.25Ø SIGC.TDTP -999.25Ø SIBH.TDTP -999.25Ø TRAT.TDTP -999.250 LC01.TDTP -999.25Ø SDSI.TDTP -999.25Ø BACK.TDTP -999.25Ø FBAC.TDTP -999.25Ø TCAN.TDTP -999.25Ø TCAF.TDTP -999.25Ø TCND.TDTP -999.25Ø TCFD.TDTP -999.25Ø TSCN. TDTP -999.25Ø TSCF.TDTP -999.250 INND.TDTP -999.25Ø INFD.TDTP -999.250 GRCH.TDTP 53.094 TENS.TDTP -999.250 CCL.TDTP -999.25Ø "'''' END OF DATA "'''' LIS Tape Verification Listing 19-JAN-1996 16:16 PAGE: 19 Schlumberger Alaska Computing Center --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- TCAN TDTP CPS 5Ø0715 øØ øøø ØØ ø 3 1 1 4 68 ØØØ0ØØØ0ØØ TCAF TDTP CPS 5Ø0715 øø øøø ØØ ø 3 1 1 4 68 0ØØØØØØøøø TCND TDTP CPS 5ØØ715 0Ø øøø øø ø 3 1 1 4 68 øØØØØØØ00Ø TCFD TDTP CPS 50Ø715 øØ 0ØØ Øø ø 3 1 1 4 68 ØøøØØøØØØØ TSCN TDTP CPS 5ØØ715 øØ øøø Øø 0 3 1 1 4 68 ØøØØØØØØ0Ø TSCF TDTP CPS 5ØØ715 ØØ øøØ ØØ ø 3 1 1 4 68 ØØØØØØØØ0Ø INND TD TP CPS 5ØØ715 øØ Ø0Ø øø ø 3 1 1 4 68 ØØøøØØØØØØ INFD TDTP CPS 5ØØ715 øØ øØØ øø ø 3 1 1 4 68 ØøøøØØØøøø GRCH TDTP GAPI 5ØØ715 0Ø øøø øø ø 3 1 1 4 68 øøøØØØØØØ0 TENS TDTP LB 5Ø0715 øØ øøø øø 0 3 1 1 4 68 ØØØØØØØ00Ø CCL TDTP V 5ØØ715 øø øøø Øø ø 3 1 1 4 68 ØøøøøøøøØØ --------------------------------------------------------------------------------------- LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-1996 16:16 PAGE: 20 "'''''''II< FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE HEADER "'''''''''' EDIT .004 FLIC 001C01 96/01/19 1024 LO FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and back round counts; arithmetic average of edited static baseline passes for al I other curves. DEPTH INCREMENT 0.SØØØ # PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS -------------- ------------ TDTP $ REMARKS: 1, No arithmetic average 3 was computed because there is only one base pass logged (no pumping). This data is identical to the main base pass in fi Ie #1. $ # LIS FORMAT DATA "'* DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB "'* ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 ø 14 65 FT 15 66 68 16 66 1 "'* DATA ** DEPT. 8143.5ØØ SIGM.PNAV 39.495 TPHI.PNAV 7Ø.192 SBHF.PNAV 42.74Ø SBHN.PNAV 55.378 SIGC.PNAV ø.øøø SIBH.PNAV 95.171 TRAT.PNAV 1. 949 SDSI.PNAV Ø.88Ø BACK.TDTP 72.459 FBAC.TDTP 19.4Ø5 TCAN.PNAV 1619Ø.Ø41 TCAF.PNAV 4Ø99.591 TCND.PNAV 15919.311 TCFD.PNAV 3477.22Ø TSCN.PNAV 1665.384 TSCF.PNAV 428.794 INND.PNAV 2175.329 INFD.PNAV 336.7Ø4 LCØ1.PNAV 3.884 GRCH.TDTP -999.25Ø DEPT. 7141. 5ØØ SIGM.PNAV 33.789 TPHI. PNAV 52.Ø56 SBHF.PNAV 56.7ØØ SBHN.PNAV 64.334 SIGC.PNAV 0.879 SIBH.PNAV 123.811 TRAT.PNAV 1.782 SDSI.PNAV Ø.949 BACK.TDTP 135.226 FBAC.TDTP 24.8Ø5 TCAN.PNAV 12381.74Ø TCAF.PNAV 3597.Ø69 TCND.PNAV 13668.025 TCFD.PNAV 3190.137 TSCN.PNAV 1422.329 TSCF.PNAV 45Ø.324 INND.PNAV 2186.682 INFD.PNAV 318.334 LCØ1.PNAV 3.158 GRCH.TDTP 43.813 ** END OF DATA ** LIS Tape Verification Listing 19-JAN-1996 16:16 PAGE: 21 Schlumberger Alaska Computing Center ------------------------------ TYPE REPR CODE VALUE ------------------------------ ø 66 1 ------------------------------ "'* SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ff: LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 5ØØ715 Ø0 øøø øø ø 4 1 1 4 68 ØØØ0ØØØØØØ SIGM PNAV CU 5ØØ715 øø øøø øø ø 4 1 1 4 68 øøøøøøøØøø TPHI PNAV PU-S 5ØØ715 øø øøø øø ø 4 1 1 4 68 øøøøøøøøøø SBHF PNAV CU 5ØØ715 øø øøø øø ø 4 1 1 4 68 øøøøøøøøøø SBHN PNAV CU 5Ø0715 øø øøø øø ø 4 1 1 4 68 øøøøøøøøøø SIGC PNAV CU 500715 øø Ø00 øø ø 4 1 1 4 68 øøøØøøøøøø SIBH PNAV CU 5ØØ715 øø øøø øø ø 4 1 1 4 68 øøøøøøøøøø TRAT PNAV 5ØØ715 øø øøø øø ø 4 1 1 4 68 øøøøøøøøøø SDSI PNAV CU 5ØØ715 øø øøø øø ø 4 1 1 4 68 øøøøøøøøøø BACK TDTP CPS 5ØØ715 øø øøø øø ø 4 1 1 4 68 øøøøøøøøøø FBAC TDTP CPS 5ØØ715 øø øøø øø ø 4 1 1 4 68 øøøøøøøøøø TCAN PNAV CPS 5ØØ715 øø øøø øø ø 4 1 1 4 68 øøøøøøøøøø TCAF PNAV CPS 5ØØ715 øø øøø øø ø 4 1 1 4 68 øøøøøøøøøø TCND PNAV CPS 5ØØ715 øø øøø øø ø 4 1 1 4 68 øøøøøøøøøø TCFD PNAV CPS 5ØØ715 øø øøø øø ø 4 1 1 4 68 øøøøøøøøøø TSCN PNAV CPS 5ØØ715 øø øøø øø ø 4 1 1 4 68 øøøøøøøøøø TSCF PNAV CPS 5ØØ715 øø øøø øø ø 4 1 1 4 68 øøøøøøøøøø INND PNAV CPS 5ØØ715 øø øøø øø ø 4 1 1 4 68 øøøøøøøøøø INFD PNAV CPS 5ØØ715 øø øøø øø ø 4 1 1 4 68 øøøøøøøøøø LCØ1 PNAV 5ØØ715 øø øøø øø ø 4 1 1 4 68 øøøøøøøøøø GRCH TOTP GAPI 5ØØ715 øø øøø øø ø 4 1 1 4 68 øøøøøøøøøø --------------------------------------------------------------------------------------- LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-1996 16:16 PAGE: 22 **** FILE TRAILER **** FILE NAME EDIT .004 SERVICE FLIC VERSION 001C01 DATE 96/01/19 MAX REC SIZE 1024 FILE TYPE LO LAST FILE **** FILE HEADER **** FILE NAME EDIT .005 SERVICE FLIC VERSION 001C01 DATE 96/01/19 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate fi les; raw background pass in last fi Ie PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 f : FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- TDTP 8143.0 $ 7140.Ø f : LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE Ø7-JAN-95 CP4Ø.2 lØ0Ø 07-JAN-JA 8286.Ø 7140.Ø 8146.0 180Ø.0 NO f : TOOL NUMBER ---------------- --------- ----------- TDTP TDTP TDTP TDTP CCL $ TDTP SONDE GENERATOR TDTP SONDE DETECTOR TDTP CARTRIDGE TELEMETRY CARTRIDGE COLLAR LOG TNG-P-236 TND-P-75 TNC-P-141 ATC-CB-1163 CAL-UB-597 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-1996 16:16 PAGE: 23 * * BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): lOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 7568.Ø BORAX WATER -15.Ø # # # BLUELINE COUNT RATE SCALES SET BY FIELD FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE lOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): ENGINEER ø 12ØØØ Ø 3ØØØØ # REMARKS: TIED INTO CET DATED 7/16/93 ***. JOB SEQUENCE ...* 1) MADE BASE TDT PASS - NO PUMPING DONE 2) PUMPED 4Ø BBLS OF BORAX WATER INTO PERFS 3) MADE 1ST BORAX PASS 5) PUMPED 6Ø MORE BBLS OF BORAX WATER INTO PERFS - BORAX WATER OVER DISPLACED INTO PERFS BY APROX. 10 BBlS SEAWATER ALL FLUIDS APPEAR TO BE GOING INTO THE PERFS. NO CHANNELS, LEAKS OR FLOW AROUND THE LINER LAP WAS FOUND. This is base pass #1. $ # LIS FORMAT DATA LIS Tape Verification Listing 19-JAN-1996 16:16 PAGE: 24 Schlumberger Alaska Computing Center ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ------------------------------ ** SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 500715 00 000 00 ø 5 1 1 4 68 0ØØØØØØøøø SIGM PS1 CU 500715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø TPHI PS1 PU 500715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø SBHF PS1 CU 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø SBHN PS1 CU 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø SIGC PS1 CU 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø SIBH PS1 CU 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø TRAT PS1 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø LCØ1 PS1 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø SDSI PS1 CU 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø BACK PS1 CPS 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø FBAC PS1 CPS 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø TCAN PS1 CPS 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø TCAF PS1 CPS 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø TCND PS1 CPS 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø TCFD PS1 CPS 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø TSCN PS1 CPS 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø TSCF PS1 CPS 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø INND PS1 CPS 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø INFD PS1 CPS 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø TENS PS1 LB 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø GR PS1 GAPI 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø CCl PS1 V 5ØØ715 øø øøø øø ø 5 1 1 4 68 øøøøøøøøøø --------------------------------------------------------------------------------------- 7140.0 TDTP 8143.0 $ ---------- ---------------- ----------- FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate fi les; raw background pass in last fi Ie PASS NUMBER: 2 DEPTH INCREMENT: Ø.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..** FILE HEADER .*.* FILE NAME : EDIT .ØØ6 SERVICE : FLIC VERSION : Ø01C01 DATE : 96/01/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE TRAILER *... FILE NAME : EDIT .Ø05 SERVICE : FLIC VERSION : Ø01CØ1 DATE : 96/01/19 MAX REC SIZE : 1Ø24 FILE TYPE : LO LAST FILE .. DATA .. DEPT. 815Ø.ØØØ SIGM.PS1 34.928 TPHI.PS1 Ø.00Ø SBHF.PSl 67.774 SBHN.PS1 lØ8.952 SIGC.PSl Ø.ØØ0 SIBH.PSl 147.717 TRAT.PSl Ø.ØØ0 LC01.PS1 Ø.øØø SDSI.PSl 1.804 BACK.PS1 19.984 FBAC.PS1 20.3Ø7 TCAN.PS1 ø.øøø TeAF.PS1 0.ØØØ TCND.PS1 -244.478 TCFD.PS1 -242.951 TSCN.PS1 Ø.øØø TSeF.PS1 Ø.ØØ0 INND.PS1 -Ø.679 INFD.PS1 -0.690 TENS.PS1 855.ØØØ GR.PS1 52.75Ø CCL.PS1 Ø.000 DEPT. 7138.50Ø SIGM.PS1 34.169 TPHI.PS1 55.139 SBHF.PS1 56.669 SBHN.PS1 63.425 SIGC.PS1 Ø.671 SIBH.PS1 120.906 TRAT.PS1 1.831 Leø1.PS1 3.378 SDSI.PS1 Ø.986 BACK.PS1 137.380 FBAC.PS1 25.861 TCAN.PSl 12367.297 TeAF.PS1 3528.464 TCND.PS1 13736.799 TCFD.PS1 3213.157 TSCN.PSl 1431. 413 TSCF.PSl 423.781 INND.PS1 2318.255 INFD.PS1 317.2Ø8 TENS.PS1 93Ø.0ØØ GR.PS1 48.ØØØ CeL.PS1 Ø.Ø00 .. END OF DATA .. 25 PAGE: 19-JAN-1996 16:16 LIS Tape Verification Listing Schlumberger Alaska Computing Center LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-1996 16:16 PAGE: 26 f LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 07-JAN-95 CP40.2 1000 07-JAN-JA 8286.0 7140.0 8146.0 1800.0 NO f TOOL NUMBER ---------------- --------- ----------- TDTP TDTP TDTP TDTP CCL $ TDTP SONDE GENERATOR TDTP SONDE DETECTOR TDTP CARTRIDGE TELEMETRY CARTRIDGE COLLAR LOG TNG-P-236 TND-P-75 TNC-P-141 ATC-CB-1163 CAL-UB-597 f f BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 7568.0 BORAX WATER -15.0 f # # BLUELINE COUNT RATE SCALES SET BY FIELD FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): ENGINEER o 120ØØ ø 3ØØØØ LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-1996 16:16 PAGE: 27 # REMARKS: TIED INTO CET DATED 7/16/93 .... JOB SEQUENCE .... 1) MADE BASE TDT PASS - NO PUMPING DONE 2) PUMPED 4Ø BBLS OF BORAX WATER INTO PERFS 3) MADE 1ST BORAX PASS 5) PUMPED 6Ø MORE BBLS OF BORAX WATER INTO PERFS - BORAX WATER OVER DISPLACED INTO PERFS BY APROX. 1Ø BBLS SEAWATER ALL FLUIDS APPEAR TO BE GOING INTO THE PERFS. NO CHANNELS, LEAKS OR FLOW AROUND THE LINER LAP WAS FOUND. This is BORAX pass #1. $ # LIS FORMAT DATA .. DATA FORMAT SPECIFICATION RECORD .'" "'''' SET TYPE - 64EB .. ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 66 ø 2 66 ø 3 73 92 4 66 1 5 66 6 73 7 65 8 68 Ø.5 9 65 FT 11 66 11 12 68 13 66 Ø 14 65 FT 15 66 68 16 66 1 Ø 66 1 ------------------------------ .'" SET TYPE - CHAN .'" --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 5ØØ715 øø øøø øø ø 6 1 1 4 68 øøøøøøøøøø SIGM PS2 CU 5ØØ715 øø øøø øø ø 6 1 1 4 68 øøøøøøøøøø TPHI PS2 PU 5ØØ715 øø øøø øø ø 6 1 1 4 68 øøøøøøøøøø SBHF PS2 CU 5ØØ715 øø øøø øø ø 6 1 1 4 68 øøøøøøøøøø SBHN PS2 CU 5ØØ715 øø øøø øø ø 6 1 1 4 68 øøøøøøøøøø SIGC PS2 CU 5ØØ715 øø øøø øø ø 6 1 1 4 68 øøøøøøøøøø SIBH PS2 CU 5ØØ715 øø øøø øø ø 6 1 1 4 68 øøøøøøøøøø TRAT PS2 5ØØ715 øø øøø øø ø 6 1 1 4 68 øøøøøøøøøø **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE ** DATA ** DEPT. 815Ø.000 SIGM.PS2 34.445 TPHI.PS2 Ø.ØØ0 SBHF.PS2 93.512 SBHN.PS2 1Ø4.393 SIGC.PS2 ø.øøø SIBH.PS2 14Ø.693 TRAT.PS2 Ø.Ø00 LCØ1.PS2 Ø.Ø0Ø SDSI.PS2 Ø.678 BACK.PS2 219.063 FBAC.PS2 6Ø.245 TCAN.PS2 Ø.ØØ0 TCAF.PS2 Ø.ØØ0 TCND.PS2 -2461.8Ø9 TCFD.PS2 -674.453 TSCN.PS2 Ø.Ø0Ø TSCF.PS2 Ø.ØØ0 INND.PS2 -7.446 INFD.PS2 -2.048 TENS.PS2 1115.000 GR.PS2 76.25Ø CCL.PS2 0.0Ø0 D EPT . 7139.000 SIGM.PS2 33.072 TPHI.PS2 51.198 SBHF.PS2 65.140 SBHN.PS2 74.179 SIGC.PS2 0.637 SIBH.PS2 155.297 TRAT.PS2 1.786 LC01.PS2 3.182 SDS!. PS2 Ø.95Ø BACK.PS2 151.872 FBAC.PS2 26.80Ø TCAN.PS2 10741.232 TCAF.PS2 3135.870 TCND.PS2 10685.963 TCFD.PS2 2562.232 TSCN.PS2 1168.899 TSCF.PS2 367.293 INND.PS2 1860.140 INFD.PS2 269.513 TENS.PS2 1010.000 GR.PS2 53.531 CCL.PS2 0.000 ** END OF DATA ** LIS Tape Verification Listing 19-JAN-1996 16:16 PAGE: 28 Schlumberger Alaska Computing Center --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS 10 ORDER t LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- LCØ1 PS2 50Ø715 ØØ ØØØ ØØ Ø 6 1 1 4 68 ØØØØØØØØØØ SDSI PS2 CU 5ØØ715 Ø0 ØØØ ØØ Ø 6 1 1 4 68 ØØØØØØØØØØ BACK PS2 CPS 5ØØ715 Ø0 ØØØ ØØ Ø 6 1 1 4 68 ØØØØØØØØØØ FBAC PS2 CPS 5ØØ715 0Ø ØøØ ØØ Ø 6 1 1 4 68 ØØØØØØØØØØ TCAN PS2 CPS 5ØØ715 øØ ØØØ ØØ Ø 6 1 1 4 68 ØØØØØØØØØØ TCAF PS2 CPS 5ØØ715 ØØ ØØØ ØØ Ø 6 1 1 4 68 ØØØØØØØØØØ TCND PS2 CPS 5ØØ715 øø ØØØ Øø Ø 6 1 1 4 68 ØØØØØ0ØØØØ TCFD PS2 CPS 5ØØ715 Ø0 ØØø ØØ 0 6 1 1 4 68 ØøØØØØØØ0Ø TSCN PS2 CPS 5ØØ715 øø 000 øø ø 6 1 1 4 68 ØØ0ØØØØ0ØØ TSCF PS2 CPS 5ØØ715 0Ø Ø00 ØØ Ø 6 1 1 4 68 ØØØØ0ØØØ0Ø INND PS2 CPS 5ØØ715 Øø ØØ0 ØØ Ø 6 1 1 4 68 ØØØØØØØØØØ INFO PS2 CPS 5ØØ715 Øø ØØØ ØØ Ø 6 1 1 4 68 ØØØØØØøøøØ TENS PS2 LB 5ØØ715 Øø øØØ Øø Ø 6 1 1 4 68 ØØØØØØøØøØ GR PS2 GAP I 5ØØ715 ØØ ØØØ ØØ Ø 6 1 1 4 68 ØØØØØØØØØØ CCL PS2 V 5ØØ715 ØØ ØØØ ØØ Ø 6 1 1 4 68 ØØØØØØøØøØ --------------------------------------------------------------------------------------- LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-1996 16:16 PAGE: 29 **** FILE HEADER ***. FILE NAME EDIT .007 SERVICE FLIC VERSION 001C01 DATE 96/01/19 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate fi les; raw background pass in last fi Ie PASS NUMBER: 3 DEPTH INCREMENT: 0.5ØØØ # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- TDTP 8143.0 $ 714Ø.Ø # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TO DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE Ø7-JAN-95 CP4Ø.2 100Ø Ø7-JAN-JA 8286.0 714Ø.0 8146.0 18ØØ.0 NO # TOOL NUMBER ---------------- --------- ----------- # TDTP TDTP TDTP TDTP CCL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): TDTP SONDE GENERATOR TDTP SONDE DETECTOR TDTP CARTRIDGE TELEMETRY CARTRIDGE COLLAR LOG TNG-P-236 TND-P-75 TNC-P-141 ATC-CB-1163 CAL-UB-597 7568.Ø # BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BORAX WATER -15.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-1996 16:16 PAGE: 30 # BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DE G): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): # # BLUELINE COUNT RATE SCALES SET BY FIELD FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE lOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): ENGINEER o 12000 o 30000 # REMARKS: TIED INTO CET DATED 7/16/93 **** JOB SEQUENCE **** 1) MADE BASE TDT PASS - NO PUMPING DONE 2) PUMPED 40 BBLS OF BORAX WATER INTO PERFS 3) MADE 1ST BORAX PASS 5) PUMPED 60 MORE BBlS OF BORAX WATER INTO PERFS - BORAX WATER OVER DISPLACED INTO PERFS BY APROX. 10 BBLS SEAWATER ALL FLUIDS APPEAR TO BE GOING INTO THE PERFS. NO CHANNELS, lEAKS OR FLOW AROUND THE LINER lAP WAS FOUND. This is BORAX pass #2. $ # lIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 2 3 4 5 6 7 66 66 73 66 66 73 65 ø ø 92 1 -- DATA -- DEPT. 8150.000 SIGM.PS3 33.Ø72 TPHI. PS3 51.198 SBHF.PS3 65.140 SBHN.PS3 74.179 SIGC.PS3 0.637 SIBH.PS3 155.297 TRAT.PS3 1. 786 LC01.PS3 3.182 SDSI. PS3 0.950 BACK.PS3 151.872 FBAC.PS3 26.800 TCAN.PS3 10741.232 TCAF.PS3 3135.870 TCND.PS3 10685.963 TCFD.PS3 2562.232 TSCN.PS3 1168.899 TSCF.PS3 367.293 INND.PS3 186Ø.140 INFD.PS3 269.513 TENS.PS3 985.0ØØ GR.PS3 74.188 CCL.PS3 ø.øøø LIS Tape Verification Listing 19-JAN-1996 16:16 PAGE: 31 Schlumberger Alaska Computing Center ------------------------------ TYPE REPR CODE VALUE ------------------------------ 8 68 Ø.5 9 65 FT 11 66 11 12 68 13 66 ø 14 65 FT 15 66 68 16 66 1 ø 66 1 ------------------------------ .. SET TYPE - CHAN .. --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER * LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø SIGM PS3 CU 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø TPHI PS3 PU 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø SBHF PS3 CU 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø SBHN PS3 CU 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø SIGC PS3 CU 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø SIBH PS3 CU 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø TRAT PS3 50Ø715 øø øøø øø ø 7 1 1 4 68 øØØØØØØ00Ø LCØ1 PS3 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø SDSI PS3 CU 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø BACK PS3 CPS 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø FBAC PS3 CPS 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø TCAN PS3 CPS 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø TCAF PS3 CPS 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø TCND PS3 CPS 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø TCFD PS3 CPS 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø TSCN PS3 CPS 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø TSCF PS3 CPS 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø INND PS3 CPS 5ØØ715 øø øøø øø ø 7 1 1 4 68 øØØØØØØ0ØØ INFD PS3 CPS 5ØØ715 øø øøø øø ø 7 1 1 4 68 øØØØØØØ0ØØ TENS PS3 LB 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø GR PS3 GAPI 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø CCL PS3 V 5ØØ715 øø øøø øø ø 7 1 1 4 68 øøøøøøøøøø --------------------------------------------------------------------------------------- 62.400 1.707 23.044 3006.192 285.974 32 PAGE: **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/01/19 ORIGIN : FLIC REEL NAME : 95036 CONTINUATION # PREVIOUS REEL COMMENT : ARca ALASKA INC, 1Y-24, KUPARUK RIVER UNIT, 50-029-22371-00 **** TAPE TRAILER ***. SERVICE NAME : EDIT DATE : 96/01/19 ORIGIN : FLIC TAPE NAME : 95036 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, 1Y-24, KUPARUK RIVER UNIT, 50-029-22371-00 46.128 SBHF.PS3 128.382 TRAT.PS3 146.360 FBAC.PS3 12775.258 TCFD.PS3 1790.086 INFD.PS3 0.000 TPHI.PS3 SIBH.PS3 BACK.PS3 TCND.PS3 INND.PS3 CCL.PS3 32.391 1.097 1.120 3700.649 468.072 48.969 19-JAN-1996 16:16 **** FILE TRAILER **.. FILE NAME : EDIT .007 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE ** END OF DATA ** SIGM.PS3 SIGC.PS3 SDSI.PS3 TCAF.PS3 TSCF.PS3 GR.PS3 7120.000 65.763 2.960 12162.711 1355.806 915.000 DEPT. SBHN.PS3 LC01.PS3 TCAN.PS3 TSCN.PS3 TENS.PS3 LIS Tape Verifica~ion Lis~ing Schlumberger Alaska Computing Cen~er ***************'************** * * * ALASKA CQMPUTING CENTER * * * **************************'*** *-....-._._-.~_._--_.-.-_._--* *------- 5CHLUMBERGER -------* *--.--.-.-.---------.-....---* ****************************** COMPANY Nþ,MtD ~~EIJt, NA~iE: FIEIJD NA.f'JE BDROUGH STATE API NUMBER RF^:FERENCE t.D ARca ALASKA, INC. 1 Y-24: KUPA.RlJK RIVER NORTH SIJiJPE ALASKA 50·029....22371,-00 93319 q~ ~ 7:2- _l'0 ~ tí)<t>S ~ REfEIVED OCT 2 5 1993 NasIèa Oil & Gas Cons~ ~ AndD.., MICROfllM~D D:Jte- { 3 ()/ # ëURVF SHIF'T OA'ì'A -- AL,L PASSES TC STANDÞ.RD(ìJ,fASIJRED DF:P'rH) 1ST STRING 2 ì'Jf) 5 T R I "1 G 3RD STRING PRODUCTION STRI~r CASING WEIGHT (LB/FT) -----------.-- 36.00 26.00 DRIIJLrR "5 DEPTH CFT) ---..-.---- 4599.0 7568.0 OPEN HOLE CASI~G BIT SIZE (IN) SIZE (IN) ------------ ---.-.--- 9.625 7.000 # wELT, CASING RFCGRD TAPE: HEADER PRUDHOE BAY UNIT CA5F'D HOl..E vlIRF:f,INE,; IJOGS # ~¡ Ell t. N A M E; ; API NUMBER: CJpgR f\ tliOR : LOC;GING CO~~PANY: TAPE CREATION DATE: \,JOB t,ìUMBER: LOGGING ENGINEER: OPERATOR wITNESS: # SIJRFACE IAJC~TION SF:CTION: TOWNSHIP: HAI"IGE: F' N t" : FSL: fEL: f\'J L : E LEV A T 10 Ì'J ( f T F P. (.J r!ii"î S IJ 0) KELLY BUSHING: ' DERRICK fLOOR: GRDïJ"TD LEVEl,: 176? 107.00 lú7.úO 66.00 1. l1N 9E 570 lY-24 500292237100 ARCOALASKA, INC. SCHLUMBERGFR ~ELL SERVICES 24·AUG-93 93319 FO~MICA ANGLEN . ¡ ARca ALASKA INC., 11-24, KUPARUK, 50-029-22371-00 TAPE HEADER **** NAff¡E : EDIT : 93/08/24 : FLIC : 93319 : 1 **** SEHVICE: DATF ORIGIN TAPE '·,fAME CONTINUATION # pREVIOUS TAPE CONJ,1ENT HEADF~R **** : EI)lT : 93/08/24 : FIJ.IC : 93319 : . ¡ ARca ALASKA INC., lY-24, KUPARUK, 50-029-22371-00 *'*** HEEl" SFRVICE NAME t)A TF ORIGIN RE:'EL N/U\I!E CON'I'INOÞ.T:t:Of'·¡ # pRE;VIOUS REEL C 0 rvn,~ F: N l' 1 PAGE: 24-AUG-1993 14:47 ·IS Tape verification L1stinQ ;chlumberger AlaskaComputin~ Center # LIS FORMAT DATA TPE tJEPTH ADdliSTrFr:TS SHOWn ¡\ROVE REFLE:CT GRCH OF PASS 1. TO 'jht:~ OPEi¡ HOllE DIE/GR. SIGM or PASS 1 \oJAS A{JSO A D\..1{.~ &1 r~D TO THE DPE;'} HOLE [¡Tf/ G R, AND A 1.,1, OT H~~R TDTP C li R V F: S n F PAS S 1 ~': ERE CAR R 1 E [. ~;, r T H T H Å T S H 1fT. $ # R F' r·~ ¡d~) K S : 7571.0 75il.(I 102.0 99.5 $ ··~------.EQUIVALEN1 GRCH SIGr,1 ---.--. -..---- 80887.5 88887.5 8102.0 8102.0 8071.0 8065.5 JIB Tape Verification Listing ;chlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS PBU TOOL CODE: DTE PBU CIH<VE CODE': GH RUN NUMBER: 1 DATE LOGGED: 26-JUN-93 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES 8029.5 80],9.5 7959.0 7951.0 7900.5 7874.5 7853.5 7842.0 7814.5 778S.() 7760.5 7739.0 7732.5 7719.0 7696.0 766f.>.5 UNSHIFTED DEPTH-.-...---.·. 2 24-AUG-1993 14:47 PAGE: 7757.0 7738.5 7739.0 77UR.O 7£)96.5 7679.0 7666.5 7656.5 7b2~.~ 7596.0 88R8R..O 8102.5 8072.0 8066.5 H065.5 8030.5 8020.0 8019.5 7960.5 7959.0 7952.5 7901.0 7900.0 7875.5 7855.0 7B43.0 7842.0 78:1.6.0 7786.0 7761.5 7756.0 7739.0 773R.O 7731.5 7719.0 7718.5 7707.0 7696.0 7678.0 7667.0 766F..O 7655.0 7624.0 7595.0 7571.5 75t-Q.O 100.0 7842.5 7900.5 8019.5 7959.0 8065.5 .-..."""""-.""""""....-...... 8!-\SE;[,INE DEPTH # ------------------.--------~-- 1 66 0 2 66 0 3 73 84 VALUE REPR CODE -------------------------.---- TYPE; ** DATA FORMAT SPfCIF"ICATION RfCORD ** ** SET TYPE - 64EB ** T.~IS FILE CONTAINS THE FIRST PASS OF THE TDTP, AND NO PASS TO PASS SHIFTS wERE APPLIED TO THIS DATA. $ ----------EQUIVALENT UN5HIFTED DEPTH---------- # LIS FORMAT Df-\TA # RFM1\RKS: $ ----....-.........--- PASF.I.1INE [H':;PTH # # CURVE SHIFT DATA p PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PßU CURVE CODE: PASS NUMBER: 51'OP DEPTH --""-..----- 7538.0 7538.0 81,94.0 H185.0 .-----..---- S'l'AR'T Df~PTH 1 and clippeð curves for each pass In separate files. 1 -~5000 FILE HEADER FILF NUMBER: EDITED CURVES repth shifted PASS NU~BER: DEPTH INCREMENT: # FILF SUMMARY PBll TOOL CODE ------------- GRCH TDTP S HEAI)FF**** : f:DIT . O(} 1 : F'LIC : OOlC01 : 93/0B/24 : j024 "' : 110 . '" **** F'IflF: fl[¡F: NAME SER" ICE: VERSION nATF' 'MAX Rf:C SIZE FILE TYPE II,ð S T F' 1 L E ~IS Tape Verification Listing 5chlumberger Alaska Computing Center LIS FORMAT DATA 3 24-AUG-1993 14:47 PAGE: JIS Tape verification Listing ;chlumherger Alaska Computing Center 24~AUG·1993 14;47 PAGE: 4 -~---.--.-.-------.---._---"-- '1'¥PE Ht~PP CODE VAI,,¡UE ---p.-----.----_.-_.-~------~- 4 66 1 5 66 6 73 7 65 8 68 0" S 9 65 F1'~ 1 j 66 1 2 1 2 6B 1 3 66 0 1 4 65 FT 1 5 66 68 1 6 66 1 0 66 0 .--.------------------..-.-.-. ** SET TYPE · CHAN ** -.---------.-.-.---.--.-.----..--..-------.-.---------------------------..--.----..-.-- NAMF' SE:RV U N :r '1" 5EPV 1. Clf; API A.PI A,P,J: AI)1 P'llJE NtlMB NUMB SIZE: RE:PR PROCESS ID ORDER # 1.JOC; TYPE Cl.lASS ~OD Nt.JMB SAMP ElJEM CODE (HEX) -----_.---------.-----------------------.-.---------------------.---------..---------.- OE'PT F'J: 469840 00 000 00 (I 1 1 1 4 68 0000000000 5 J G"\ "81 CU 469í{40 00 000 00 0 1 1 1 4 68 0000000000 SlGC ~:S 1 ell 469840 00 000 00 0 1 t 1 4 68 0000000000 SIBH TSl CU 469840 00 000 00 () 1- 1 1- 4 68 0000000000 5DS! "51 CD 469840 00 000 00 () 1 1 1 4 68 0000000000 S8HN TS1 CII 469840 00 000 00 (I 1 1 1 4 68 0000000000 sBHF' TSl CU 469840 00 000 00 0 1 1 1- 4 68 0000000000 TPHI TS1. pu-s 469840 on 000 00 C 1 1 1 4 68 0000000000 T RA '1' TSl 469840 00 000 no Ü 1 1. 1 4 68 0000000000 TCAN TSl CPS 469840 CO 000 00 Ü 1- 1 1 4 68 0000000000 TCAP T51 CPS 469840 00 000 00 C 1- 1 1 4 68 0000000000 TCNT) TSl CPS 4b9B40 00 000 00 0 1 1 1 4 68 0000000000 TCrD T51 CPS 469840 00 000 00 0 1 1. 1 4 b8 0000000000 TSCN TSt CPS 469840 00 000 00 0 1 1 1 4 68 0000000000 TSCF' '1'S1 CPS 46cHi·10 00 000 00 ( 1 1 l 4 68 0000000000 I Nt,,!D TSl CPS 469840 00 000 00 0 1 j 1 4 68 0000000000 ¡NFf'\ TS1 CPS 469840 00 000 00 C 1 1 1 4 68 0000000000 B~Cf<' '1"S t CPS 469940 00 000 00 () 1 1 1 4 68 0000000000 FPL\(" TSl CPS 469840 00 000 00 C 1 l 1 4 68 0000000000 GRCP IS1 GAPI 469640 00 000 no (J 1 1 1 4 68 0000000000 TE~! S TSl 1..J8 469840 00 COO 00 0 1. 1 1 4 68 0000000000 ------------~~-_.----------------------------------.------------------------~._------_. ** DATA ** DF:P'r" 5051.1'51 TRA"I'.1'S1 TCF'n.ISl INPD.l'Sl T F' !'J S . T S 1 R194.000 -999.250 -999.250 -999.25(; -999.250 -99Q.25ü Slcr'i.TSl SBHtJ.TSl TCAh. 'T'S 1 TSC¡\!.T~l RA C ~~ . T R l "'999.250 -999.250 -999.250 -999.250 -999.250 SIGC.TSl SRHF.TSl TCAF.TSl TSCF.TSl F8AC.TSl -999.250 -999.250 -999.250 -999.250 -999.250 SIBH.TSl TPHI.TSl TCND.TSt INND.TSl GRCH.TS1 -999.250 -999.250 -999.250 -999.250 55.125 ,IS Tape verification Llstio(] ;chlumberqer Alaska Computinci Center DEPT. SDSI.TSl THAT.TSt TCFD.TS1 INFD.1'Sl TENS.TSl DE:PT. SDSI.~r51 TRAT.TSl TC'FD.TSl INFO.TSl Tf:NF;.T51 aooo.ooo 0.421 1.86'7 3371.500 344.41.0 1.686.000 7538.000 0.471 2.393 2629.71.6 272.917 1570.000 SIC; t'1 . T S 1 SBHj'J. TS 1 ~rCAt,J. r:rSl TSCN.T51 BA.Ct<~. TS 1 SIGM.TS1 SBHN.TS1 TCAN.TSl TSCN .~rs l BJ\CK. 1'51 ** END OF DATA ** **** F'ILF.: FY'".!": NAM.E SERVICE VERSION DATE MAX PEC SIZE FILE TYPE L,l\ 5 l' F' I 11 E **** f"Il¡f.: FI LE NlH1~: SEH v I CF.: VERSION DA t.rF MAX HFC SIZE ~""'JLF TYPE L ft S rr F I IJ E TRAIIJER **** : EDIT .001 : fLIC : 00lCOl : 93/08/24 : t024 : JJ('J . ,. HEADER **** : EOIT .002 : F'LIC : 00lCOt : 93/08/24 : 1024 : t,{J : FILE HEADER F'ILF NUMBEQ: EDI'T'ED CURVES nepth shifted PASS NUMBER: DEPTH INCRE~·'!ENT: #: F I {, f: SUM t/( A R Y PBU TOOL CODE 24·AUG~1993 14:47 31.501 70.836 42512.000 1735.6'25 1.10.915 :31.973 69.258 45062.969 1.699.183 1.63.694 SIGC.TSl SBHF.TSl TCAP.TSt T5CF'.TSl FaAC.TSl SIGC.TSl SBHF".TSl TCAr.IS! TSCF.TSl FBA.C .TS 1 0.626 59.874 12301.000 544.813 22.594 0.264 57.486 10448.914 408.738 26.364 2 and clipped curves for each pass in separate files. 2 -.5000 STt\RT OEPTH ......We......___ (;f<CH TDTP S -----.......--- R192.0 8163.0 STOP OF.'P'rH --.-.--.-.. 7544.0 7544.0 SIBH.TS1 TPHI.1St TCND.TS1 INNO.TSl GRCH.T51 SIfSH.TSl TPHI.TSl TCND.TS1 INND.TSl GRCH.TSl PAGE: s 144.606 52.318 14501.000 3666.844 48.500 139.561 81.047 13628.;389 3306.413 33.750 TH~; DEPTH AD"JUST(\iEr,!TS SHown AROVE REFLECT PASS 2 GHCH 7590.5 7561.5 7553.5 100.5 7639.5 8013.5 7979.0 7958.5 7951..0 7909.0 7870.0 7810.5 7799.5 7794.5 7760.0 7738.0 7732.0 7709.5 7675.5 88887.0 8207.5 8185.5 8144.5 8123.5 8102.5 8068.5 -........"'" # RF'r~At~KS : $ 102.0 88888.0 B208.5 8185.0 9145.5 B124.0 8107.0 8t03.0 8102.0 8069.5 8062.0 8034.5 8019.0 8014.0 7Q94.0 7979.5 7960.0 7952.0 7909.5 7899.5 7871..0 7841.5 7811.5 7Rl1..0 7B01.5 77QS.5 7784.0 7761.0 7738.0 773:1.0 7718.5 7709.0 7695.0 7676.0 7665.5 7654.5 7640.0 7624.0 7594.5 7590.5 7566.5 7561.5 755~.O 100.0 7784.5 773R.5 7719.0 7696.0 7666.5 7656.5 7625.5 7596.0 7570.5 7900.5 7842.0 7812.0 8106.5 B1.02.0 8062.0 8034.0 8019.5 7994.0 BR8S7.5 ...........- ....""'..""'..-....""'....-""".."'" --_....----EQUIVALENT U SHIFTED DEPTH""""""-.."""'·_- GRCH TDT? # rAsr:l11 NE Df:PTH # CURVE SHIFT DATA q PASS TO PASS(MEASURED DEPTH) BASE':l.!Ií'1E CUHVE F'OR SHIF~rS PBU CURVE CODE: GRCH PASS NUMBER: 1 6 PAGE: 24-AUG-1993 14:47 JIS Tape Verification ListlnQ ;chlumberger Alaska Computing Center ..-.-----------------------------.-.----.-.---------------------------------.-------.-- NAMF SERV UNIT SEl<VTCE API API API API FILE NUNB NUMB SIZE REPR PROCESS ID ORDEP # r.lOG TYPE CLASS t-10D NU~1H SAMP ELEM CODE (HEX) -.----------------------------------------.-------------------------------------------- DE'P'T' FT 469R40 00 000 00 C 2 1 i 4 68 0000000000 SIGV rrS2 CO 469840 00 000 00 0 2 1 1 4 68 0000000000 SIGr 'rS2 CU 46QR40 00 GOO 00 0 2 j 1 4 68 0000000000 SIBP TS2 CD 469B4Ü 00 000 00 0 2 1. 1 4 68 0000000000 50S1 T52 C11 469840 00 non üo 0 2 1 ], 4 68 0000000000 SBH"; T52 CU 469R40 00 ooe 00 0 2 1 1. 4 68 0000000000 SAHF T52 CO 469(140 00 000 00 0 2 1 1 4 6H 0000000000 TPHT T52 pu-s 4bQH4Ü 00 POD 00 () 2 1 1 4 68 0000000000 TFAT TS? 469!:i40 00 (JOG 00 0 2 1 1 4 68 0000000000 TCA 1\' T S 2 CPS 469840 00 000 00 0 2 1 4 4 68 0000000000 !. Pj'CAF 1'82 CPS 469840 on 000 00 0 2 1 1 4 68 0000000000 TCNÐ TS2 CPS 469840 00 000 00 0 2 1 1 4 68 0000000000 TCPD TS2 CPS 4hQ840 00 000 00 0 2 3 1 4 68 0000000000 TSCr TS2 CP5 4.t)9840 00 000 00 0 2 t 1 4 68 0000000000 TSC'" T52 CPs 469Ü40 on oOü 00 0 2 1 l 4 68 0000000000 INt:D TS2 CPS 469~40 00 000 00 0 2 1 1 4 68 0000000000 INFD TS2 CPS 4b(}S40 00 0(1) 00 () 2 1 1 4 68 0000000000 ** SFT TYPE ~ CHAM ** ~__.._______..N__.._..______._.___ 1 66 0 2 66 0 3 73 84 4: 66 1 5 66 6 73 '7 65 a 68 0,5 ç 65 F'T 1 t 66 12 12 68 1 3 66 0 14 65 F"T 15 66 68 16 66 l () 66 1 -------.---------------.-..-..-- v AldJP; REPH CODE TYPE ._.~._.---..-----_.-..-._.-.-..- ** DATA FORMAT SPECIfICATION RECORD ** ** SET TYPE - 64EB ** TO PASS 1 GRCH, AND PASS 2 SIGM TO PASS 1 SIGMf WITH ALL OTHER TDTP CURVES CARRIED WITH THE SIGM SH,FTS, S FORMAT DATA # LIS 7 PAGEJ 24~AUG-1993 14:47 JIB Tape Verification Listing ;chlumberger Alaska Computing Center 136.452 87.576 13473.326 3206.336 -999.250 146.239 48.222 14745.184 4023.432 67.134 -999.250 -999.250 .999.250 -999.250 108.563 5IBH.TS2 TPHI.TS2 TCND.TS2 INND.TS2 GRCH.TS2 SIBH.TS2 TPHt.TS2 TCND.T52 INND.TS2 GRCH.TS2 SIBH~TS2 TPHI.TS2 TCND.TS2 INND.T52 GRCH.TS2 0.022 58.377 10377.102 405.655 33.987 0.675 63.605 14520.424 571.740 33.741 -999.250 -999.250 -999.250 -999.250 -999.250 SIGC.TS2 SBHF~TS2 'rCAF'.'"rS2 T 5 C f. l' 5 2 fBAC..TS2 51c;C~TS2 5BHf.TS2 TCA,E-". TS2 TSCF.TS2 F'BAC.TS2 SIGC.TS2 5BHF. ~rS2 TCAF.T52 r.I'SCF. TS 2 FBAC. 'rS2 32.485 6B.2d6 45776.234 1746.965 19()~566 31.408 71..347 48194.984 1746.891 197.021 -999.250 ·999.250 -999.250 ·999.250 -999.250 rrRAIl,¡Ek **** : fDIT .002 : FLIC ! 00lCOl : 93/08/24 : 1024- : LO : SIGM.TS2 SBHN.TS2 TCAN.TS2 TSCN.T52 BACK.TS2 SIGM.TS2 SBHN.TS2 TCAN"T52 TSCN.TS2 B}\CK.TS2 SIGM~TS2 SßHN.TS2 TCAN.T52 TSCN.TS2 BACK.TS2 * * * * fI' I 1J E FIt'" NA.ME SF'RVJCE vFRSTn~ DATr;: MAX PEC STZE FILF' TYPE LAST fILE ** END OF DATA ** 8192.000 """999.250 -999,,250 .999.250 -999.250 -999.250 BOOn.OOo 0.425 1.783 3502.197 344.921 1.655.000 7542.500 0.544 2..460 2556.512 269.092 1635.(jOO ** DATA ** DEPT. SDSJ.TS2 TRAT.TS2 TCJc"'D.TS2 INFD.TS2 'IfJJS. T52 [) E: PT.' SD51.TS2 TRAT.T52 TCF'D.TS2 :rNFD.TS2 TENs.rrS2 DEPT. SDSI.'l'S2 TRAT.TS2 TCF'f).TS2 INF'D.TS2 'l'ENS. 'TS2 __"""____~-~~_w_._____.___.______________--------___..-____________________-__..._._._._. NAME SERV UN!T SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB 5AMP ELEM CODE (HEX) ~_~~.~._~___-N._.-~______~-_______..___-_-_-.-___-________.____________.--..._...--____ BACK T52 CPS 469840 00 000 00 0 2 1 1 4 68 0000000000 FBAC TS2 CPS 469840 00 000 00 0 2 1 1 4 68 0000000000 GRCH TS2 GAPI 469840 00 000 00 0 2 1 1 4 68 0000000000 TENS TS2 L8 469840 00 000 00 0 2 1 1 4 68 0000000000 ._____--ø_______._ft__M________~_______--_-_-_-__.-__________._-------_-__._._.....__-__ 8 PAGE: 24-AUG-1993 14:47 ~IS Tape Verification Listing ;chlumberger Alaska Computing Center ---~--~---EQUIVALENT GRCH TDTP ------- ------- 88887.5 88887.0 9123.5 B102,5 8065.5 8019.5 8006.5 7995.0 7979,0 7974.5 7959.0 7951.0 7900.0 7869.5 7810.5 7760.0 UN5HIFTED DEPTH---------- 7Rbl.0 7785,0 a8888.0 8124.5 8103.0 8102.5 R066.5 8065.5 8023.5 8020.0 8007,0 7995.5 798°.0 7976.0 7960.0 7952.5 7919.0 7900.5 7870.5 7859.5 7812.0 77B4.0 7761.0 791g.5 8065.5 8023.5 Bt02.0 ....--.,......---...... BASEl) I N~~ DEPTH # # CURVE SHIFT DATA - PASS TO PASS(MEA5UREP DEPTH) BASElJINE CURVE F'OR SHIFTS PBU CURVE CODE; GRCH PASS NUMBER: 1 7540.0 7540.0 -.-""'..----- s~rop DE:PTH 8182.0 8173.0 GRCH TDTP $ .I!III.!II!III__............ø ""--.-.."""---....-- START DF;P1'H FILE HE;ADE~H FILF: NUMBt:H; EDITE:D CUHVF~S Depth shifted PASS NIHU3ER: DEpTH INCREME:NT: # FILE SUMMAHY p eu TOOL CODt~ 3 and clipped curves for each pass in separate files. 3 -.5000 9 PAGE: 24-AUG-1993 14:47 HEADFR **** : FDIT .003 : FLIC : 001C01 : 93/08/24 : 1024 LO **** FILE FILE NAME SERVICE VERSION DATE MAX REC SIZF FILE TYPE LAST FILE ,IS Tape V~r1flcatlon Listina ;chlumberger Alaska Computing Center ~----------------------------- 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 6C; .:) H 6B 0.5 9 65 FT t 1 66 12 1? 68 1 3 66 0 1.4- 65 F''1 15 66 68 16 66 1 0 66 1 __.~_..__N______._______-_-_W_ ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** _____ø.____________~____-_---_ TYPE REPR CODE VALUE # LIS FORMAT DATA THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT PASS 3 GRCH TO. P~5S1 GRCH,AND PASS 3 SIGM TO PASS 1 SIGMf WITH ALL OTHER TDTP CURVES CARRIED ~rTH THE SIGM SH~FTS. $ 7569.0 7554.0 lQO.O 7735.0 7719.0 7675,,5 7639.5 10 PAGE: 24~AUG-1993 14:47 it f\Et',1ARKS: 101.5 7734.0 7718.5 7718,,0 7677,,5 7676.0 7666.0 7640.0 7624.0 7594.5 7569,,5 7569.0 7554,,0 100,0 $ 7719.0 7678.5 1666.5 7625.5 7596.0 7571.0 JIB Tape verification Listinq ;chlumberger Alaska Co~Þutlnª Center -999.250 SIGC.TS3 -999.250 SIBH.TS3 -999.250 -999.250 SBHF.!rS3 -999.250 TPHI.TS3 -999.250 -999.250 TCAf.TS3 -999.250 TCi\lD. TS3 -999.250 -999.250 1'SCF.TS3 -999.250 INND.T53 -999..250 -999.250 F'BAC.TS3 -999.250 GRCH.TS3 132.375 30.971 STGC.'l'S3 0.770 SIBH.TS3 145.541 71.128 SBHF.TS3 60.284 TPHI.TS3 49.257 42522.375 TCAF.TS3 12535.266 TCND.TS3 12789.008 1536.147 TSCF.TS3 491.007 INND.TS3 2976.946 2C4.413 FBAC.TS3 36.250 GRCH.TS3 90.575 31.810 SIGC.TS3 0.344 SIBH.TS3 141.283 69.7tJ7 SBHF.TS3 59.507 TPHI.TS3 75.119 43595.766 TCAf.TS3 10467.941 TCND.TS3 13341.006 1653.430 TSCf.TS3 419.587 INND.TS3 3247.042 192.457 FBAC.TS3 34.051 GRCH.TS3 83.250 SIGM.rS3 SBHN.T53 TCAN.TS3 TSCN.TS3 BACK.TS) SIG~4. TS3 SBHN.TS.3 TCA¡'.TS3 TSCN.TS3 ßACK.TS3 51GM.TS3 SBHN.T53 TCAN.TS3 TSCN.TS3 ßACK.TS3 ** [NO OF DATA ** 8182.000 -999.250 -999,250 -999.250 -999.250 -999.250 SOOO.OQ0 0.503 1.822 3020.844 297.211 1740.000 1540.0GO 0.491 2.306 2592.301 265.033 1570.000 DE~P1' . 50,51.153 TRAT.TS3 TCFD.TS3 INFD.TS3 TEf\!~.TS3 DFPT. 5DST.1'S1 THAT.TS3 TCfP.TS3 INFO.lrS3 T E \t .t; . T S 3 ** DATA ** DEPT. SDSI.TS3 TRAT.TS3 TCFD.TS3 I t\.J P' D . 't S 3 1'ENS.TS3 ** SET TYPE - CHAN ** ._ft_~___.__._________~____.-_____________-_-_-___________.___..-._._.-____.--.._.___-... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMa SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------..~.._---------------------..---------_.-----------------------.----.------.-..-.- DEPT FT 469840 00 000 00 0 3 1 1 4 68 0000000000 stGM TS] CU 469840 00 000 00 0 3 1 1 4 68 0000000000 SIGC T53 CD 469840 00 000 00 0 3 1 1 4 68 0000000000 SI8H T53 CU 469840 00 000 00 0 3 1 1 4 68 0000000000 5D51 TS3 elJ 469840 00 000 00 0 3 1 1 4 68 0000000000 SBHN TS3 CU 469840 00 000 00 0 3 t 1 4 68 0000000000 SBHF T53 CU 469840 00 000 00 0 3 1 1 4 68 0000000000 ¡PHI T53 PU-S 469840 00 000 00 0 3 1 1 4 68 0000000000 TRAT TS3 469840 00 000 00 0 3 1 1 4 68 0000000000 TCAN T53 CPS 469840 00 000 00 0 3 1 1 4 68 0000000000 TCAF T53 CP5 469840 00 000 00 0 3 1 1 4 68 0000000000 TeND TS3 CPS 469B40 00 000 00 0 3 1 1 4 68 0000000000 TCFD 153 CPS 469840 00 000 00 0 3 1 1 4 68 0000000000 TSCN 153 CPS 469840 00 000 00 0 3 1 1 4 68 0000000000 T5CF TS3 CPS 469840 ()U 000 00 0 3 1 1 4 68 0000000000 INND TS3 CPS 469840 00 000 00 0 3 1 1 4 68 0000000000 INFD T53 CPS 469840 00 000 00 0 3 1 1 4 68 0000000000 BACK TS3 CPS 469840 00 oro 00 0 3 1 1 4 68 0000000000 FBAr TS3 CPS 469B40 00 000 00 0 3 1 1 4 68 0000000000 GRCH TS3 GAP I 469840 00 000 00 0 3 1 1 4 68 0000000000 TENS TS3 LB 469840 00 000 00 0 3 1 1 4 68 0000000000 -.-.-.--..--.----------------------------.-.-.-.----.-------------------------.-.....-.- 11. 24~AUG-1993 14:47 PAGE: JIB Tape Verification Listing Schlumberger Alaska Computing Center arithmetic average 12 PAGE: o o 84 66 66 73 1 2 3 --------~----~--_._----.~~---- VAIJl1t~ REPR ConE TYP~ ---~---------.._--~----~--~-~- ** DATn FORMAT SPECJFICATIO~ RECURD ** ** SET TYPE - 64EB ** THE APITHMETIC AVFRAGE OF PASSES 1, 2 & 3 WAS COMPUTED AFTER ALL DEPTH ADJUSTME~TS ~EkE APPLIED. $ 1, 2, 3, 1, 2, 3, #. l,TS FORMA" OAT A it RErJ¡f-.RI':S: (;RCH 'fDTP S ..------...---... .....--..-...--- F'IfJE J.jE,:A[>F.R FILE NUMBER: 4 AVE:RAGED CURVES Compensated Neutro": Arithmetic average of edited passes for all curves. Pul~ed Neutron: Unaveraged edited Pass 1 Qamma ray and backround counts' of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 # PASSES INCLUDED IN AVERAGE PBU TonL CODE PÄ55 NUM8~RS HEADER **** : EDJ'r' .004 : FLIC : OOtC01 : 93/08/24 : 1024 : 1,1.0 '" 111 TFV\ I 1d.:.:R * * * * : EDIT .003 z FI,¡l'C : OOtCOi, : 93/08/24 : 1024 : 1.10 III . **** FIllE: f'ItIENAME; SERVICE . VERSION DATE MAX REC SIZE FIT-IE: TYPE LAST rlt,F.~ **** FIf.,E rIllE NAfl'1E SERVICE VERSION DA1'E MAX REC SIZE F'tLJE TYPE~ LAST FILE: 24·AUG~1993 14;47 lIS Tape verification Listinq ;ch!umberqer Alaska Computing Center ~lS Tape Verification Listing ;ch¡Umberqer Alaska Computln~ Center 24~AUG~1993 14:47 PAGE: 13 _.~.eø_~~._.______~_____-.-ø.- "YPh: REPf? COnb.: VAI)UE -.---_.-.__..~------.--------. 4 66 1 5 66 6 7 3 7 6 5 B 68 0 . 5 9 65 Fl' 1 :, 66 1 2 1, 2- 68 1 1 66 0 1 4- 65 F'T 1 5 66 6B 1 6 66 1 () 66 1 .-~.--.--..-----_._----------- ** SET TYPE - CHAN ** -w________._.--.________________-_____.-.-.-_-__.__.-_--________---_____-_.--.......... Nt\.J-,I¡E SEPV UNIT SERVICE API API API API FIlJF: NUMB NIH~B SIZE REPR PROCESS II.) DRDF:R # ),.IOG TYP~: CrJAS5 Me]D NUMB SANP ~~ 11 e: M COD~~ (HEX) -----~---------------------------_.----------------------------------.----.--.-.....-.. PE:P'I~ F'~r 4:69840 00 000 on 0 4 j 1 4: 68 0000000000 SIGM 1\ v F: Cll 469840 00 000 00 () 4 1 1 4 68 0000000000 SIGC AVF: CD 469840 00 000 00 0 4 1- 1 4 68 0000000000 Slf3H AV«: eLl 4:6gS40 00 000 00 0 4 1 1 4 68 0000000000 50SJ ~VF: CD 469840 00 000 00 0 4 1 1 4 68 0000000000 sBHN AVE ell 469B40 00 000 00 0 4 j, 1 4 68 0000000000 SBHF AVE: ctJ 469840 00 000 00 0 4 1 1 4 68 0000000000 TPHI AVE; pu-s 469840 00 000 00 0 4 1 1 4 68 0000000000 TRA'T' þ., V f~ 469840 00 000 00 0 4 1 1 4 68 0000000000 TCAN AVE CPS 469840 00 000 00 0 4 1 1 4 68 0000000000 TCAF AVP. CPS 469B40 00 (100 00 0 4 1- 1 4 68 0000000000 TCi-JD AVE CPS 469840 00 OOÜ 00 0 4 1 1 4 68 0000000000 TCFn AVF CPS 4h9~40 00 000 00 0 4 1 1 4 68 0000000000 'l'SCN AVV. CPS 469840 no 000 00 0 4 1 1 4 68 0000000000 TSCf 1\ VE CPS 469840 00 000 00 () 4 1 1 4 68 0000000000 I N t~ 0 AVE CPS 469840 00 f)OO 00 0 4 1 1 4 68 0000000000 INFD AVE CPS 46964(1 OCi 000 00 0 4 1 1 4 68 0000000000 BACK AVE CPS 409840 00 000 00 0 4 ,. 1 4 68 0000000000 FEAC AVP CPS 469ti40 00 000 00 0 4 1 1 4 68 0000000000 GRCH A"F GAPl 469840 00 000 00 Ü 4 1 1 4 68 0000000000 TE r; s AVE LB 469840 no 000 00 0 4 1 1 4 68 0000000000 __-_-________"___..__-8___""___________-.-____________-__.-_________-.-________________ ** DAT,l\ ** DFp'T'. SDSl.AVF: TRAT.AVE TCF'n.AVE INFD.AVE TFrJS . AVE 8194.00G -999.25G -999.250 -999.250 -999.250 -999.250 SIGM.AVE S n J1 ~~ . A V E TCAr" . AVE, T S C í·J . A V t. BACK . AVE: -999.250 "999.250 -999.250 -999.250 -990.2~o SIGC.AVE SBHF'.AVE TCAf.AVE TSCF.AVE FRl\C.AVF -999.250 -999.250 -999.250 -999.250 -999.250 SIBH.AVE TPHI.AVE TCND.AVE INND.AVE GRCH.AVE -999.250 -999.250 -999.250 -999.250 55.125 7535.0 ....-...----- TDTP 8220.0 $ # -----~---------~ ----------- FJ [JE" HEADER FTLP NUMBER 5 RlIw CTlRVP::S Curves and loq header data for each pass in separate pAS S fJ lH~ BE R : - 1 DEPTH INCREMENT: -.5000 n FIL~: SUMf'oIARY - VENDOR TOOL CODF START DEPTH STOP DEPTH files; raw bacKground pass in last £1 -999.250 "999.250 -999.250 -999.250 33.750 145.447 49927 14010:330 3555.385 48.500 14 PAGE: 51BH.AVE TPHI.AVE TCND.,A VE INND.AVE GRCH.AVE SIBH.AVE TPHI.AVE TCND.AVE INND.A.VE GRCH.AVE -999.250 -999.250 -999.250 -999.25Q 26.364 0.690 61.248 13117.586 535.800 22.594 SIGC.AVE SBHF.AVE TCAF.AVE TSCF.AVE FBAC.AVE SIGC.AVE SBHF.AVE TCAF.AVE TSCF.AVE FBAC.AVE ...999.250 ""999.250 -999.250 ..999.250 163.694 31.290 71.097 44405.344 1672.720 110.915 24-AUG-1993 14;47 HEADf~H **** : EDIT .005 : FlJIC : OOlCOl : 93/0R/24 : 1024 : TiD . '" TRAIJ!E:H **** : EDIT .()04 : FL! I C : 001COl : 93/013/24 : 1024 : tAO " '" **** fILE FILE NAME SERVICE VERSION Dl'\TE ~!IÞ·X REC SIZE fILE TYPE.: LAS'" FILE **** F'Il,¡t; FTIJE NAr/iE: SP.:RVICf:: VERSION DATE fvd~X PEC SIZE FItlf~ TYPf: LAST Flr,E~ ** END OF DATA ** SIGÞ;~. AVE SBHN.AVE TCAN..AVE: T5CN.AVE BACK.AVE 7538.000 -999.250 -999..250 -999.250 -999.250 ..999.250 t:! I G '" ~ '\It.> ~? . 1::. f~ ',.!;~ SOH!\:.. A v F. 'rCAN.AVE; frSCN.~VE BACK.AVE 8(J()O.000 0.450 1.824 :3297.B53 32B.814 1693.497 DEPT. SDSI.AVE rrRAT.AVF: TCFD.AVE I NFt!. AVE rrENS. þ, VE DEPT. S{)ST.AVE:, 'fRA.T.A VE TCFD. A VF: INFD.AVE l'ENS./\ VE ,IS Tape Verification Listing ;chlumberqer Alaska Computing Cent@r :15 Tape Verification listing ;chlumberger Alaska Computing Center 24~AUG.1993 14:47 PAGE: 15 LOG HI:<AOER DATA nl\TE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: 't'D Df~IrJt.l£R CfT): TO IJOGGER(FT): TOP LOG INTERVAL (FT): ~OTTaM LOG INTERVAL CFT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ló-¡,.JlHJ""93 CP 32.6 1 rd.! 16.JLJl)-93 8282.0 8261..0 7550.0 8222.0 600.0 NO # 1:'ODLi N lH~BER -.........""..--.. Cl\l.!-¥.1\ 30 TCC-B 290 SGC-SA 261 TNC-PI3 390 TYND·PC 395 ...-----..-.-.....-.. ...-...---. CASING COLLAR LOG TELEMETRY CARTRIDGE Gl\~1MA RAY THERMAL DECAY TOOL THERMAL DECAY TOOL '* TiDrp TDT? TDTP TDTP TOT'P $ BOREHOLE AND CASING DATA OPEN HOLE BIr SIZE (IN): DRILLERS CASING DEPTH CfT): LOGGERS CASING DEPTH (FT): 4599.0 ** BOREHOL~ CONDITIONS F'LUID TYPE.: fLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF); FLUID SALINITY (PPM): FLUID LEVEL CFT): FLUID RATE AT WELLHEAD (BPM): ~ATER CUTS (PCT): GAS/OJLJ RATIO: CHOKE (PEG): BH I N~; 11.70 162.0 # # t\iEI1.THON TfJOIJ TOOl! TYPE (EPT'nifRMAIJ OR THERMAl,): r'1 A T R I X : r-r A T R I X DE t'J SIT Y : HOLF CORRECr 'IUU (IN): F~ L U E rJ I ~j E CO U N T RAT E r'HHH·1 A LIZ A T ION INn I L Z [\ N F TOP NORMALIZING WINDOk (FT): R A S E NOR M A II 1 Z J "J G \,-; I N D () 1;) ( F T ) : NEITHE~R SANDS'fONf: 2.65 # #- F IJ (1 f: L I NEe 0 U ~~ T KAT E5C.~ L F: SSE T BY F 1 F l¡f) f~ N GIN ~ E R FAR COUt!'r Pl\TE LO~~ 5C.ALE (CPS): 0 FA R C C In; T PAT f. ~i I G µ f; c.1.\ L E~ (C P 5 ) : 4 0 NEaR COUNT RATE LOW SCALE (CPS): 0 t-IF,AR courrT H.~TE HIGH SCALE (CPS): 40 TOOL STANDOFF (I~): -----_._----------~--------------------------------~-----.------.------.------.-.--..-- NAME" S fI; R V UNIT S~RV:rCE: API API API API FIl,E NU~1B NUMB SIZE REPR PROCESS ID o H r)l<~R # LOG TYPE CLASS µOD NUMB SAMP ELEM CODE (HEX) -.-.----------------------------------------.--------------------------.--.-.---------- DEPT FT 469840 00 000 00 0 5 '- 1 4 68 0000000000 SIGM PSi ell 469840 00 000 00 0 5 1 1 4 68 0000000000 STorr pst 469840 00 000 00 0 5 1 1 4 68 0000000000 TPHT PSi PIJ 469840 00 000 00 0 5 1 1 4 68 0000000000 ISBU PS1 V 469840 00 000 00 0 5 1 1 4 68 0000000000 SF'F'D PSi CU 469840 00 000 00 0 5 1 1 4 68 0000000000 SFND PS1 CU 469840 00 000 00 0 5 1 1 4 68 0000000000 SBHF' PS1 CU 469840 00 000 00 () 5 1. 1 it 68 0000000000 SRHN PSi CU 469840 00 000 00 (1 5 1 1 4 68 0000000000 F''T'DT pst CPS 46984.0 00 000 00 0 5 1 1 4 68 0000000000 NTDl' PSt CPS '\óQS40 00 000 00 (I 5 l 1 4 68 0000000000 AF'FD PS~ CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 APFf) PSi CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 AFND PSI CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 ABNf) PSl CPS ,~ 6 <;; 8 4 n OÜ 000 00 0 5 1 1 4 6B 0000000000 SIGC PSl CU 469840 00 O"f) 00 0 5 1 1 4 68 0000000000 ** SET TYPE - CHAN ** -------------------------.-.-. 1 66 0 2 66 () 3 73 256 4 66 1 5 66 6 73 7 65 B 68 . 0.5 9 65 FÌ" lt 66 4 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1. --..------.--------------.-.-- ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** --_.------._~----------------- TYPE REPR CODE V A.LUF~ # LIS FORMA.T DATA TIE; D I 1" T (] S iti S D I b D A tr E D :2 6 - J U t¡ E -1 9 9 3 THREE PASSES MADE @ 600 FPH EACH. $ PE~1ARY~S : # 16 PAGE: 24~AUG-1993 14:47 JIS Tace Verification Listlnq ;chlumberger Alaska Computing Center JIS TaDe Verification Listing ;ch!umberger Alaska Computing Center 24-AUG-1993 14:47 PAGE: 17 ~_~_~~___.________.__.__._____ø____._____R__"Ø~_______..._____._____________.......--__ NAME SERV UNiT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORnER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) .___--~----.---________________---.-----------ft-______"____________.---___._.__..-.--.- SIBH PSI CU 4b9840 00 000 00 0 5 1 1 4 68 0000000000 MMOF PSI 469840 00 000 00 0 5 1 1 4 68 0000000000 TRAT pst 469840 00 000 00 0 5 1 1 4 68 0000000000 8DS! PSI CU 469H40 00 000 00 0 5 1 1. 4 68 0000000000 BACK PSi CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 FBAC pst CP5 469840 00 000 00 0 ~ 1 1 4 68 0000000000 TCAN PSi CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 TCAF PSl CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 TCND PSi CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 TCFD PSI çps 469840 00 000 00 0 5 1 1 4 68 0000000000 TSCN psi CPS 46984Q 00 000 00 0 5 1 1 4 68 0000000000 TSCF PS1 CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 INND PSI CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 INFD PSI CPS 469840 06 000 00 0 5 1 1 4 68 0000000000 RNl PSI CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 RN2 PSI CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 RN3 PSi CPS 4b9840 00 000 00 0 5 1 1 4 68 0000000000 RN4 PS1 CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 RN5 PSl çps 469840 00 000 00 0 5 1 1 4 68 0000000000 RN6 PSi CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 RN7 PSl CP5 469840 00 000 00 0 5 1 1 4 68 0000000000 RNB PSI CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 RN9 PS1 CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 RN10 PSi cpa 469840 00 000 00 0 5 1 1 4 68 0000000000 RN11 PSI CP5 469840 00 000 00 0 5 1 1 4 68 0000000000 RN12 PS1 CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 RN13 PSi CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 RN14 PSi çps 469840 00 000 00 0 5 1 1 4 68 0000000000 RN15 PSi CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 RN16 PSi CPS 4b9840 00 000 00 0 5 1 1 4 68 0000000000 RFl PSi çps 469840 00 000 00 0 5 1 1 4 68 0000000000 RF2 PSl CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 RF3 PSI CPS 4b9R40 00 000 00 0 5 1 1 4 68 0000000000 RF4 PSl CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 RF5 PSi CPS 46QB40 00 000 00 0 5 1 1 4 68 0000000000 RF6 Pè1 CPS 469840 on 000 00 0 5 1 1 4 68 0000000000 RF7 PS1 ers 469B40 00 000 00 0 5 1 1 4 68 0000000000 RF8 PSI CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 RF9 PS1 CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 RFIO PS1 CPS 469H40 00 000 00 0 5 1 1 4 68 0000000000 RF11 PSl CPS 4bQ840 00 000 00 0 5 1 1 4 68 0000000000 RF12 PSi CPS 46QS40 00 000 00 0 5 ] 1 4 68 0000000000 RF13 PS1 CPS 469840 00 000 00 n 5 1 1 4 6a 0000000000 RF14 PSi CPS 469840 00 000 00 n 5 1 1 4 68 0000000000 RF1S PSI CPS 469b40 00 000 00 0 5 1 1 4 68 0000000000 RF16 PSi CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 GR PSl GAP I 4h9840 00 000 00 0 5 1 1 4 68 0000000000 TENS PSi LB 46Q840 00 000 00 0 5 1 1 4 68 0000000000 ~_-~-__.M_______~__._~_~~__"__________.-_-_-_-_____~_.-___________-_______-______-.~-__ ,IS Tape Verification ListlnQ ¡chlumberger Alaska Comput1nQ Center ** DATA ** DEPT. ISHf1.F'S1. 5BH~J.PS1 ARF'f'ì. PS 1 SI8H.PS1 BACK.PSt TCND.PSl INND.P51 RN3.PSl RN7.PSl RN11.P51 HN15.PSl RF3.PSl RF7.PSl RF'J.,1.PSl F~F15.PSl DEPT. ISHU.PS1 SBHN.PSl ABFD.PSl SIBB.PSt BACK.PSt TCND.PSI INND.PSl RN3.PSl RN7.PS1 PN11.PSl RN15.PSl RF3.P51 RF7.PSl HF11.PS1 RF15.PS:t. DEP'-. ISHJT.PSl SBHN.PSl ABF"P,. PS 1 SIBH.PS1 BACK. pst TC'ND.Pst INND.PSl PN3.PSl RN7.PSl PNl1.PS1. R "I 1 5 . P S 1 RF3.PSl Rf7.PSl RF11.PSl RF'15.PSl 8220.500 36.875 220.449 2.84J 319.513 1.9.l9(: -238.563 "0.652 3:3.021 0.000 Ü.OOO 0.000 17.361 0.000 0.000 Ü~OO() 8000.000 35.563 70.771 86.434 144.396 110.153 1.4856.680 3580.053 1.114.583 613.095 1590.774 455.357 240.502 182.292 468.750 1.31.,,740 7535.000 38.6?5 73.515 68.485 153.171 165.782 13227.432 3441.472 ll62.2Rl 619.517 1.504.934 6()4.44.1. 215.186 132.950 345.395 111.020 SIGl\¡l.PSl SFFD.PSl FT[)T. PS 1 AF~Nf). PS " MMOF.PSl f'8AC.PSl TCF'D.PSl INFD.PSl HN4.PSl RN8.PSl RN12.P51 RN16.PSl RF4.PSl RF8.PSl RF'12.PSl RF16.PSl S!GM.PSl SFFD.PSl F'TDT.PSI AF'N!) " PS 1 MMOF.P51 FBAC.PSl TCr"'D. PS 1 INFD.PSt HN4.PS1 Rf'J8.PSl RNt2.PSl RN16.PSl HF'4.PSl RF8.PSl RF12.PSl Rf'16.PSl S r G ;'1\ . P S j 5f"f"V. PS 1 FTDT.PSl AFND"PSl M~40F'.PSl FHAC.PSl TCF'D.PSl INFD.PSl RN4.PSl RN8.P5l RN12.PSl RN16.PSl RF'4.PSl RFB.P51 HF12.PSl RF'16.PSl 24-AUG-1993 14:47 40.647 41..716 O.OtJO 118.146 -0.047 lB.645 -221.072 ~O.634 13.021- 0.000 0.000 0.000 13.021 0.000 0.000 0.000 30.384 31.056 3.9BB 389.925 0.929 22.392 3471.356 349.136 1,400.297 876.488 1415.17B 413.690 310.968 271.140 41.2.071 Bl..1H9 32.197 32.458 2.B67 )46.630 0.903 25.62B 2653.961 280.971 137B.838 B55.263 130H.936 63B.7U6 2b5.899 237.1.16 316.612 90.461 5'fDT.. PS 1 SFNP.P51 NTDT.PSl ABND.PSl THAT.PSt TCAJ! .PSl TSCN.PSl RN1"PSl RN5.PSl RN9.PSl RN13.PSl RF1.PSl RF5.PSl RF9.PS1. Rf13.PSl GR.P51 STD'I'.. PS 1 SFND.PSl ~'TDT .PSi ABND.PSl THAT.PSl TCAN.PSl TSCN.PSl RN1.PSl RN5..PSl RN9.PSl RN13.PSl RF'l.PSl RF5.PS1 RF9.PSl RF'13.PSl GR.PSl SToT.PSl SFNt).PS1. NTDT.PSl ABNO.PSl TRAT.PSl TCArI.PSl TSC:,¡. PSi RN1.PSl RN5.PSl RN9.PSl RN13.PSl RF1.PSl RF'5.PSl Rf9.PSl RF13.PSl GR.PSl 2.000 43.246 0.000 3.',70 0.000 0.000 0.000 26.042 13.021 0.000 0.000 17..361 4.340 0.000 0.000 53.969 66.000 33.322 13.749 424.014 1.905 44928.758 1875.287 918.155 1244.047 1372.024 1102.678 304.841 33,0.968 384.497 399.816 48.500 66.000 35.183 1,1.228 404.Q07 2.082 39774.336 1450.500 955.318 1255.482 1428.180 1054.002 264.529 241.228 298.194 257.675 3Q.938 TPHI.P51 SBHF.PSl AFrD.pst SIGC.PSl St)SI. pst TCAF.PSt TSCF.PSl RN2.P51 RN6.PSl RN10.P51 RN14.PSl RF2.PSl RF6.PSt RF10.PSl RF14.PSl TENS.PSt TPHI.PSl SBHF.PSl AFFD.PSt SIGC.PSl SOSI.PS1 TCAF.PSt TSCF.PSl RN2.pst. RN6.PS1 RN10.PSl RN14.PSl Rr2.PSl RF6.PS1 RF10.PS1 RF14.PSl TENS.PSl TPHI.PS1 SBHF.PS1 AFrD.PS1 SIGC.PS1 SDSI.P51 TCAF.PSl TSCF.PSl RN2.P51 RN6.P51 RN10.P51 RN14.PSl RF2.PSl RF6.PSl RF10.PSl RF14.PSl TENS.PS1 PAGE: 18 (} 000 107:874 69.134 0.000 4.828 0.000 0.000 13.021 0.000 0.000 0,000 13.021 0.000 0.000 0.000 1530.000 52.089 59.250 67.761. 0.606 0.399 13008.891 583,684 91.473 1101.190 1272,,321 738.095 20124 292:586 349.265 240.502 1745.000 64..554 64.126 52.018 0.606 0.590 10238.994 401..422 152..220 1107.456 1228.070 753.838 21.109 217.928 272.752 189.145 1615.000 TOOL NUr.1BER ---------~._--~- --------- -..-----..--- TOOL STf:¿ING (TOP Tn BOTTOM) VENDOR TOOL CDGE TOOL TYPE # 16-JUL-93 CP 32.6 1749 16-JUL-93 8282.0 8261..0 7550.0 8222.0 600.0 NO # LOC; HF:ADf~R DATl\ DATE LOGGED: SOfTWARE VERSION: TIME LOGGER O~ bOtTOM; TD DRILLER CFT,: TD LnGGER(FT): TOP LOG INTERVAL CFT): ROTTOM LnG INTtRVAL CFT): LOGGING SP~ED (FPHR): r¡'::PTH rO:~TROL USEe) (Yr:S/f\O): STOP DEPTH .--------- 7542.0 8219.0 ___w___________. "D'rp $ rIllE: Hr~ADER Fl1JE NUMBER RA~i CUH"ES Curves and loq header data for each pass in separate pASS NHHBF.~R: 2 DEPTH INCREMENT: -.5000 # FILF SUM¡·~AHY VENDOR TOUL CODE START DEPTH ------..---- tiles; raw backqround pass 1n last f1 6 fiEADJï.:H **** EDIT .006 rT.,IIC : 001.C01 : 93/08/24 : 1024 : l¡O . .. !tRAII,ER **** ; EDIT .005 : F'LIC : 001COl : 93/08/24 : 1024 I.tO **** f"IIJE FIllE NiU1E SERVICE vERSION D Þ 'I' F tl\J\ X REC SIZE FIIJE: TYPE LAST F:II¡E **** FILE F'I14F NAME gFHVICE V E R S 1. 0 ¡,¡ pATE :~ftAX REC SIZF: FILE TYPE: l¡ftST FIllE ** END OF DATA ** 19 PAGE: 24-AUG-1993 14:47 JIS Tape Verification List1nQ )cMlumberger Alaska Computing Center 1* LJ S FORt"¡À" nATA TIED INTU SWS DIL DATED 26-JUN~-1993 THRE~ PASSES MADE 0 600 FPH EACH. S RE~AhKS: TOOL STANDOFF (IN): fHillEL! ',IE COON T RA '1"ENOR~1 AIJ I ZA T ION IN OIL ZONE: TOP NORMALIZING WINDOW CFT): RASE NORMALIZING WINDOW CFT): ALUF:TJ! N F: COUNT RATE SCALES SET BY FIELD ENG I NEER ¡'''AR COUNT PA.TE: I.. (H·~ SCAL~: (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 40 NfU\R COUNT RA'I'E I,DW SCALE (CPS): 0 \'.rr':AR COUNT RATE HIGH SCArt~~ (CPS): 40 NEITHì~R SANDSTONE 2.65 TDTP TDTP 'pnTP TDTP TDTP $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH eFT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE:: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGf): BOTTOM HOLE TEMPERATURE (UEGF): fLUID SALINITY (PPM): F L II I D L E: v E 1, (r T) : FLUID RATE AT WELLHEAD CBPM): WATER CUTS (PCT): GAS/CJtL RATIO; CHOKE: (PEG): NEl.fTRON TQOlJ TOOL TYPE (EPITHERMAL OR THERMAL): fv\ATRIX: r1ATRIX DENSJ1'Y; HOLE CORRECTION (IN); BHINE 11,,70 162.0 4599.0 CAIJ...YA 30 TCC-B 290 SGC-.S.A 261 'l'tNC-PB 390 TYND"PC 395 CASING COLLAR LOG TELEMETRY CARTRIDGE GAMMA RAY tHERMAL DECAY TOOL THEPMAL DECAY TOOL # # '* # ;t # # 20 PAGE: 24~AUG-1993 14:47 ,IS Tape verification ListinQ ichlumberaer Alaska Computinó Center __._~._._n_"__~___.__..______________________-________________________-.-.______--_._.- NAME S~RV UNIT SERVICF API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SÄMP ELEM CODE (HEX) ----------------------------------------------.-----------.--.-----------------.------- DEPT FT 469840 00 000 00 0 6 1 1 4 68 0000000000 SIGM PS2 CU 469640 00 000 00 0 6 1 1 4 68 0000000000 STpT PS2 469840 00 000 00 0 6 1 1 4 68 0000000000 TPHI PS2 PU 469840 00 000 00 0 6 1 1 4 68 0000000000 ISHU PS2 V 469840 on 000 00 0 6 1 1 4 68 0000000000 SFFD PS2 CU 4b9R40 00 000 00 0 6 1 1 4 68 0000000000 SFND PS2 CU 469840 00 000 00 0 6 1 1 4 6B 0000000000 SRH~ PS2 CU 469840 no 000 00 n 6 1 1 4 68 0000000000 SPHN PS2 CO 469840 ou 000 00 0 6 j 1 4 6B 0000000000 fTOT PS2 CPS 46QS40 00 000 00 0 6 1 1 4 68 0000000000 NTDT PS2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 AFF~ PS2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 ABFD PS2 CP5 4h9840 00 000 00 0 6 1 1 4 68 0000000000 AF~r PS2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 A8ND PS2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 S!GC' PS? CU 469840 00 onu 00 0 6 1 1 4 68 0000000000 SIBH PS2 CD 4h9840 Ou 000 00 0 6 1 1 4 68 0000000000 M~OF P52 469840 00 000 00 0 6 1 1 4 68 0000000000 TRAT PS2 469840 00 000 OU Û 6 1 1 4 68 0000000000 50ST PS2 CU 46Q840 no 000 00 0 6 1 1 4 68 0000000000 BACK PS2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 FBAr PS2 CPS 469840 00 000 on 0 6 1 1 4 68 0000000000 TCA~ P52 CPS 4b9840 00 UOQ 00 0 6 1 1 4 68 0000000000 tCAV PS2 CPS 469b40 00 000 00 0 6 1 1 4 68 0000000000 TCNn PS2 çPS 469840 00 000 00 0 6 1 1 4 68 0000000000 TCrD P52 CPS 469R40 00 GOO 00 0 6 1 1 4 68 0000000000 ** SET TYPE - CHAN ** .---_.._~._--------------.._-- 1 66 0 2 66 0 3 73 256 11 66 1, 5 66 6 73 7 65 8 68 0.5 9 65 F1' 11 66 4 12 68 13 66 () 1,4 65 F'J' 15 66 68 16 66 1 0 66 1 -------------------------.---- VALJIJE REPP CDDE TYPE -------------------------.-.-. ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** 21, P AGia 24-AUC-1993 14:47 JIS Tape verification ListinG ;chlumberger Alaska Computinq Center 64.554 64.126 52.018 0.606 0.590 10238.994 401.422 110.280 TPHI.P52 SBHF.P52 AFFD.PS2 SIGC.P52 SDSI.PS2 TCAF.PS2 TSCF.PS2 RN2.P52 32.197 32.458 2.867 346.630 0.903 25.628 2653.<1Bt 2RO.971 SIGM.PS2 SFFD.PS2 FTDT.PS2 AFND.PS2. M (1 0 F . P S 2 FP>AC.PS2 TCF'D.PS2 IÌ\~Ff).PS2 821Q.000 35.563 73.515 68.4P5 153.171 lh5.782 13227.432 3441..472 66.000 35.183 11.22B 404.907 2.082 39774.336 1450.500 9(J9.091 STDT.PS2 SFf~D.PS2 NTDT.PS2 ABrJ[). PS2 TRAT.PS2 TCAN.PS2 TSCtJ.PS2 kNl.PS2 ** IJATA ** fJEPT. TSHlI.PS2 SBHN.PS2 ABFD.PS2 SrBH.PS2 P.Þ·CK . PS2 TCND.PS2 I ~H;,n. PS? -.-----------------------.--------------.--------------------------------------------.- __-__~_-----_---_---_-_______e____-____---_.--___-______--________._____________._.---_ NÞf~F SERV UNIT SERVICF: API API API API FILE: NUMB NUMB SIZE: REPR PROCESS TO OHDfCR # LOG TYPE CLASS MOD NUMB SANP ELEM CODE (HEX) __.__--_"~__ø___~_________________Ø___---------__-----_____-.-____-______._....-....-.. TSCN PS2 CPS 4698í~O 00 000 Of) 0 6 t 1 4 68 0000000000 TSCF PS2 Cpr:¡ 469840 00 000 00 () 6 1 1 4 68 0000000000 INr,ID PS2 CPS 46984() on 000 ()O () 6 ;I{ 1 4 68 0000000000 J, INFD PS2 CPS 469B40 00 ()OO 00 0 6 1 1 4 68 0000000000 RNl PS2 CPS 469B40 00 000 Oü 0 6 1 1- 4 68 0000000000 RN2 PS2 CPS 469840 00 000 no 0 6 1 1 4 68 0000000000 RN :~ P52 CPS 469840 00 OOQ 00 0 6 1- 1 4 68 0000000000 RN4 PS2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 FeNS PS? CPS 469840 00 000 00 0 6 1 1. 4 68 0000000000 RN6 PS2 CPS 4:69840 00 000 00 () 6 1 1 4; 68 0000000000 RN7 PS2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 RNB PS2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 RN9 PS2 CPS 4:69840 00 000 00 0 6 1, 1 4 68 0000000000 RJ' t n P S '2 CPS 469B40 00 000 00 () 6 1 1. 4 68 0000000000 RN11 PS2 cPS 46984:0 00 aoo 00 0 6 j 1 4 68 0000000000 ... Rf'J 1 2 PS2 CPS 4b9B40 00 000 00 () 6 1 1 4 68 0000000000 H~¡1,3 PS2 CPS 469840 00 000 00 0 6 1 1- 4 68 0000000000 RN14 PS2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 RNt5 P52 cPS 469840 QO 000 00 0 6 l 1 4 68 0000000000 Rf'>¡ 16 PS2 CPS 469840 00 000 00 0 6 1 l 4 68 0000000000 RFl P52 CPS 469840 00 000 no 0 6 1 1 '* 68 0000000000 RF2 PS2 CPS 469840 00 000 Oû 0 6 1- 1 <4 68 0000000000 RF'3 PS2 CPS 469840 00 000 00 t) 6 1 1 4 68 0000000000 RF4 PS2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 RF5 P52 CPS 4ó9B4(} 00 000 00 0 6 1 1 4 68 0000000000 RF6 PS2 CPS 469840 no ()()(J 00 0 6 1 1 4 68 0000000000 RF7 PS2 CP5 4-69840 00 000 00 () 6 1 1 4 68 0000000000 RF8 PS2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 RF9 PS2 CP5 469840 00 ooü 00 0 6 1 1 4 68 0000000000 RF10 PS2 CPS 469840 00 O()O 00 0 6 1 1 4 68 0000000000 f<Fl1. PS2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 pF 1. '2 P52 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 RF13 PS2 CPS '~69840 00 000 00 0 6 1 1 4 68 0000000000 RF14 PS2 CPS 4bQ840 00 000 00 0 6 1 1 4 68 0000000000 RF'15 PS2 CPS 469840 00 OOv 00 0 6 1 1 4 68 0000000000 RF'16 PS2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 GR PS? GAPI 469840 00 000 00 0 6 1 1 4 68 0000000000 TF.'r~5 PS2 [,B 469840 00 000 on () 6 1 1 4 68 0000000000 22 PAGE: 24-AÜG.1993 14:47 JIS Tape Verification Listing ;chlu~berqer Alaska Computing Center 1174.242 128.,3.144 686.553 46.440 250.947 331.439 137.311 1685.000 46.172 61.385 70.501 0.684 0,407 15394:426 617.452 190.920 1151.175 1248,.664 801.282 29.670 288.461 372.596 284.455 1765.000 87.576 58.377 53.58g 0.022 0.544 10377.102 405.655 171687 1100:603 1234.923 884.046 32 250 232:372 265.759 180.288 1635.000 23 PAGE: RN6 P52 RN10I>S2 RN14 PS2 RF2.PS2 Rlt6. P52 RF~lO.PS2 RF14.P52 TENS.PS2 TPHI.PS2 SBHF.PS2 AFFD.PS2 SIGC.PS2 SDSI.PS2 TCAF.P52 TSCF.PS2 RN2.PS2 RN6.PS2 RN10.P52 RN14.PS2 RF2.PS2 RF6.PS2 RF10.P52 RF14.PS2 TENS.PS2 TPHI.PS2 5BHf'. P52 AFFD.PS2 SIGC.PS2 SDSI.PS2 TCAF.PS2 TSCF.PS2 RN2.PS2 RN6.PS2 RN10.PS2 RN14.PS2 RF'2.PS2 RF6.PS2 RF10.PS2 RF14.PS2 TENS.P52 1297.34:8 1444.129 866.477 288.826 288.826 378.788 20.3.598 124.688 66.000 34.153 13.743 429.552 1.759 50022.547 1,828.9j1 941.506 1245.993 1379.541 1.139.156 295.139 297.810 3$1.944 375.267 68.000 66.000 32.586 12.525 379..114 2.480 45776.234 1746.965 93B.871 1202.028 1362.390 1138.980 248.397 237.714 293.803 277.778 62.656 RN5.PS2 RN9.PS2 RNt3.PS2 RF1.PS2 HF5.PS2 HF9.PS2 RF13.PS2 GR.PS2 S'rD! 'II PS2 SFND.PS2 NTDT.PS2 ABN[). PS2 TRAT.PS2 TCAN.PS2 TSCN~PS2 RN1..PS2 RN5.P52 RN9.PS2 RN1.3.PS2 RJi'l.PS2 RF5.PS2 Rr9.PS2 RF13.PS2 GR.P52 STDT.P52 SFND.PS2 NTD'l'. PS2 A8ND.PS2 TRAT.PS2 TCAN.PS2 TSCN.PS2 RN1.PS2 RN5.PS2 HN9.PS2 RN13.PS2 RF1.PS2 RF5.PS2 RF9.PS2 FH'13.PS2 GR.PS2 1377.941 871..212 1197.917 643.939 274.621 255.682 288.826 1,27.641 30.834 31.074 4.221 410.655 0.911 32.5b7 3575.407 341.238 1398.237 877.404 1,363.515 734.508 320.513 271.100 424.679 128.205 32.485 32.643 2.914 3:35.234- 0.892 33.987 2556.512 269.092 1293.860 856.634 1280.153 727.796 228.365 235.043 317.842 121.528 24-AwG-1993 14:47 RN4.PS2 RN8.P52 RN12.PS2 RN1.6.PS2 kF'4.PS2 RF8.PS2 Rf12.PS2 RF"1,6.PS2 SlG1vt.PS2 SFFD.PS2 F'TI)T. PS 2 AFND.PS2 Ml·;JOF. PS2 FBAC.PS2 TCF'O.. PS 2 INFD.P52 HN4.PS2 RN8.PS2 RN12.PS2 RNt6.PS2 RF4.P52 fH...·S.PS2 RFl2.PS2 RF16.PS2 SIGM.PS2 Sf'FD.PS2 FTDT.PS2 l\FNO.PS2 MMOF.PS2 FBAC.PS2 rrCFD.PS2 INFD.PS2 RN4.PS2 RN8.PS2 RN12.PS2 PN16.PS2 RF4.PS2 RFB.PS2 RFt2.PS2 RF16.PS2 ** END OF DATA ** 8000.000 36.00{j 71.395 85.981- 146,,394 196.2Br) 1,5001.947 4034.179 1161.859 681.09() 1553.152 710.470 259.0B1 198.985 460.737 154.91.5 75421!'OOO 35.156 68.286 63.633 136.452 1-90.566 13473.326 3206.336 1018.366 6R8.04B 1513.158 101.754 lR2.959 145.566 331.1.97 132.21.2 1065.341 653.409 1576.704 544..508 232.008 132.576 340.9Ü9 118.371 DFPT. 15tH}. P52 SBHr: . PS2 ABF'D.PS2 SIBB.PS2 BACK.PS2 TC'ND.PS2 INND.PS2 PN3.PS2 RN'1.PS2 FH·Jll.PS2 RN15.PS2 RF3.PS? RF7.PS2 HF11.PS2 RF15.PS2 DE:P1' . 1StH'. PS2 SBHN.PS2 ARF'fi.PS2 SIBH.PS2 BACK.PS2 TCND.PS2 INND.PS2 PN3.PS2 PN7.PS2 RN11.PS2 RN15.PS2 RF3.PS2 RF7.PS2 RF11.PS2 RF1S.PS2 RN3.PS2 HN7.PS2 RNl1.PS2 RN15.PS2 PF'3.PS2 Rf'7.PS2 RF1~..PS2 RF15.PS2 JIS Tape Ver1flcatio~ Listing ;chlumberger Alaska Computing Center CAL-YA 30 TCC-R 290 SGC-SA 261- 1'NC-PB 390 TYND-PC 395 CASING COLLAR LOG TELEMETRY CARTPIUG[ GAi'4MA RAY THERMALt DECAY TOCT, THfRrAf\L DECAY TOCt, ----------- ---.....---. ------~--------- # LOG HEADKR nATA nATE LOGGED: SOfTwARE VERSIO~: TIME LOGGER ON BOTTOM: or D D .;¡ ILL F. R ( F tr ) : TD l.lOGGER{F'T): 'TOP flOG INTERVAL eF'T): AOTTOM LOG INT~RVAL CFT); LOGGIN~ SPEED (FPHR): npPTH CClNTROlJ IJSFD (YES/NtJ): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL COD~ TOOL TYPf TOOIJ iHH<1BER 16-JUL-93 CP 32.6 1859 16-JUL-93 82B2.0 8261.0 7550.0 8222.0 600.0 NO TDTP TDTP tDTP rnTP TOTP s # 7538.0 TDTP 8221.0 S __e~__________~_ ____M~__~__ ....-""'....----- FILE HEADER FILF NUMBER 7 RAW CURVES Curves and loq header data for each pass In separate PASS NUMBER: 3 DEPTH INCREMENT: ft.5000 # þTLE SUMMARY VENDOR TOOL COD~ START DEPTH STOr DEPTH fl1es~ raw backaround pass In last £1 HEADER **** : EDIT ,007 : FL!C : OOICOI : 93/08/24 : 1024 LO TRAILISR **** : EDI'f ,006 : FJ.JIC : 001C01. : 93/08/24 : 1024 : lJO : **** FILE FILF NAME ~FRVICE VERSION DATE MAX REC SIZE FtLF TYPE LAST FILE **** FILE F' I 1.1 F N JUH.: gKRV ICE VE:RSION nATE' ~1AX PEC SIZI~ FIIAf TYPE: IJAsrr FIL,r~ 24 24-AUG-1993 14:47 JIS Tape Verification Listing ¡chlumberg~r Alaska Computlna Center PAGE:: ¡IS Tape Verification Listing ¡ch!umberqer Alaska Computing Center 24·AUG-J993 14:47 PAGE: 25 # # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRTLLERS CASING DEPTH CFT): LOGGERS CASING DEPTH CFT): BOREHOLE CONDITIONS F·l.,U,ID TYPE: FLUID DENSITY (LB/G); SURFACE TEMPERATURE (DEGf): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PP~): FLUID LEVEL CFT): FLUID RATE AT WELLHEAD CBPM): WATER CUTS (PCT): GAS/OIL RA'l':lO: CHOKE (DEG): BHINg 11.70 162.0 4599.0 # # Nf:lJTRON TO()L TOOL TYPE (EPITHERMAL OR THERMAL): ¡,,~ A 'r R I X : fJtAI'RIX DF~NSITY: HOLF CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW CFT): BASE NORMALIZING WINDOw (FT): BLUET,orNE: COUNT RATE SCALES SET BY F'IELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RAT~: .HIGH SCAt)£!: (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): () 40 o 40 NEITHgR SANDSTONE 2.65 # # # TOOL STANDOFF (IN): TIED INTO SWS DIL DATED 26~JUNE-1993 THREE PASSES MADE @ 600 rPH EACH. $ PET"LARKS: # L T S F fJ R f'1 þ, 'r D A T A ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64E8 ** --------------_._--~-----_._-- TYPt; PEPR CO OF.: VALUf~ .__._________M__________-.-.-. 1 2 3 4 66 66 73 66 o o 2~6 1. -.-.----.-------.-..------.-.-.------.--.-.-.-.-.-.-.---------.-.--.-.-.--.---.-...-.-. N,AMF Sf'RV tJN!T S.Ef~V'ICE ,A.PI API .API API FILE NIJMB !'HI M B SIZE REPR PROCESS ID ORDE,:R # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ---.----------------.----.-------.--.-.---.------------------------..--.--.........--.. Df.I~PT F'T 469840 00 000 00 0 7 1 t 4 68 0000000000 sJGM PS3 CU 469í340 00 000 00 () 7 1 1- 4 68 0000000000 STDT PS3 4691340 00 000 on 0 7 1 1 4 68 0000000000 1'PHT PS3 PU 46<':H140 00 000 on (; 7 1 1. 4 68 0000000000 lSHV PS3 v 469840 00 000 00 0 7 1 1 4 68 0000000000 SFF'O PS 3 CO 469840 00 000 00 0 7 1 1 4 68 0000000000 SF"ND PS3 elf 469B40 00 000 00 0 7 1 1 4 68 0000000000 SBHF PS.3 CIJ 469840 00 000 00 0 7 1 1 4 68 0000000000 SBRN PS3 CU 469840 00 000 00 0 7 1 1 4 68 0000000000 F'TDT PS3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 NTDT PS3 CPS 469B40 00 000 00 0 7 1 1 4 68 0000000000 AFrn PS3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 ARF'D PS3 CPS 469B40 00 000 00 0 7 1 1 4 68 0000000000 AF"ND PS3 CP5 469H40 no 000 00 0 7 1 1 4 68 0000000000 ABNO PS3 CPS 469B40 00 000 00 fì 7 1 1 4 68 0000000000 STGC PS3 CU 469840 00 OOu 00 0 .., 1 1 4 68 0000000000 STBH PS3 en 469840 00 000 00 0 .., 1, 1 4 68 0000000000 MMOF PS'3 469840 on 000 00 0 7 1 1 4 68 0000000000 THAT PS3 469840 00 000 00 0 7 1 1 4 68 0000000000 SDSJ PS3 eLl 469840 00 000 00 0 7 , 1 4 68 0000000000 8ÞCJ( PS3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 fBAC PS3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 TeA 1\1 p S 3 CPS 46Q840 00 000 00 0 7 1 1 4 68 OOOOOOOOOQ TC'A.F P53 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 'TCND PS3 CPS '1 b 9 8 4 0 00 000 00 0 7 1 1 4 68 0000000000 TCf'f" PS3 CPS 469&40 00 000 00 0 7 1 1 4 68 0000000000 T S C 1\1 P S 3 CPS 469d40 00 000 00 0 7 1 1 4 68 0000000000 TSCF PS3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 I~PH) PS3 CPS 469R40 00 00(; 00 () 7 1 1 4 68 0000000000 IMFD PS3 CPS 4&9840 00 000 00 n 7 1 1 4 68 0000000000 R~: 1 PS3 CPS 469b40 00 000 00 !) 7 1 1 4 68 0000000000 RN2 PS3 CPS 469840 00 000 00 () 7 1 1 4 68 0000000000 RN3 PSl CPS 46C}840 00 000 00 0 7 1 1- 4 68 0000000000 *' SET TYPE - CHAN ** .-.-------.------....--.-.-.-- o F'T 68 1 1. 66 73 65 68 E>? 60 68 66 65 66 66 66 5 6 7 B 9 11 12 13 l4 15 16 o 0.5 F'T 4 -----.--...----.--.-.----.-.-. VÞ,LUF; REPR CODE TYPE .----.---.---.-.--.-.----.-.-- 26 PAGE; f 24-AUG-1993 14:47 lIS Tape Vprification Listinq Ichlumberger Alaska Computing Center ** DATA. ** DFPT. 8221.500 SIGN.PS3 32.485 STDT"PS3 66.000 TPHI.PS3 87.576 ISHU.PS3 35.156 SFFD.PS3 32.643 SFND.~S3 32.586 SBHF.PS3 58.377 SBHN.PS3 68.286 FTDT.PS3 2.914 NTDT.?S3 12.525 AFFD.PS3 53.589 ABFD.PS3 63.633 AFND.PS3 335.234 AB:ND.PS3 379.314 SIGC.PS3 0.022 SI8!4.PS3 136.452 t>HI¡OF. PS 3 0.892 TRA1'.PS3 2.480 5D5I.PS3 0.544 BACJ<.P53 190.566 FBAC.PS3 33.967 TCAN.PS3 45776.234 TCAF.PS3 10377.102 T("ND.PS3 13473.326 TCFD.PS3 2556.512 TSCIi.PS3 1746.965 TSCF.PS3 405.655 I~;r.dD.PS3 3206.336 INFD.PS3 269.092 RN1.PS3 938.871 RN2.PS3 171.687 Pf':!3.PS3 1018.366 RN4.PS3 1.293.960 RN5.PS3 1202.028 RN6.P53 1100.603 RI\7.PS3 6B8.048 RN8.PS3 856.634 RN9.PS3 3,362.390 RN10.PS3 1234.923 R~11.PS3 15t3..l5R RI'.ì12.PS3 1280.153 R!'J1.3.PS3 1138.980 RN14.P53 884.046 RN15.PS3 701.754 RN16.PS3 727.796 RF1.PS3 248.397 RF2.PS3 32.250 PF3.PS:3 182.Y59 RF4.PS3 22R.365 RF5.PS3 237.714 Rf6.PS3 232.372 PF'7.PS3 145.566 RrB.PS3 235.043 RF'9.PS3 293.803 RF10.PS3 265.759 RF11.PS3 331.197 RF12.PS3 317.842 RF13.PS3 277.778 RF14.PS3 180.288 --------------------------------------------------------------------------.-......----- -------~----~-~----------.-----------------------------------.-----------...........--- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ______~______-___________~___._---___----ø-----_---_-.~_._.--_______--______.___....-.. RN4 PS3 CP5 469840 00 000 00 0 7 1 1 4 68 0000000000 RN5 PS3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RN6 PS3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RN7 PS) CP5 469840 00 000 00 0 7 1 1 4 68 0000000000 RNB PS) CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RN9 PS] CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RN10 P53 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RN11 P53 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RN12 PS3 CPS 469640 00 000 00 0 7 1 1 4 68 0000000000 RN13 PS3 CP5 469840 00 000 00 0 7 1 1 4 68 0000000000 RN14 PS3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RN15 PS3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RN16 PS3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 Rfl P53 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RF2 PS) CPS 4.69840 00 000 00 0 7 1 1 4 68 0000000000 RF3 PS3 çPS 469840 00 000 00 0 7 1. 1 4 68 0000000000 RF4 PS3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RF5 PS3 CPS 469840 00 000 00 0 7 1 1 4 68 0000008000 RF6 PS3 CPS 469840 00 000 00 0 7 1 1 4 68 000000000 RF7 PS3 CP5 469840 00 000 00 0 7 1 1 4 68 0000000000 RFB PS3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RF9 PS3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RF10 PS3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RF11 PS3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RF12 PS] CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RF13 PS3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RF14 PS3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RF1~ PS3 CPS 469B40 00 000 00 0 7 1 1 4 68 0000000000 RF16 PS3 CP5 469840 00 000 00 0 7 1 1 4 68 0000000000 GR PS3 GAPT 469840 00 000 00 0 7 1 1 4 68 0000000000 TENS PS3 LB 469840 00 000 00 0 7 1 1 4 68 0000000000 27 PAGE: 24·AUG~1993 14:47 JIB Tape Verification Listinq ;chlumberqer Alaska Computing Center 1635,000 48.045 56.908 61.954 0.770 0.482 13048.451 515.287 198 660 1060:363 1155.181 785.·256 30,960 276.442 319.177 248.397 1750,QOO 78.741 60.210 52.653 0.323 0,532 10413.715 411,.192 188.340 1131.143 1274.038 869.391 30.960 235.746 283.717 211.075 1590.000 28 PAGE: TENS.P53 TPHI.PS3 SBHF.PS3 AFFD.P53 SIGC.PS3 SDSI.<PS3 TCAf.PS3 Tscr.PS3 RN2.P53 RN6.P53 RN10.PS3 R~114..PS3 RF2.PSJ Rf'6.PS3 RF10.PSJ RF14.P83 TENS.P53 TPHI.PS3 SBHF.PS3 AFFP.PS3 5IGC.PSJ SDSI.PS3 TCAF.PS3 TSCF.PS3 RN2.PS3 RN6.PS3 RN10.PS3 RN14.PSJ RF2.PS3 RF6.P53 RF10.PS3 RF14.PS3 TENS.PS3 62.656 66.000 34.177 11.983 372.445 1.814 43765.570 1593.626 929.487 1147.169 1245.993 l065.705 27ó.442 269.765 344.551 344.:551 90.688 66.000 33.882 12.325 381.214 2.332 44264.313 1653.319 929.487 1197.917 1370.192 1187.233 252.193 245.340 286.458 264.529 81.563 STDT.PS3 SfND.PS3 NTDT.PS3 ABND.PS3 TRA1'. P 53 TCAN.PS3 TSCN.PS3 IHJl.PS3 RN5.PS3 RN9.P53 RN13.PS3 RF1.PS3 RF5.PS3 HF9.PS3 RF13.P53 GH.PS:~ 5TDT.PS3 5F'ND.PS3 NTDT.PS3 ABND.P53 TRA'r.PS3 '1'CAN.PS3 TSCN .I?S3 RNt.PS3 RN5.P53 RN9.P83 RN13.PS3 RF'1.PS3 RF'5.PS3 Pf9.P53 Rf'13.PS3 GH.PS3 GH.PS3 121..528 30.4b9 31.490 3.570 359.252 0.883 35.781 3071.120 293.209 1244.658 822.650 1.255.342 717.147 2f;:10.449 243.056 391.293 140.224 32.403 32.399 2.931 355.547 O.8B4 33.453 2608.182 26B.024 1315.438 840.011 1388.8B9 753.205 252.193 223.410 ,313.871, 124.726 24-AUG-1993 14:47 TRAILE:R **** : EDIT .007 : F'LIC : 00lCOl : Q3/08/24 : lG24 : J.JO . . S!G;'c~.PS3 S~'FD. PS3 F'.rDT. PS3 AfND.PS3 MMOF.PS3 F8AC.PS3 TCFD.PS3 INFD.PS3 RN4..PS3 RN8.PS3 R¡"a2.PS3 RNl6.PS3 RF'4.PS3 RF"8..PS3 Rf12.PS3 Rf'16.P53 SIc;!~1.PS3 SfF'f).. PS 3 PTDT.PS3 AFND.PS3 M~,10f It PS 3 F'BAC.PS3 TCf'D.P53 INF'D.PS3 RN4.PS3 RN8.PS3 RN12.P53 RNl6.PS3 RF'4.PS3 RF8.PS3 RF12.PS3 RF16.PS3 RF16.PS3 **** FILE FILE I'JAFf: SERV ICE: VFH~Inn DATE ¡{¡AX RF.'C f;TZE FILF' TYPE: LÞ.ST fT.¡A~~ ** END OF "ATA ** l32.212 8000.000 41.2t9 71.122 74.222 145.521 205.609 12994.186 2917.964 l014.957 670.406 14(}O.9QB 670.406 219.01.7 176.282 4:05.983 162.927 75:~8.000 40.781 69.239 65.391 139.49ß 193.197 13413.342 3233.871 1.022.970 703.793 1587.874 730.502 1.91..B86 150.76(5 335.80(j 146.656 RF15.P53 OEPT. ISHl1.PS3 SBHN.PS3 APIi'D.?S3 SIBH.PS.3 BACK.PS3 TCMD.PS3 INNO.PS3 RN3.PS3 f'N7.PS3 RNll.PS3 RN15.PS3 Rf3.PS3 RF7.P53 RF11..PS:3 RF'15.PS3 DF:PT. ISHU.PS3 SP·H~i. PS) ABF'D. PS3 SI8H.PS3 BACK.PS3 TC'f\JD.PS3 INND.PS3 RN3.PS'3 RN7.PS3 Rt~ll1.PS3 RN15.PS3 RF3.PS3 RF'7.PS3 RF11,.PS3 RF15.P53 lIS Tape Verification Listing :chlumberger AlasKa Computing Center R E E IJ T R A I lj E: R * * * * NAt'1E : E:DI'T : 93/08/24 : F 1,1 I C : 933..19 .. . .. ¡ ARCa ALASKA INC., 11-24~ KUPARUK, 50-029-22371-00 T E .A I Ii E R * * * * EDl'r 93/0B/24 FLIC 93319 1 ARCU ALASKA INC., 1Y-24, KUPARUK, 50-029-22371-00 **** SERVICE DATE ORIGIN REEL NAME CONTINUATION # PREVIOUS REEL COMMENT **** TAP~ SERVICE N~~~ DATF ORIGIN TAPE NAME CONTINUATION # PPEVIOUS TAPE COMMENT 29 24~AUG-1993 14:47 JIB Tape Verification Listinq ;chlumberqer Alaska Computln~ Center PAGE: MICROFILMED Date _ I '.~ / I)j : ARca ALASKA, INC. : 1Y-24 : KUPARUK RIVER : NORTH SLOPE : ALASKA : 50-029-22371-00 : 93318 COMPANY NAME: WEt./l! NAME FIELD NAME BOROUGH STA'l'E API "'lUMBER REFERENCF. NO ~f; 4. C<y¡ ~ ci'",~. ,~6' I Y!'p 4/ ;> " of ~ l.9.9cJ ~Cfi 'ò~ ~'O^ ~ /'t ·cr9ð \oo~ . ~~ .~" ****************************** * * * ALASKA COMPUTING CENTER * * * ****************************** *-..-....-.....-..-........--* *------- SCHLUMBERGER .-.-..-* *-------.-.-.----------.-..--* *****************************~ o ?;1~tl~r (¡\A ft71L\~ 36.00 26.00 -----..-------- CASING WEIGHT (LB/FT) # CURVE SHIFT DATA .. ALL PASSES TO STANDARD(MEÄSURED DEPTH) 4599.0 7568.0 ---------.. DRIIJLER"S DEPTH (FT) 1ST STRING 2ND STRING 3pn STRING PRODUCTI0N STRING OPEN HOLE CASI~G 8IT SIZE (IN) SIZE (IN) --.--------- -----.-...- 9.625 7.000 # W~Lr CASING RECORO 1762 107.00 107.00 66.00 'tAPE HE:Ar>ER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS # WELl, NAME: J\PI NUMBER: Ol'ERATOP: LOGGING COMPANY: 7'APE CREATION DATE: JOB NtJMBER: LOGGING ENGINEER: OPEØATOR WITNESS: # SURFACE LOCATION SECTION: T 0 \~ N 5 HIP: FANGE: FNL,: FSIJ: F E:I, : FWL: ELEVATION{FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROtJND LEVEL: 1 l1N 9E 570 lY-24 500292237100 ARea ALASKA, SCHLUMBERGER 4...,ð,UG-93 93318 JEFF FORMICA TOMMY ANGLEN INC W~:Lt SERVICES HEADER **** : gD!'l' : 93/08/ 6 : FIJIC : 9331.8 : t · ¡ ARca ALASKA, INC.,KUPARUk RIVER,lY-24,50.029-22371-00 HEADER **** : EDIT : 9:3/08/ 6 : FLIC : 9331.8 , · · ; )\RCCJ ALASKA, INC.,KUP1~RUI( RIVER,lY-24,50-029-22371-00 1. PAGE: **** TAPE S££HVICE NAM~ DA1'F ORIGIN TAPr' I\¡AME~ CONTINUATION # pREVIOtJS TAPE COMMENT **** REEL SF.:RVICE NAj1tiE DATE OPIGIN RFEtt NAME CONTINUA1'IOPlI # pREVIOUS REE!,; COMMENT 6-AUG-1993 14:47 IS Tape Verification Listing ,chlumberger Alaska Computing Center HEADER **** : ED!.T .001 : FLIC : 00lC01 : 03/08/ 6 : 1024 : LO : **** FILF FILE NAME SERVICF VF"RSJON DATF ~4 AX REC S IZF: F J' L E r¡' Y P E ld~ S 'T' F I L E # LTS FORMAT DATA LIS FORMAT nATA THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT GRCH OF PASS 1 Tn. THE O.PE.N H.OLF.. DTE. GR~. A. LL OTHER CURVES WERE CARRIED WITH THE OPEN HOLE SHIFT. S # ¡:H:f~ARKS : 8R888.5 8110.0 8106.5 8102.0 B065.5 8063.5 13029.5 8025.0 8019.5 7975.0 7900.5 7861.0 7804.0 7785.0 7719.0 7705.5 7675.0 7666.5 7656.5 7649.0 7641.5 7625.5 7551..5 '01.0 s ~B88B.O 8109.5 B107.0 8102.0 8066.0 8063.5 8029~S 8023.5 8019.0 7975.0 '7900.0 7860.0 7802.0 7784.0 771.9.0 7704.5 7674.5 7666.5 7655.0 7648.5 7640.0 7624.5 7550.5 100.0 .........-..... ..-.""".............--- ·_---·_·--ECUIVALENT UNSHIFTED DEPTH.............. GRCH AASEt.,INE DEPTH # 2 PAGE: JIB T8~e Verification Listing 6~AUG-1993 14:47 ;chlumberger Alaska Computin~ Center RASELINE CURVE F0R SHIFTS PBU TOOL CQDE: PTE PBU CURVE CODE: GR RUN NUMBER: 1 DATE LOGGED: 26~JUN~93 LOGGING COMPANY: SCHLtJMBERGER WELL SERVICES \ o o 76 1 66 66 73 66 66 73 65 68 65 66 68 66 65 66 66 66 1 2 3 4 5 6 7 8 9 1.1 12 13 14 15 16 n ~t5 13 o FT 68 1 o ------.------._-------------~- *~ DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ---~-_.----------------------- TYPE REPR CODE VALUE # LTS FORMAT DATA THIS FILE CONTAINS THE FIRST PASS OF THE CNTG & HLDT. NO PASS TO PASS SHIFTS wERE APPLIED TO THIS DATA. S # REMAHK5: $ -...---.-......-- BASF:IJJNE DEPTH ----""'..----EQUIVALENT UN5HIFTED DEPTH-------""'-- # DEp!rH) CNTG HLDT S # tURVE SHIFT DATA""" PASS TO PASS(MEASURED BASELINE CURVE FOR SHIFTS PBU CURVE CODE: PASS NUMBER: START Dt~PTH .-....--.--- 8196.0 8220.0 ""'--""".....---.---- S~!'OP OEPTl'J ""'''''''''''...-''''- 7550.0 7550.0 F'TlJF HEADEH FIl.IE NUMBER: E;DrrrED CURVES Depth shifted pASS NUMI:3ER: DEPTH INCREMENT: # FILE SUt~MARY VENDOR TOOL CODE and clipped curves for each pass In separate files. 1 -.5000 1 3 PAGE: 6.-.AUG-1993 14:4"1 JIS Tape Verification Listing ¡chlumberger Alaska Computing Center ** DATA ** DFPT. 8220.000 ENPH.CNTG -999.250 ENRA.CNTG ..999.250 CFEC.CNTG "999.250 CNF2C. CNTG -999.250 NPHl.CNTG -999.250 NRAT.CNTG -999.250 CRAT.CNTG -999.250 NCNT.CNTG -999.250 rCNT. CI\ITG -999.250 CNTC.CNTG -999.250 CF'TC.CNTG "999.250 GRCH.CNTG -999.250 CAr" 1 . eN T G -999.250 TENS.CNTG -999.250 CCL.CNTG ·999.250 PEF . HsrHJ 29.938 RHOB.HSDN 2.326 DRHO.HSDN -0.426 DEPT. 8200.000 ENPH.CN'rG -999.250 ENRA.CNTG -999.250 CFEC.CNTG -999.250 CNEC.CNTG -999.250 NPHI.CNTG -999.250 NRA'r .CN'rG -999.250 CRAT.CNTG -999.250 r,: C t'J T . C N T G -999.250 FCNT.CNTG -999.250 CNTC.CNTG -999.250 CFTC.CNTG -999,250 G~CH.CNTG -9'?9.250 CAL1.CNTG -999.250 TENS.CNTG -999.250 CCL.CNTG .999.250 PEJ:'.HSDP 40.000 RHOB. .JSDN 2.1.06 DRHO.HSDN -0.530 DEPT. 8100.000 ENPH.CNTG 26.476 ENRA.CNTG 4.288 CFEC.CNTG 858.719 CNEC.CNTG 3681.844 NPHI.CNTG 28.624 NRAT.CNTG 2.939 CRAT.CNTG 2.973 NC'NT.CNTG 1840.242 FCNT.CNTG 540.688 CNTC.CNTG 1767.230 CFTC.CNTG 600.133 CRCH.CNTG 65.938 C A [. 1 . eN T G 4.484 TENS.CNTG 2673.063 CCL.CNTG -0.041 PE"".HSDN 32.523 RHOB.H5DN 2.285 DRHO. HSDN ..0.483 OFPT. 8000.000 E~) PH. CNTG 23.944 ENRA.CNTG 4.007 CFEC.CNTG 963.406 CNFC.CNTG 3860.094 NPHI.CNTG 25.726 NRAT.CNTG 2.882 CRAT.CNTG 2.814 t·' C NT. C NT G 1987.500 F" C ~ T . C ,~ T G 676.188 CNTC.CNTG 1900.219 CFTC.CNTG 696.750 GRCH.CNTG 66.465 CAL1.CN'fG 4.508 Tf.:NS. CNTG 2666.938 CCL.CNTG 0.001 P F F . H S lHl 40.000 RHOB.HSDN 2.324 DRHO. HSDt\f ..0.584 ** SET TYPE .. CHAN ** ...--...--.......----..-...........-..-...........-...-............-.....................-......-............................. NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ItEM CODE (HEX) ._-----~.".....---_.-_........_-_.--_._.---.---_....__.....................-...........-.. DEPT FT 469840 00 000 00 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 469840 00 000 00 0 1 1 1 4 68 0000000000 ENR~ CNTG 469840 00 000 00 0 1 1 1 4 68 0000000000 crEC CNTG CP5 469840 00 000 00 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 469840 00 000 00 0 1 1 1 4 68 0000000000 NPHI CNTG Pu-s 469840 00 000 00 0 1 1 1 4 68 0000000000 NRAT CNTG 469840 00 000 00 0 1 1 1 4 68 0000000000 CRAT CNTG . 469840 00 000 00 0 1 1 1 4 68 0000000000 WCNT CNTG CPS 469840 00 000 00 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 469840 00 000 00 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 469840 00 000 00 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 469840 00 000 00 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 469840 00 000 00 0 1 1 1 4 68 0000000000 CAL1 CNTG IN 469840 00 000 00 0 1 1 1 4 68 0000000000 TENS CNTG LB 469840 00 000 00 0 1 1 1 4 68 0000000000 eCL CNTG V 469840 00 000 00 0 1 1 1 4 68 0000000000 PEr HSDN . 469840 00 000 00 0 1 1 1 4 68 0000000000 RHOB HSDN G/C] 469840 00 000 00 0 1 1 1 4 68 0000000000 DRMO HSDN G/C3 469840 00 000 00 0 1 1 1 4 68 0000000000 -.-.-.---------..........-.-----.-....--.---..-.-.-.--------..------...--.-.---..-.....--- .------.-.----..---------.-.-. 4 PAGE: 6"AUG-l.993 14:47 ~IS Tape verification Listing )chluæberger Alaska Co~puting Center IS Tape Verification Listing chlumberqer Alaska Cornputinq Center DEPT. CNEC.CNTG NCMT.CNTG GHCH.CNTG f'EF"HSDN DF'PT" CNr~C.. CNTG NCNT"CNTG GRCH.CNTG P~:F'" HSDN DEPT. CNJ~~C" CN'rG NCNT"CNTG Gf~CH. CN1'G 'PEF.HSDN DF:PT.. CNEC.CNTG NCNT.CNTG GRCH.CNTG PEF.HSDN DEPT. CNEC.CNTG NCNT.CNTG GRCH.CNTG Pf~F .HSDN 790().OOO 4008.500 2164.625 43.13.3 39.930 7800.000 3580.250 1643.281 41.942 39.9R7 7700.()OO 2886.348 1224.058 76.742 35.402 7600.000 3004.376 1.262.432 71.875 40.000 7550.000 3l69.725 1057.570 59.375 40.000 ** END OF DATA ** **** FTtl~~ FllJf' NAME Sf.i:RVICE VF'R~ION DATE MAX RFC SIZE F T (J E T Y P E LAST rIllE **** FILE f' T L E r~ AM E SER"ICE: VERSION D~TF M,AX REC SIZE FTLF TYPE LAST FILE ENPH.CNTG NPHI.CNTG FCNT.CN'fG CAL1.CN~l'G RHOB.HSDN ENPH.CNTG ~tPHI . Cf\P.CG rCNT . CNrrG C ,~1,1 . CN'I'G RHOB.HSDN ~:NPH.CN'rG NPHI.CNTG FCNT.CNTG C A IJ 1. eN T G RHOB.HSDN ENPH.CNTG NPHI.CNTG f'CNT. CNTG CAL1.CNTG HHOB.HSDN ENÞH.CNTG NPHl.CN'I'G FCNT.CNTG CA tJ 1 "CNTG RHOB.H5DN TRAILEP **** : EDIT .001 : FLIC : 001C01 : Q)/08/ 6 : 1024 : LO : HEADER **** : EDIT .002 : F"LIC : 001C01. : Q3/0S/ 6 : 1024 : LO : 6-AUG-1993 14:47 PAGE: 5 22 · B92 ENRA. CNTG ),.888 CFEC.CNTG 1031.063 30 " 911 NHAT.CNTG 3.187 CRAT.CNTG 3.098 746. 531 CNTC.CNTG 2242.563 CFTC.CNTG 782.344 4.500 TF~NS" CNTG 2570.250 CCL.CNTG -.0.029 2 · 199 DRHO.HSDN .0.579 32 .277 ENRA.CNTG 4.892 CFEC.CNTG 731.953 36.169 NRAT.CNTG 3.552 CRAT.CNTG 3.387 469.690 CNTC.CNTG 1680.273 CF'TC.CNTG 503.'438 4.449 TENS.CN'rc; 2583.188 CCL.CNTG -0,01,4 2.164 DRHO.HSDN -0,591 4'1 · 930 ENRA.CNTG 5.787 CFEC.CNTG 498.742 45 · 591 NR.AT. CNTG 3.945 CRAT.CNTG 3.904 288 · 547 CNTC.CNTG 1211,.484 CFTC.CNTG 314.340 4 · 500 TE:N 5. CNTG 2497,.375 CCL.CNTG -0.030 2. 105 DRHO.HSDN -0.518 42 .057 ENR,A ,CNTG 5.798 CFEC.CNTG 518.133 50.867 NRAT.CNTG 4,563 CRAT.CNTG 4193 293.784 CNTC.CNTG 1220.043 crTc.CNTG 292:172 4.461 TENS .CNTG 2290,000 CCL.CNTG 0.007 2 · 060 DRHO.HSDN -0,571 50. 734 €NRA.CNTG 6. 504 CFEC.CNTG 487.326 60 542 NRAT.CNTG 5.132 CRAT.CNTG 4724 220: 1 31 CNTC.CNTG 1047.942 CFTC.CNTG 235:277 4 · 320 TENS.CNTG 2405,000 CCL.CNTG 0,013 2 · 365 DRHO. HSDN -0,794 7975.5 7959.0 7968.5 7954,0 7944.5 7984.0 8046.5 8019.0 8012.5 8007.0 7994.0 7987.0 R009,O 8000.0 7996,0 8026,0 8062.0 8055.0 8063,5 8135.5 B118.5 8107.0 8102,5 8065,5 81.03.5 8112.0 8149,5 8121.0 DEPTH....·..·..-..·· ·..._------EQUIVALENT UNSHIFTED GRCH CNTG HLDT ----..- ......- ...-...- 88888.5 a8888,5 88888.0 8206 0 8190:0 8154.5 8182.5 BASELINE; DEPTH -..........-...-..- 888B8.0 8206.0 8189.5 8182.0 8154,5 8149.0 8134,5 8120,'5 811.8,5 8111,0 8106.0 8102,5 8102,0 0065,0 8062,5 8061..5 8054,0 8045,5 R025,5 P018.5 8011.5 9008.5 8006,5 7999.0 7993.5 7986,0 7983,0 1Q74,O 7968.0 795'3,5 7953,0 7Q43.5 # # # CURVE SHIFT DATA... PASS TO PASSCMEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH p~SS NUMBER: 1 srrop DEPTH ",-,..",-.-.- 1550.0 7550,0 81,96.0 8220.0 ........---... 51'ART DE:PTH and clipped curves for each Dass in separate files. 2 -.5000 ._-~...-----.-.._- CNTG HLDT $ :2 FILE Hf3:ADER F :r L E~ N U r·H~ E R : EDI11ED CURVES De"th shifted PASS NlHH3~~'R = DEPTH INCREMENT: # FTLE SUMÞ-IARY VENDOR TOOL CODE 6 PAGE: 6....AUG-1993 1.4:47 ¡IS Tape Verification Listing ;chlumberger Alaska Computing Center THE DEPTH ADJUS1'HENTS SHOWN ABOVE REFLECT PASS 2 GRCH TO PASS 1 GRCH, PASS 2 NPHI TO PASS 1 NPHI AND PASS 2 RHOR TO PASS 1 PHDB. ALL OTHER CURVES WERE CARRIED WITH THEIR RESPECTIVE SHIFTS. $ 101.0 7617.5 7585.5 7579.5 7561.5 7675,0 7705.5 779B.5 7748.0 7739.0 7733.0 7906,5 78bO.5 7834,5 7 6... \UG-1,993 14:47 PAGE: 7571.0 7551.5 101,0 7586,0 7625,5 7696,5 7720.0 7739.Ct 7827.5 7816.5 7909,0 7940,0 7550.5 100.5 7584.0 7696.0 7666.0 7624,5 7732.5 7721.5 7719.0 7707,0 7104,5 7767.5 79(H),O 7860.0 7933.0 7928.5 791.3.0 # LTS FORMAT nATA # REMARKS: s 7940,0 "1932,5 7926,5 7911,5 7908.5 7905.5 7899,5 7859,5 7859,0 78)-4-,0 7826,5 7816,0 7797,5 7767,0 7747.5 7738,0 7732,5 7731,5 772t,5 7719,5 7718,0 7706,5 7705,0 7704,5 7695.5 7695,0 7674.5 7665.5 7625.0 7624.0 7616.5 7585.5 7saS,O 7583.5 7579,5 7571.5 7560,5 7550.5 7550.0 100.0 ;15 Tape Verification Listing 5chlumberger Alaska Computinó Center ~IS Tape Verification Listinq 3chlumberger Alaska'Computin~ Center 6·AtJG-1993 14:47 PAGE: 9 ** OAT A FORMAT SPECIFICATION RECORD ** ** SET TYPE .. 64EB ** ..---..---.--...-.----------.-- TYPE REPR CODE VALUE ------------.------.-.-.-.-..-- 1 66 0 2 66 0 :3 73 76 4 66 1 5 66 6 73 "1 65 8 68 0;;5 9 65 F ; 1 1 66 13 12 68 1. 3 66 0 14· 65 F1' 1.5 66 68 16 66 1 0 66 1 -..----------...---.---..----.-- ** SET TYPE - CHAN ** ----------------------.---------------------.------...--.------.-.-.-..----.----..-.---. NAME SERV UNIT SERVICE AÞI API API API FILIE NUMB NUMB SIZE REPR PROCESS In ORDER *' LOG TYPE CLASS MOD NUMB SAMP ELE~1 CODE (HEX) -.----------------.---.--------.-----..-----.-..------...--.-----.-~-_._---.._--------- DF'PT FT 469840 00 000 00 0 2 1 1 4. 69 0000000000 ENPH CNTG PlJ-S 469840 00 000 00 0 2 1 1 4 68 0000000000 ENRA CNTG 469840 00 000 00 0 2 1 1 4 68 0000000000 CFEC C1\!TG CPS 469840 00 000 00 0 2 1 1 4 68 0000000000 C!\"EC CNTG CPS 469840 00 000 0<> 0 '} 1 1 4 68 0000000000 NPH! CNTG PU"S 469840 00 000 00 0 2 1 1 4 68 0000000000 NRAT CNTG 469840 00 000 00 0 2 1 1 4 68 0000000000 CRA'T CNJ'G 469840 00 000 00 0 2 t 1 4 68 0000000000 N (" N "f' CNTG CPS 469840 00 000 00 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 469840 00 000 00 0 2 t 1 4 68 0000000000 CNTC C'N'T'G CPS 469840 00 000 00 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 469840 00 000 00 0 2 1 1 4 68 0000000000 GRCµ ChJrG GAPI 469840 00 000 00 0 2 1 1 4 68 0000000000 Cð,L1 C' r; T G 1"'1 469840 00 000 00 0 2 1 1 4 68 0000000000 TF"NS (:I'.ITG LB 469840 00 000 00 0 2 1 1 4 b8 0000000000 cCt. CNTG v 469840 00 000 00 0 2 1 1 4 68 0000000000 PEr HSDN 469840 on 000 00 0 2 1 '- 4 68 0000000000 RHOB HSDN G/C3 469840 00 000 ('0 0 2 1 1 4 68 0000000000 DPHO HSDt~ G/C3 469840 00 000 00 0 2 1 1 4 68 0000000000 ------------------------------------------.---.----------------------.----------------- ** DATL\ ** 6..1\UG-1993 14:47 PAGE: 9 -999.250 ~~NRA .CNTG ·999.250 CFEC.CNTG -999.250 -999.250 NRAT,CNTG -999.250 CRAtf.C!\1TG -999.250 -999.2S() CNTC.CNTG -999.250 CFTC.CNTG -999.250 ..999.250 TENS.CNTG .999.250 eCLA. CNTG -999.250 2.238 DRHO.HSDN -0.458 "999.250 ENRA. CN'rG -999.250 CFr:C. CNTG -999.250 -999.250 NRAT.CNTG -999.250 CRAT.CNTG -999. ,250 -999.250 CNTC. C~JTG -999.250 CFTC.CNTG -§99.250 -999.250 TENS.CNTG -999.250 CCL.CNTG - .99.,250 2.1-00 DRHO.HSDN -0.523 26.54Q ENRA..CNTG 4.295 ~FEC,CNTG 863.688 30.279 NRAT.CNTG 3.199 ·RAT.CNTG 3.064 561.031 CNTC·~ CNTG 1775.211 CF.'1.~C. CNTG 588.688 4.492 TENS.CNTG 2749.500 eeL. Cr~TG -0.060 2.242 DRHO.HSON -0.509 25.591 ENRA.CNTG 4,191 CFEC.CNTG 924.719 28.455 NRAT.CNTG 3.008 CRAT.CNTG 2.964 634.703 CNTC.CNTG 1914.766 CFTC.CNTG 666.813 4.494 TENS.CNTG 2713.188 CCl,. CNTG "0.018 2.337 DRHO.HSDN -0.542 24.ROO ENRA.CNTG 4.103 CFEC.CNTG 101~.109 22.372 NRAT.CNTG 2.894 CRAT.CNTG .630 746.906 CNTC.CNTG 2074.938 CFTC.CNTG 798.922 4.488 TENS.CNTG 2644.750 CCL.CNTG 0.010 2.226 DRHO,HSDN -0.507 31.445 ENRA.CNTG 4.807 CFEC.CNTG 753.438 34.603 NR.AT.CNTG 3.418 CRAT.CNTG 3.301 476.906 Cl\ITC. CNTG 1643.445 CFTC.CNTG 511,.828 4.449 TENS.CWrG 2597.063 CCL.CNTG 0.018 2.167 D'RHO.HSDN -0.562 43.105 ENRA.CNTG 5.888 CFEC.CNTG 493.564 44.269 NRAT.CNTG 3.968 CRAT.CNTG 3.831 307.375 CNTC.CNTG 1235.781 CFTC.CNTG 327.188 4.500 TF:NS.CNTG 2550.500 CCL.CNTG -0.025 2.111 ORHO.HSDN -0.521 48.751 ENRA.CNTG 6.350 CFEC.CNTG 481.302 49.630 NRAT.CNTG 4.966 CRAT.CNTG 4.125 285.593 CNTC.CNTG 1154.739 CFTC.CNTG 290.236 4.430 TENS.CNTG 2330.000 CCL.CNTG -0,012 2.089 DRHO.HSDN -0.560 47.138 ENRA.CNTG 6.222 CFEC.CNTG 508.349 61.497 NRAT.CNTG 5.408 CRAT.CNTG 4.776 228.308 CNTC.CNTG 1086,456 CFTC.CNTG 235.153 4.320 TENS.CNTG 2260.000 CCL.CNTG 0.009 2.414 DRHO.HSDN ..0.776 ENPH.CNTG NPHI.CNTG FCNT .CNtre; Cl.\l!l.CN'l'G RH08.HSDN ENPH.CNTG f\tPH I. CN'fG ~CNT.CNTG CAL1,CNtfG RHOB.HSDN ENPH.CNTG NPHI.CNTG FCNT.CNTG CAr.!1. CNTG RHOB.HSDN E;NPH. CNTG NPHI.CNTG FCNT. C~JTG C.Ät. 1. CNTG RHOB.HSDN ENPH,CNTG NPHI.CNTG FCNT. Cl'}TG CAL1.CNTG RHOS.HSDN f~t·JPP. C NTG !\JPHI.CNTG FC~iT. CNTG C A t1 1 . eN T G RHOB.HSDN r-:NPH. CNTG NPHI.CNTG FCNT.CNTG CAL1.CNTG RHOA.HSD~~ ENPH.CNTG NPHI.CNl'G F'CNT,CNTG C AI.11 . CMTG RHOR.HSDN ENPH" CN'l'G NPHI.CN'l'G FCNT,CNTG CAL1"CNTG RHOB,HSDN B220.000 -999.250 -999.250 ·999.250 37.125 8200.000 ...999.250 -999.250 -999.250 38.945 8100.000 3709.547 1791.938 67.758 23~350 8000.000 3875.547 2018,625 71..875 40.000 7900.00Q 4157.125 2115.688 42.719 32.625 7800.000 3619.346 1635.594 43.9Q6 39.964 7700.000 2906.195 1247.844 77.872 30.344 7600,,000 3056.392 1115.112 74.313 40.000 7550..000 3162~869 11?9.269 61.375 40.000 Df.~P1' . CNE;C.CNTG ~'CNT . CNTG G~Cf-'.CNTG PEF.HSDN DFPT. CNF:C'. CNTG NCNT.CNTG GÞCH,CNl'G PEF'.HSON' I"IFPT. CN~C.CNTG t~ C "1" . (' N T G GRCH.CNTG ?Efi'.~SDN DFPT. CNEC.CNTG NCNT.CN'fG G R C H " C ~ T G PEF. HSD~J DEPT. CN£!~C "CNTG NCNT"CNTG GQCH.CNTG PEJ:r"HSDN DEPT. CNEC.CNTG NC'N'T'.CNTG GRCH.CNTG PE:F.HSDN DEPT. eNEC'. CN'~G NCNT.CNTG GRCH.CNTG ÞEF.HSDN DE~PT . CNE:C . CNTG !\ICNT, CNtrG GRCH.CNTG ?8F.HSDN DEPT. CNEC.CNTG NC'NT.CNTG GPCH.CNTG PE'" .HSDN JIS Tape Verification Listing iChlumberger Alaska Computing Center ----------FQUIVALFNT UNSHIFTED DEPTH---------- GRCH CNTG HLDT _______ __w____ .-_-___ B8888.5 88889.0 88888.0 8200.5 8191.0 8184.5 8176.0 BBQBB.O 8200.5 8190.0 8184.0 8174.0 ---.------..--- BASELINE DEPTH # # C(IRVF SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVR CODE: GRCH PASS NUMBER: 1 STOP DEPTH -----11II......-- 7550.0 7550.0 8196.0 8220.0 ---------------- ___Wl_______ (",NTG HtJD'T' S ~~IIJF HEA.DER F'ILE NU~1I3ER: f;nlTE'D CURVF:S Depth shifted and clipped curves for each pass in separate files. pASS NUMBER: 3 DFPTH INCREMENT: -.5000 # FTLP- SUMMARY VE~DnR TOOL CODE START DEPTH 3 HEADER **** : f~Dr¡r .003 : FLIC : 001COl : 93/08/ 6 : 1024 : tlD : TRAII ~~R **** : EDIT .002 : FLIC : OOlCOl : 93/09/ b : 1.024 : 1.0 : **** t-"ILE fIrJE NAME SF:RVICE VERSION DATE' MAX RE:C SIZE FIl,E TYPE r~AST FIllE **** FILE FILF NAME SERVICE: VERSION Dl\TE MÞ,X REC SIZE F'Ir,F TYPE L,AS 'J' FI LE ** END OF DATA ** 10 PAGE: 6-AUG-1993 14:47 JlS Tape Verification Listing ;chlumberger Alaska Computing Center THE DEPTH ADJUSTMENTS SHOW~ ABOVE REFLECT PASS 3 GRCH TO PASS 1 GPCH, PASS 3 ~FHl TO PASS 1 NPHI AND PASS 3 RHOR TO PASS 1 RHOS. ALL OTHER CURVES wERE CARRIED WITH 100.0 7617.5 7585.5 7579.5 7555.5 770B.0 7694.0 7687.5 7666.0 7792.5 7860.5 7838.5 7826.5 7816.5 BOQ9.0 7939.0 8080.0 8106.5 8236.5 8154.5 11 6·AUG-3..99314:47 PAGE: 99.0 7551.0 7592.0 7625.5 7696.5 7739.0 7803.0 7937.0 8033.0 8014,0 8121.0 8108.0 814.9.5 7550.5 100.5 7624.5 7584.5 7677.S 7761,5 7752.5 7738.5 7732.5 7811.5 7900.0 7860,0 8102.0 8092.5 8065.5 8019.0 8009.5 7994.5 81.35.5 811B.5 8173.0 8153.5 # P.F:'M~RKS: 8112,5 81,54.5 8153,0 8149,0 H136,O 8134,0 H121,O 8118,0 8107,5 S106,5 8101,5 8091,0 8079.5 8065,0 8033,0 8019,0 8013,0 BO()ß.5 7994,5 7938.5 7937.0 7899.5 7860,0 7839.0 7A26.5 7816.0 7811.0 7802.5 7792.0 7761.0 7753.0 7738.5 7738,0 1732.0 7707.5 7696,0 7694.5 7686.5 7677,0 7666.0 7625.5 7624.5 7617.0 7584.5 75R2.0 7579.5 75SC5.5 7552.0 7550.0 100.0 S ,IS Tape Verification Listing ¡chlurnberger Alaska Computing Center ~___~____________-w-_-________________.---_.--___-__-_-_______-___._-.-.--______.__-__. NAMF S~RV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PRDCESS IP ORDER # LOG TYPE CLASS MOP NUMB SAMP ELEM CODE (HEX) -------------------------------------------------------------------.-------------.----. DFpT fT 469840 00 000 00 0 3 1 1 4 68 0000000000 FNPH CNTG PU-S 469840 00 000 00 0 3 , 1 4 68 0000000000 ENRA CNTG 469840 00 000 00 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 469840 00 000 00 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 469840 00 000 00 0 3 1 1 4 68 0000000000 NPHT CNTG PU-S 469840 00 000 00 0 3 1 1 4 68 0000000000 NPAT CNTG 469840 00 000 00 0 3 1 1 4 68 0000000000 CRAT CNTG 469R40 00 000 00 0 3 1 1 4 68 0000000000 NrN~ CNTG CPS 469840 00 000 00 0 3 1 1 4 68 0000000000 FCNT r~TG CPS 469840 00 000 00 0 3 1 1 4 68 0000000000 cNrc CNTG CPS 469840 00 000 00 0 3 1 1 4 68 0000000000 CFTC CNTC CPS 469840 00 000 00 0 3 1 1 4 68 0000000000 GPCH C~TG GAPl 46QS40 00 000 00 0 3 1 1 4 68 0000000000 CÞL1 CNTG IN 469840 00 000 00 0 3 1 1 4 68 0000000000 T~NS CMTG LR 469840 00 000 00 0 3 1 1 4 68 0000000000 eCL CNTG V 46QS40 00 000 00 0 3 1 1 4 68 0000000000 PEF HSDN 4b9840 00 000 00 0 3 1 1 4 68 0000000000 RHQP HSDN G/C3 469840 00 000 00 0 3 1 1 4 68 0000000000 ** SFT TYPF - CHAN ** --------------------.--.---.-. 1 66 0 2 66 0 3 73 76 4 66 3.. 5 66 6 73 7 65 8 68 0,5 9 65 Fi' t1 66 13 12 68 13 66 0 14 65 FT 15 66 66 16 66 1 () 66 1. -...-..........-..........-... VAI.,UE REPR cor,g TYPE: --.-....-.....-----...-.-.-... ** DATA FORMAT SPECIFICATIO~ RECORD ** ** SET TYPE - 64EB ** # LIS FORMAT DATA THEIR RESPECTIVE SHIFTS. $ 12 PAGE: 6-AUG-1993 14.:47 JIS Tape Verification Llstlno 5chlumberqer Alaska Computin~ Center ** nA'rA ** D F' P '1' . B220.000 ENPH.CNTG -999.250 ENRA.CNTG -999.250 CFEC.CNTG ..999.250 CNEC.CNTG ..999.250 NPHI.CNTG -999.250 NP.AT.CNTG -999.250 CRAT.CNTG .999.250 NCNT.CNTG "999.250 FCNT. CN1'G -999.250 CN1:C. CN~rG -999.250 CFTC.CNTG -999.250 GPCH. Cf>;ITG -999.250 CAL!1.CNTG ·999.250 TENS.CNTG -999.250 eClJ. CNTG -999.250 PEF.HSf>N 40.000 RHOB.HSDN 2.167 DRHO.HSDN .0,495 DEPT. 8200.000 ENPH.CNTG ·999.250 E:NR A. CNTG -999. ,250 CFEC.CNTG ,,999.250 CNEC'.CN'rG -999.250 NPHI.CNTG -999.250 NFLAT .CNTG -999.250 CRAT.CNTG -999.250 NCNT. c~J'rG -999.250 FCN T. CNII'G -999.250 C~tTC. CNTG -999.250 CFTC.CNTG ·999.250 GRCH.CNTG -999.250 CAt,l. CNTG -999.250 TENS.CNTG -999.250 CCI.i.CNTG -999.250 PF:F. HSDN 37.174 RH08.HSDN 2.095 DRHO.HSDN -0.550 DFP'!' . 8100.000 ENPH.CNTG 26.708 ENRA.CNTG 4313 CFEC.CNTG 855.734 CNEC.CNTG 3690.922 NPHI.CNTG 28.R24 NRAT.CNTG 2:954 CRAT.CNTG 2.984 NCI\!'T'. CN'rG 1849.594 FCN'I'. CNTG 566.625 CN'T'C.CNTG 1795.063 CFTC.CNTG 615.453 GRCH.CNTG 66.B63 C A 1, 1. eN T G 4.504 TENS.CNTG 2693.875 eelJ. CNTG -0.001 PEF.HSDN 34.781 RH()~.H5DN 2.274 DRHO.HSDN -0.501 DE:PT. BOOO.OOo ENPH.CNTG 23.250 ENPÄ.CNTG ~.929 CFEC.CNTG 976.742 CNE:C . CNTG 3836.71.9 NPH.I.CNTG 22.739 NRA'f. CN'l'G .618 CRAT.CNTG 2.649 rJ (" N 'f . C N T G 2026.500 FC~jT. CNTG 663.250 CNTC.CNTG 1899.594 CFTC.CNTG 697.984 GRCH. C!'>·!TG 68.498 CALl.CNTG 4.510 TENS.CNTG 2653.000 CCL.CNTG "0.024 "FF.HSDN 32.758 RH08.HSDN 1.680 DRHO.HSDN -0.998 DRPT. 7900.000 ENPH.CNTG ~2.1~8 ENRA.CNTG 3.799 CFEC.CNTG 1051.000 CNEC.CNTG 3992.891 NPHI.CNTG 6.6 7 NRAT.CNTG 3.085 CRAT.CNTG 2.867 NCN'T'.CNTG 2137.375 FCNT.CNTG 757.250 CNTC. CN'fG 2237.125 CFTC.CNTG 804.531 GRCH.CNTG 45.203 CAL1.CNTG 4.449 TENS.CNTG 2550.000 CCL.CNTG 0.007 ÞE~.HSf)N 3'2.330 RHOB.HSDN 2.252 DRHO.HSDN -0.490 DFP'T'. 7BOO.OOO ENPH.CNTG 32.834 ENR".CNTG 4.947 CFEC.CNTG 739.188 CNEC.CNTG 3655.469 NPHI.CNTG 39.514 NRAT.CNTG 3.813 CRAT.CNTG 3.570 NCNT.CNTG 1601.234 F'CNT. CNTG 430.438 CNTC.CNTG 1629.219 CFTC.CNTG 475.766 GÞCH.CNTG 46.180 CAL1.CNTG 4.391 T F. N S . C t-' l' G 2508.406 CeT.!. CNTG 0.012 PEF.µSDN 32.641 RHOB. HSD'" 2.167 DRHO.HSDN -0.527 DFPT. 7700.000 ENPH.CNTG 43.024 ENRA.CNTG 5.881 CFEC.CNTG 491.109 CNEC.CNTG 2B87.922 NPHI.CNTG 45.625 NRAT.CNTG 3.919 CRAT.CNTG 3.905 NCNT.C'NTG 1198.500 FCNT.CNTG 284.250 CNTC. C~J1'G 1203.875 CFTC.CNTG 314.397 GRCH.CNTG 83.141 CAL1.Cf\JTG 4.508 TENS.CNTG 2387.875 CCL.CNTG -0.023 ~EF.HSDN 39.238 RHOB.HSDN 2.099 DRHO.HSON -0.528 -~._--.--.-----._---_._--_._---_.-..--_._-.---_..-----.----...-------...-..........-.... NAME SPRY UNIT SERVICE API API API API FILE HIIMR NUMB SIZE REPR PROCESS IC ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ------...-----.-.---.-.-------..--------.---.-...--------------------....--...-.--........ DPHO HSDN G/C3 469840 00 000 00 0 3 1 1 4 68 0000000000 -.--..--------------...-...-...-----.-....-----.-.----.-------..-...----.....----------..-.-. 13 PAGE: 6"'AUG-1993 14:47 JIB Tape Verification L1stinQ ;chluwberger Alaska Computing Center THE ARITHMETIC AVERAGE OF PASSES 1,2, & 3 WAS COMPUTED 1,2,3, 1,2,3, # REMARKS: rNTh HIJbT S _________tllit..... ---------.-- F''fLF HEADER F T f.J F N \ H-1 B E R : 4 AVERAGED CURVES ~ Co~pensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and backround counts; arithmetic average ðf edited static baseline passes for all other curves. DEPTH INCREME~T 0.5000 # PASSES II\!('LtT£)ED IN AVERAGE PBU TOOL CODF PASS NUMBERS 511.019 4:688 236:435 -0.031 CFEC.CNTG CRAT.CNTG CFTC.CNTG CCL.CNTG 500.693 4.042 290.203 -0.078 CFEC.CNTG CRAT.CNTG CFTC.CNTG CCL.CNTG 14 P AGt: : 6.239 4.672 1054.758 2470.000 -0.788 6.091 4.714 1149.290 2310.000 .0..580 ENR A.. CNTG NRA T. CNTG CNTC.CNTG TENS.CNTG DRHD.H5DN ENRA.CNTG NRAT .Cl'FfG CNTC~CNTG TE.:N s. CNTG DRHO.HSDN HEADF~R **** : EDlif III 004 : F'LIC : 00lCOl : 93/()8/ ó : 1024 : J.¡O · · T R AI 11 E R * * * * : EDIT .003 : FLIC : out-COt, : 93/091 6 : 1.024 : LO · " **** FILE FILE NAME SERVICE vERSION DATF MAX REC SIZE FILE TYPE LAST FILE **** F'IL.!E FJJJF NAME SERVICE VF'RSION DATE MAX REC SIZE FILE TYPE LAST FILE ** END OF OATA ** 45.527 4B.1~ 0 274.067 4.445 2.091 47.353 59.890 215.166 4.348 2.376 ENPH.CNTG NPHI.CNTG FCNT.CNTG CAL1.CNTG RHOß.HSDN ENPH.CNtfG NPHI.CNTG FC!\Pf. CNTG CAl~l.CNTG RHOB.HSPN 7600.()OC) 3049.644 104:0.972 74.250 36.016 7550.000 31B8.310 1065.871 66.000 40.000 DEPT. CNE:C. CNTG ~~CNT. CNTG GRCH" CI\ITG PE:f'lII HSDN DE~PT III CNEC.CNTG N('NT.CNTG GRCH.CNTG PE:F III HSDN 6'"'AUG..199.3 14:47 JIS Tape Verification Listing ;chlumberger AlaskaComputlnq Center .w~~----__w_____-____--_-__-__ ** SET TYPE - CHAN ** ---~----------------_._------------------------------------------.---.----------------- NA~F 5ERV UNIT 5ERVICF API API API API FI1.f.: NtJMR NUMB SIZE REPR PROCESS tD ORDER # LOG TYPE CLASS MOD NUMB 5 JdAP EIJEM CODE (HEX) -----------.----------------.---------.-.-----------.-----------------------------.---. DFpT fT 469B40 00 000 00 0 4 1 1 4 68 0000000000 NI?H CNAV PU 469840 00 000 00 0 4 1- 1 4 68 0000000000 ENR ~ C!'''L~ V 469840 00 000 00 0 4 1 1 4 68 0000000000 CFEC CNAV CPS 469840 00 000 00 0 4 1 1 4 68 0000000000 CNEC CNA.V CPS 409840 00 COO 00 0 4 1 1 4 68 0000000000 r~PHT CNAV PU 469840 00 000 00 0 4 1 1 4 68 0000000000 ~RAT CNAV 469B40 00 000 00 0 4 1 1 4 68 (\000000000 CRAT CNA.V 469840 00 000 00 0. 4. 1 1 4 68 0000000000 N('NT CNAV CPS 469840 00 000 00 0 4 1 1 4 68 0000000000 FCN" CNA V CPS 469940 00 000 00 {\ 4 3. 1 4 68 0000000000 C~JT(' CNAV CPS 469840 00 000 00 0 4 1 1 4 68 0000000000 CF'TC' CNAV CPS 469R40 00 000 00 0 4 1 1 4 68 0000000000 GRC~ CÞJAV GAP} 469840 00 000 00 ('I 4- 1 1 4 68 0000000000 TENS CN~, V LB 469g40 00 OOC 00 0 4 1 1 4 68 0000000000 PEF HSAV 459840 00 000 00 0 4 1 1 4 68 0000000000 {<HOE HSAV G/C3 469840 00 000 00 C 4 1 1 4 68 0000000000 DRH(' HSI\V G/C3 469840 00 000 00 0 4 1 1 4 68 0000000000 TENS HSAV [JB 469840 00 {)00 00 (ì 4 1 1 4 68 0000000000 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE "'" 64EB ** ..............-.-............. TYPE REPR CODE VALUE ----................---....... 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 63 0,5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 15 66 1 o 66 1 AFTER ALL DEPTH ADJUSTMENTS WERE APPLIED. $ # LTS FORMAT DATA 15 PAGE: 6-AUG""t993 14:47 LIS Tape verification Llst1na Schlumberqer Alaska Computin~ Center JIS Tape Verification Listing 5chlumberaer AlaSka Computln~ Center 6-J\l'G-1993 14:47 PAGE: 16 .""'._...~..-----_.._-_..---------------...-_..------------.---....-.------.........------ ** DAT~ ** nEPT. 8220.000 NÞH.CNAV -999.250 ENRA.CNAV -999.250 CFEC.CNAV -999,.250 CNEC.CNAV ..999.250 NPHI.CNAV ·999.250 NRAT.CNAV -999.250 CRAT.CNAV -999.250 r.JCNT.CNAV .999.2!50 FCNT.CNAV -999.250 CN1'C;.CNAV -999.250 CFTC.CNAV -999.250 GRCH.CNAV ..999.250 TENS,. CNA V -999.250 PEF'.HSAV 36.903 RHQB.HSAV 2.244 PHHO.HSl\V -0.461 TENS.HSAV -999.250 DF-PT. 9200.000 NPH.CNAV "999..250 ENRA.CNAV ..999.250 CFEC.CNAV ·999.250 CNEC.CNAV ..999.250 NPHI.CNAV '"999.250 NRAT.CNAV -999.250 CRAT.CNAV -999.250 NCNT.CNAV -999.250 FCNT.CNAV -999.250 CNTC.CNAV -999.250 CFTC.CNAV -999.250 GRCH. Cf\l A V -999.250 'rENS. CNA v ·999.250 PE.~F.HSAV 3 8 .1. 09 RHOB.HSAV 2,084 f)RHO,HSAV ..0.546 TE:NS. HSA V -999.250 DEPT, 8100.000 NPH.CNAV 26.572 ENRA.CNAV 4.298 CFEC.CNAV 859,.294 CNFC,CNAV 3693.735 NPHI.CNAV 29.239 NRAT.CNAV 3.030 CRAT.CNAV 3.006 NCNT.CNAV 1827.075 FCNT.CNAV 556.059 CNTC.CNAV 1778,990 CFTC.CNAV 60~'.364 GRCH.C(\LA.V 66.84:6 TENS.CNAV 2705.208 PEF.HSAV 30.072 RHOB.HSAV .267 DRHO.HSAV -0.498 TENS.HSAV 2705.208 DEPT. 8000.000 NPH.CNAV 24.259 ENRA.CNAV 4.042 CFEC.CNAV 954.860 CNEC,CNAV 3857.067 NPHI.CNAV 25.637 NRAT.CNAV 2.836 CRAT.CNAV 2.809 NCNT.CNAV 2010.674 FCNT.CNAV 657.981 CNTC.CNAV 1904.669 CFTC.CNAV 681.114 GRCH.CNAV 68.939 TENS.CNAV 2677.440 PEF.HSAV 37.582 RHOB.HSAV 2.185 DRHO.HSAV 11III0.698 TEN5.HSAV 2677.440 DEPT. 7900.000 NPH.CNAV 23.271 ENRA.CNAV 3.930 crEC '. CNA V 1031.621 Cr.' E r . eN 'A V 4052.433 NPHT.CNAV 26.657 NRAT.CNAV 3.055 CRAT.CNAV 2.865 NCNT.CNAV 2139.015 FCNT.CNAV 750.154 CNTC.CNAV 21,84.657 CFTC.CNAV 795.186 GRCH.CNAV 43.681 TENS.CNAV 2588.075 PEF'.HSAV 34.815 RHOB.HSAV 2.192 DRHf1.HSAV ...0.567 TENS.H5AV 2588.075 DFPT. 7800.000 NPH.CNAV 32.182 ENRA.CNAV 4.881 CFEC.CNAV 741.452 CNE~C.CNAV 3617.993 NP~I.C"JAV 36.758 NRAT.CNAV 3.594 CRAT.CNAV 3.419 NCNT.CNAV 1626.541 FCNT.CNAV 458.966 CN'l'C.CNAV 1650.814 CFTC.CNAV 496.961 GRCH.CNAV 44.035 TENS. C~I A V 2562.629 PEF.HSAV 37.042 RHOB.HSAV 2.194 DRHO.HSAV 11III0.541 TENS. HSA,V 2562.629 DEPT, 77D0.000 NPH.CNAV 42.682 ENRA..CNAV 5.852 CFEC.CNAV 494.423 C~IEC,CNAV 2893.1q9 NPHI.CNAV 45.157 NR~T.CNAV 3.943 CRAT.CNAV 3.880 NCNT.CN~V 1223.345 FCNT.CNAV 293.361 CNTC.CNAV 1216.925 CFTC.CNAV 318.610 GPCH .CNAV 79.244 TEt-.:S.CNAV 2478.335 PEF.HSAV 34.107 RHOB.HSAV 2.094 DRH(t.HSAV -0.521 TE~!S. HSA V 2478.335 DEPT. 7600.000 NPH.CNAV 45.441 ENPA.CNAV 6.079 CFEC.CNAV 499.993 C~JEC.CNAV 3036.500 NPHI.CNAV 49.530 NPÞ.T.CNAV 4.747 CRAT.CNAV 4.119 NCNT. ,c!\rA V 1139.592 FC~'T.CNAV 284.453 CNTC.CNAV 1174.573 CFTC.CNAV 290.841 GRCH.CNAV 73.472 TEt,' S. CN A V 2309.769 PEF.HSAV 38.668 RHOB.HSAV 2.094 DQHf".HSl\V -0.557 TEN5.HSAV 2309.769 16-1.1U 1.,-91 CP 32.6 1745 16-JUl.-93 8282.0 8261.0 7550.0 8222.0 STOP DFPTH -------....- 7542.5 754.2.5 # LnG HEADE:R DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER CFT): TD LOGGER(FT): TOP LOG INTERVAL CFT): BOTTOM LOG INTERVAl. eFT): 8229.0 8229.0 ----....--.- C'NTG HLDT $ ----...----------- fIrJE HKADER FILF' NlJ1~EHi~R Rn.1N CUR\'ES Curves and log header data for each pass 1n separate PASS NUMBER: 1 DFPTH INCREMENT: ·.5000 # FILE SUtJjrÆARY VENrOR TOOL CODE START DEPTH files; raw background pass in last £1 502.181 4 729 235:598 2. ,397 CFEC.CNAV CRAT. CN A V CFTC.CNAV RHOB.HSAV 17 PAGE: 6.32t 5.070 1062.946 39.996 4B.4()3 60.637 221.179 2378.096 2378.096 ENRA.CNAV NRAT.CNAV C~l':rc. CN A V PEF.HSAV 6-AUG-t993 14:47 5 HEll,DER **** : EDIT .005 : FLIC : 00lCOl : 93/08/ 6 : 1024 : tlO : **** .004 TRAILER : EDIT · .. · .. .. · · .. : · .. FLIIC OQ1COl 93/091 6 1024- LO **** FILE FILE ~JAME SERVICE Vf:RSION DÞ.TF .MAX REC SIZE FILF TYPE LAST FILft~ **** FILE FIlJE NA~~E SERVICE VERSrOM DATE MAX REC SIZE F'It.E TYPr.~ LAST FILE ** END OF DATA ** NPH.CNAV NPHI.CNAV FCNT.CNAV TENS.CNAV TENS.HSAV 7550.000 3173.317 1083.795 62.244 -0.767 DEPT. CNEC.CNAV NCNT.CNAV GRCH.CNAV DRHO.HSAV ~IS Tape Verification L1stlna $chlumberger Alaska Computinci Center FIFLD ENGINEER'S REMARKS: TI~O INTO SWS OIL DATED 26-JUNE-1993 . THP~E PASSES MAnE @ 600 FPH fACH. PE~·ARK.S: bLUELINE COUNT RATE NORMALIZATION IN nIL ZON~ TOP NOþMALIZING WINDOW CFT): BAS~ NORMALIZING WINnow 'CFT): P,LtJEf.tNE COUNT RATF: SCALFS SET BY FIELD F,íIJGINE:ER ~AR COU~T RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALF (CPS): 75 NEAR COUNT RATF LOW SCALE CCPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20 TOOL STANDOFF (IN): EPITHERMAIJ S,aNDSTONE 2.65 BRINE 1.1.70 162.0 4599.0 CAL-YA 30 TCC-S 290 SGC-SA 261 CBC-EB 86 CBS-DA 86 CEEC-C 956 CESS-A 763 HLDT 20 """"..""'''''.......... ~rot\L NU MBER 900.0 t,,JO LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VF~NDOR 'TOOL CODE 'root. TYPE ~........."".....-.-...- ---....-- CNTG CALIP~R CNTC TELEMETRY CARTRIDGE CNTG GAMMA RAY CNTG COMPENSATED NEUT~ON CNTG COMPENSATED NEUTRON CNTG COMPENSATED NEUTRON CNTG COMPENSATED NEUTRDN HLDT HOSTILE LITHO.DENS. $ ROREHOLE AND CASING DATA QPFN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FI"UID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): . FLUID LEVEL CFT): FLUID RATE AT WELLHEAD (BPM): wATER CUTS (PCT): Gl\5/0IL. RATIO: CHOKE (DEG): ~n;UTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATR!X DENSITY: HOLE CORRECTION (IN): # # # # # # # # 18 PAGE: 6....AfJG....1.993 14:47 wIS Tape verification Llstlnq 5chlumberqer Alaska Computing Center -----_..-----------------_._~- ** SE~ TYPE - CHAN ** __-____~---____________________________-__R__-_________________________.____--_._.__.-_ NAf-t1F SF.RV UNIT S£o:RVTCF API API API API FILE NIJMB NUMB SIZE REPR PROCESS If) ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM COOE (HEX) --------------.---------.--------.----.-.---.-.------------------------------------.--. OFP'T' F"T 469840 00 000 00 0 5 1 1 4 68 0000000000 ENP~ CN1 PU 469840 00 000 00 0 5 1 1 4 68 0000000000 ENRA CN1 469840 00 000 00 () 5 1 1 4 68 0000000000 CFEC CN1 CPS 46QS40 00 000 00 0 5 1 1- 4 68 0000000000 CNE(' CN1 cPS 469840 00 000 00 0 5 1 1 4 68 0000000000 RCF:F CN! CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 RCEN C~\j 1 CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 NPHT CI\Jl PU 469840 00 000 00 (1 5 1 1 4 68 0000000000 Tt-· pµ CN t PU 46Q840 00 000 00 0 5 1 1 4 68 0000000000 l' N P ð (' N 1- 469840 00 000 00 0 5 1 1 4 68 0000000000 RTNR C~l 469940 00 000 00 0 5 1 1 4 68 0000000000 ~T P ('I R C ,~ j, PU 46QB40 00 000 00 0 5 1 1 4 68 0000000000 R("N'r CN1 CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 R r F ,. C "'! 1 CPS 469840 00 000 00 0 5 1 1 4 bS 0000000000 C ~, 'I' r c N 1 CPS 469340 00 000 00 0 5 1 1 4 68 0000000000 CFTC CN! CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 GP C~\11 GAP I 469840 00 000 00 0 5 1 1 4 68 0000000000 C ~ LTC f'J 1 IN 46Q840 00 000 00 0 5 1 1 4 68 0000000000 TFNS c¡~ 1 LB 469840 00 ooe 00 0 5 1 1 4 68 0000000000 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE · 64EB ** .----..-.---.-----------..-.-- TYPE REPR CODE VALUE ---------.--------.---..---.-- 1 66 0 2 66 0 3 73 Ib8 4 66 1 5 66 6 73 7 65 B 6B 0.5 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 o 66 1 # LIS FQRMAT DATA $ 19 PAGE: 6-At'G-1993 14:47 ~IS Tape Verification Listina ;chlurnberqer Alaska"Comput1nó Center ~IS Tape verification Listing 5chlumberqer Alaska co~riutln4 CentPf 6-AUG-1993 14:47 P AG1!: : 20 ...............-...-..................--...-..........---......-....................... NAMF. SF,RV UN'tT SF;RVICE API API API API P" ItJ E NUMB N.UMB SIZE REPR PROC~:SS tD DR [) E:R # t,OG TYPE C l4AS S MOD NUMB SAMP Et¡EM CODE (HEX) ---.---..........---.....--...----..-....-..................---........-....-.-..-...-- eCL CN j V 469840 00 000 00 0 5 1 1 4 68 0000000000 LSRH HI.J.l G/C3 469840 00 000 00 0 5 1 1 4 68 0000000000 SSRH HLl G/C3 469840 o () 000 00 0 5 1 1 4- 68 0000000000 PErt HLl 469840 00 000 00 0 5 1 1 4 68 0000000000 PEFS HI,! 469840 00 000 00 0 5 l 1 4 68 0000000000 PEF' HI.Jl 469840 00 000 00 0 5 1 1 4 68 OOOOOOOOQO LSW 1 H I.Jt CPS 469840 no 000 00 0 5 1 1 4 68 0000000000 rJs W 2 HtJ 1 CPS 469840 00 000 00 0 5 1 1 4- 68 0000000000 LSW3 HL1 CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 Lsw4 HLl CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 LSWS HLl CPS 469840 no 000 00 0 5 1 1 4 68 0000000000 SSW 1 H f.l 1 CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 8$\.,12 HL1 CPS 469840 00 000 00 0 5 3, 1 4 68 0000000000 5SW3 HL1 CÞS 469840 00 000 00 (I 5 t 1 4 68 0000000000 S5W4 HI-Ii CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 SSL~ 5 Hill CPS 469840 00 000 00 0 5 1 1 4 68 0000000000 H~oe HLl G/C3 469840 00 000 00 0 5 j. 1 4 68 0000000000 þRHO HLt G/C3 469840 on 000 00 0 5 " 1 4 68 0000000000 CS HLl F/HR 469840 00 000 00 0 5 1 1 4 68 0000000000 TEf\I$ HLl 1~8 469840 00 000 00 0 5 1 1 4 68 0000000000 CALI HLl :IN 469840 00 000 00 0 5 l 1 4 68 0000000000 GR HLl GAPI 469840 00 000 00 (I 5 1 1 4 68 0000000000 cet; HLl v 469840 00 000 00 0 5 j 1 4 68 0000000000 ....-................---.--....-.------..-----.-----..--------.-.-..--.....----.-.----- ** DATA ** DEPT. R229.000 ENPH.CNl 37.239 ENRA.CNl 5368 CFEC.CN! 556.606 C ~H~~ (' . C hi 1. 2987.802 RCEF.CN1 544.307 F\CEN.CNl 2772:516 NPHI.CN1 35.620 TNPH.CNl 31.899 TNR~.CNl 3.357 RTNR.CNl 3.488 NPOR.CNl 31.899 RC"NT.CN1 1373.249 RCFT.CN1 389.318 CNTC.CN1 1355.159 CFTC.CN1 414.087 G~.CN1 P6.938 CAt,I. CN 1 6.125 TENS.CNl 1670.000 eCL.CN1 o 011 L S R H . f~ L 1 2.641 SSRH.HL1 2.953 PEFL. Hl,! 37.500 PEFS.HLl 32:094 "EF.HLl 37.sno tJS~11.HL1 17&.250 LSW2.HLl 347.500 LSW3.~L1 721.000 LSW4.HLl 5l7.0nO LS\'15.HLl 497.750 SSW1.HlJl 860.000 SSW2.HL1 2670.000 SSW3.HL1 6808.000 Ssw4.HL1 3258.000 SSW5.HLl 606.000 RHOB.HL1 2.427 DRHO.HLl .U.214 CS.HLl 210.875 TENS.Hf..,l 1670.000 CALI.HLl 6.125 GP.HLt 86.938 CCL.Hli1 0.011 DEPT. 8200.0n(ì ENPH.CNl 39.175 F,NRA.CNl 5.544 CFEC.CN1 556.228 CNEC. r~: 1 3083.975 RCEF.CN! 540.071 RCE:N.CNl 2849.828 NPHI.CNl 39.360 T ",~ PH. C N 1 36.095 'TNRA.cr'!l 3.562 RTNR.CNl 3.R59 NPOR.CNl 37.098 RC'NT.CN1 1321.091 RCFT.CN! 363.659 CNTC.CNl 1334.330 CFTC.CN1 377.479 GR.CNl 86.938 CALI.CN! 4.418 TENS.CN1 2750.000 eCL.CN1 o 022 LSFH.HLl 2.623 SSPH.HLl 3.430 PEFL.HLl 38.219 PEFS.HLl 24:000 PE'"'.HL1 3~.219 T." S W 1 .. H t. 1 1óO.25Q IJ5W2.HL1 362.500 L5W3.HLl 754.500 LSW4.HL1 536.000 LS~5.HLl 481.000 5S\-Jl.HLl 531.000 SSW2.HL1 1765.000 SSI¡! 3. HLl 4696.00Ü SS\t!4.HLl 1852.000 SSW5.HLl 191.500 RHOB.HL1 2.058 DRHO.HLl "0.566 CS.Hl'/l 934.000 TFNS.PLl 2750.000 CALI.HL1. 4.418 GR.HL.l 86.938 CCli.HLl 0.022 GIS Tape Verification Listing Sch!umberger Alaska Computinª Center 6"AUG-1.993 14:47 PAGE: 21 DEPT. SlOO.GOO ENPH.CNl 26.404 ENPA.CNl 4.280 CrEC.CNl 860.003 CNEC.CNt 3680.927 RCE':F. CN 1 824.016 RCE;N. CN t 3455.192 NPHI.CN1 28.678 'fNpH .C!\Jl 26.885 'rNRA..CNl 2.976 RTNR.CNl 2.937 NPOR.CN1 25.937 HCNT.CNl 1840.332 R. C F' T. CM t 538.062 CNTC.CN1 1767.319 CFTC.CNl 599.784 (;R.CN1 65.875 CALI.CN1 4.484 TENS.CN1 2675.000 CCll.CN! -0.044 1.1 S R H. H rJ 1 2.766 SSRH.HLl 3.455 PEF'L.HLl 32.094 PEFS.HL1 40.000 PEF.HLl 32.094 LS\Aj 1. HIll 11.9.938 IJSv/2.HLl 282.250 tl5W 3 .HLl 540.500 LSW4.HLl 377.000 IJSv./S. HLl 358.75Q SSW1.HLl 524.000 SSW2.HL1 1860.000 S S ì,oJ 3. H t.J 1 4672.000 SS\.J 4.HL 1 2036.000 SSW5.HLl 230.750 RHOS. Ht.¡ 1 2.284 DRHO. Ht.ll -0.483 C5.HlJl 903.000 TE~IS.HI,1 2675.000 CAllI .Ht~l 4.484 GR.HLl 65.875 CCL.HLl "0.044 Dr~PT . 8000.000 Ff\JPH.CNl 24.328 E:NRA. CN 1 4.051 crEC.CNl 948.742 CNE.:C. C '\:ì1 3a43.04:~ RCE~F . CN 1 942.472 RCEN.CN1 3594.536 NPHI.CN1 26.:]91 TNPR.CNl 24.821 'fNRA. CN 1 2.850 RTNR.CNl 3 ,.3 4 8 NPDR.CNl 24.735 RCNT.CN1; 1925.,362 RCF'J'.CNl 679.283 CNTC.CNl 1895.094 CYTC.CN1 674.e64 GR.CN! 67.938 CALI.CN! 4.508 TENS.CN!, 2695.000 eCL.CN1 0·.01 3 LSRH.H1Jl 2.889 S5RH.hLl 3.676 PErL. HIJ 1 40.000 PEFS.HL1 35.563 ÞEf".HL1 40.000 l./SW1..Fll.ll 64.438 LSW2.HL1, 173.7S0 I,,5W3.HI,1 387.250 l ~H~ 4. HIJ 1 274.500 TJSW5.HLl 256.500 SSW1 .HLl 454.000 SSW2.HLl 1542.000 SSW3.HI)1 3994.000 SSv!4.H[jl 1733.000 SSW5.HLl 182.375 RHOB.HL1 2.337 DPHn.HLl -0.553 cs. Ht, 1 917.000 TENS. HIlt 2695.000 CALI.HLl 4.508 GR.HLt 67~938 CCI,¡.HLl 0.013 DEPT. 7900.000 ENPH..CN1 22.512 ENRA.CN1 3.844 CFEC.CNl 1040.642 c~n'fC . CN 1 4000.111 RCEF'. CN 1 1.035.867 RCEN.CNl 3664.047 NPHI.CN1 29.595 TNPH.CHl 26.709 ~rNRA.CN1 3.026 RTNR.CN1 3.362 NPOR.CNl 26.200 HCNT"CN1. 2369.317 RCFT" CN 1. 742.768 CNTC.CNl 2304.201 CFTC.CN1 785.102 GR.CN1 38.000 CAI)I. CN 1 4.496 TE:NS.CNt 2650.000 CCI,.CN1 0.013 LSRP.HLl 2.803 SSRH. HlI 1 3.801 ?EFII. HL 1 ~9.500 PEFS.HL1. 35 500 PEF.HL1 39.500 LSWl . Hta 1 103.1&8 LSW2.HL1 2 '6.250 L5W3.HLl 517:500 LSW4.HLl 348.000 L5W5.HLl 294.250 SSW1.HLl 387.500 SSW2.HLl 1290.000 SS¡"3.Hl~'. 3472.000 SSIN4. Hll1 1448.000 55W5.HLl 155.875 RHOB.HLl 2.099 DRHn.HLl -0.7<:'5 C5.HlJl 916.500 TEN5.HLl 2650.000 CALI.HL1 4.496 GR.HIJl 38.000 CCL.HLl 0.013 DFPT. 7800.000 ENPH.CNl 27.898 ENRA.CNl 4.441 crEC.CN! 847.969 C ~.: E C . C N 1 3765.740 RCEF.CNl 832.303 RCEN.CNl 3571.823 NPHI.CN1 33.363 TNpH.CNl 30.229 TNRA.CNl 3.233 RTNR.CNl 3.216 NPQR.CN1 29.643 RCfI\f'T.CNl 1.895.111 RCFT.CN1 506. 303 CNTC.CNl 1R41.294 CFTC.CN1 581.650 GR.. Ci'.J1 37 . 125 CALI.CN1 4.449 TENS.CNl 2555.000 CCL.CNt o 007 LSRf.-I.HL1 2.781 S5RH.HLl 3.541 ÞEFL. Hl,! 38.531 PEFS.HLl 32:531 ÞE~.HLl 38.531 Lswl .HLl 1,19.313 L5W2.HL1 273.750 LSW3.HLl 520.500 LSW4.HI.J1 392.000 Lsw5..HLl 323.000 SSW1 .HLl 500.000 S5W2.HLl 1651.000 SSW3.HLl 4368.000 S5W4.HLl 1869.000 SSW5.HL1 209.125 RHOB.HLl 2.249 DPHO.HL1 -0.534- CS.HLl 916.00(' TENS.HLt 2555.000 CALI.HLl 4.449 GR.HtJl 37. 125 CCL.HLl 0.007 DFPT. 7700.000 F: N PH. c~; 1 42.197 ENR/:;.. CÞ-·J1 5.R11 CFEC.CN1 492.902 CNEC.CNl 2R64.021 RCEF.CN). 482.638 RCEN.CNl 2664.199 NPHI.CNl 46.580 TNPH.CN1 40.952 TNRA.Cl\Jl 3.958 R ,. ~I R . C~' 1 4.214 NPQR.CN1 41.281 RCNT.C"N1 l lq9.672 RCFT.CNl 290.996 CNTC.CNl 1192.213 CFTC.CN1 311.504 G P . C r,¡ 1 76.063 CAIJI.CNl 4.500 TENS.CN! 2420.000 CCL.CN1 0.016 LSRH.HL1 2.586 SSRH.HLl 3. 31B PEFL.HLl 32.750 PEF5.HIJ1 40.000 415. .9.30.· 61239 64:735 206.358 o 012 40:000 346.500 741.000 1, .959 4.320 478.889 48.714 47.751 294.675 ·0.067 40.000 728.000 1731.000 2.102 4.473 826 500 1895:000 2.012 4.500 22 PAGE: CFEC.CNl NPHI.CNl NPOR.CN1 CFTC.CNl eCL.eN! PEFS.HLl L5W3.HLl S5W2.HLl RHOB.HL1 CALI.HL1 crEC.CN! NPHI.CNl ~JPOR. CN 1 CFTC.CNl eCL.CNl PJ!:FS.HLl lISW3.HL1 SSW2.HLl RHOB.HL1, CALI.HL1 LSW3.HLl 5Svi2. HLl RHOB.HL1 CALI.ALl 6.937 2681.431 5.167 965.898 2535.000 40.000 137.625 266.500 185.625 2535.000 6.166 2727.311 4.264 1220.051 2460.000 40.000 352.000 516.000 209.750 2460.000 387.500 538.000 208.750 2420.000 ENRA.CN1 RCEN.CNl RTNR.CNl CNTC.CN1 TENS.CN1 PEFL. HL'l IJ5W2.HLl 5SW1.HLl SSW5. HLl TENS . tIt, 1 ENnA.CNl RCE:N. CN 1 RTNR.CNl CN'T'C.CN 1 TENS.CN! PEFL.HLl l..!SW2. HIll SSvJl. HLl saWS.HLl 'l\EN5.HLt L.5W2. Hlll S5Wl.IIIJ 1 ssws .rHA! TENS.HLl 182.500 532.000 2042.000 916.500 0.016 46.444 472.476 4.075 276.277 4.473 3.393 162.625 477.250 2006.000 916.000 ""0.067 56.597 400.416 4.762 186.680 4.320 4.281 67.750 246.000 1008.000 914.50Q 0.012 6...AUG-t993 14:47 HEADER **** : EDIT .006 ! FLIC : OOlC01 : 93/081 6 : 1024 : [,0 : TRAILER **** : EDIT .005 : FLIC : 00lCOl : 93/081 6 : 1024 : l Q . . liS \¡II 1. . H IJ 1 Il5W5.Hr..ll SSW4. Hl! t CS.HIJl CCL.H[~l F.~NPH. Cf\11 RCEF'. CN ,. TNRA.CNl RCFT.CNl CALI.CN1 SSRH.HLl LSW1.HIJl LSW 5 .fft,l S5W4.HL¡1 cs.. HI,. 1 eCL.fiLl ENPH.CNl RCEF.CN1 TNRA.CNl RCFT.CNl CA.[¡I. CN1 SSRH. Hill {,ISW1.Hl!1 fISW5. HL1 SSv,;4.HIJl C&.HLl CClI.HI)1 **** FILE FILE' NAME SERVICE: VFRSION DATF MAX PEC SIZE FILE TYPE I.",ÞST FILF: **** FIt.,F FTLE NAME SFRVICE VFRSION DATF MAX REC SIZE F'TLJ:' TYPE LI\ST FILE ** END DF DATA ** 32.750 587.000 5068.000 IWO.51.4 76.063 7600.000 2952.71.6 46.:373 1,203.854 75.938 2.635 40.000 532.000 4748.000 -0.533 75.9,38 7542.500 2885.502 63.597 962.017 45.781 2.922 40.000 272.500 2182.000 -0.964 45.781 PE:F'.HLl l,5W4.HI,ll 55vJ3.I1[J1 DRHO.HLl GP..HLl DEPT. eN E:C . CJ\H, TNPH.CNl RCNT.CN1 GR.CN1 IISRB.HLl PP:F' .HLl LSW4.HIJ.l SSw3.HLl DRHO. HIlt GR.HL1 DEPT. CN~:C . CN 1 TNPH.CNl RCNT.CN1 (;R.CNl [¡SRH. HLtl PEJi'.HLl L5v/4.HLl SS\t~~.HrJl DRHO.HI.)l GR.HIJ1 ~!S Tape Verification Llst1nQ 5chlumberger Alaska Computing Center FILE HEADER FILE NUMBER RAW CURVES Curves and log header data for each pass in separate pASS NUMBER: 2 DEPTH INCREMENT: ·.5000 # FIL~ SUMMARY VENDOR TOOL CODE START DEPTH BRINr 11.70 162.0 4599.0 TOOtl NUMBER ..-.."".......... CAL-YA 30 TCC..B 290 SGC-SA 261 CBC..EB 86 CBS..OA 86 CEEC-C 956 CESS"A. 763 HIJDT 20 16-JUlJ"91 CP 32.6 1745 16·~JUI!..93 B282.0 8261.0 7550.0 8222.0 900.0 NO tiles: raw baCKaround pass In last ft # CNTG CNTG CN'I'G CNTG CNTG CNTG CNTG HLDT $ POREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): ORTLl,ERS CASING DEPTH CFT): LOGGERS CASING DEPTH CFT): ROREHOLE cnNOI~loNS FLUID TYPE:: FLUID DENSITY (LR/G): SURFACE TFMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEvEL CFT): F I,{J I D RAT F þ. T (.: E Ill! H F: A D (B Pt\'; ) : 1,AJATER CUTS (PCT): GA.S/OIL RATIO: CHOKE (PEG): it # BOTTOM) TonL TYPE ..w.._.._ CALIPER TELEMETRY CARTRIDGE GAM~i^, RAY COMPENSATED NEUTRON COMPENSATED NEUTRON COMPENSATED NEUTRON COMPENSATED NEUTRON HOSTILE LITHO-DENS. .-....---.--""'-... TOOL STRING (TOP TO VENDOR TOOL CODE # # [JOG HE~ADER DATA DA'1'E LC1GGE:n: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER CFT): TD {JOGGER (f'T) : TOP LOG INTEPVAL CFT): 80TTOM LOG INTERVAL CFT): LOGGING SPEED (fPHR); DEPTH CONTROL USED (VES/NO): STOP D~~PTB .-........"'. 7539.5 7539,5 -..----.-.- 8225.5 8225.5 .._.._._..._._~- CNTG Hl)DT $ 6 23 PAGE: 6""ft.lìG-1993 14:47 ~IS Tape verlflcat1o~ Listing Schlumberger Alaska Computing Center ___________..M__________-___-. TYPE PEPR CODE VALUE ---.-----------------------.-- 1 66 0 2 66 0 3 73 1.68 4 66 1 5 66 Ó 73 7 65 8 68 0.5 9 65 FT 11 66 6 12 68 13 66 0 14 65 F1 15 66 68 16 66 1 G 66 1 ---------------------------.-- ** DATA FORMAT SPECIFICATIUN RECORD ** ** SET TYPE - 64£B ** # LIS FORMAT DATA FIELD ~NGINEER'S REMARKS: TIED INTO SWS DIL DATED 26-JUNE-1993 . THREE PASSES MADE @ 600 FPH EACH. $ REMARKS: NEUTRON TOOL . TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENS!TY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATIDN TOP NORMALIZING WINDOW CFT): BASE NORMALIZING WINOOW (FT): BLtJELINE COUNT RATE SCALES S~T BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 75 NEAR COUNT RATE LOW SCALE (CP5): 0 NEAR COUNT RATE HIGH SCALE (CPSJ: 20 rOOL STANDOFF (IN): IN OIL ZONE EPITHERMAL SANDSTONE 2.65 # # # # 24 PAGE: 6-AUG-1993 14:47 ~I5 Tape Verification Listinq Schlumberg@f AlaSka Computing Center ** DATA ** --------------------------------------------------------------------------------------- ** SET TYPE - CHAN ** _______-.e_-_-_______-______"______-.-_-.-_-.-________---__-________._______-.______.__ NAME SFRV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS 10 ORDER # LOG TYPE CLASS MOD NUMB SAM? ELEM CODE (HEX) _____-_----______-.-_-________________.-.-----._____-_-.-____w_________________-_______ PEPT FT A69840 00 000 00 0 6 1 1 4 68 0000000000 ENPH CN2 PU 469840 00 000 00 0 6 1 1 4 68 0000000000 ENRA CN2 469840 00 000 00 0 6 1 1 4 68 0000000000 ePEC CN2 CPS 469840 00 000 00 0 6 1 1 4 6B 0000000000 CNEC CN? CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 RCEF CN2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 RCEN CN' CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 NPHI CN2 PU 469840 00 000 00 0 6 1 1 4 68 0000000000 TNPH CN? PU 469840 00 000 00 0 6 1 1 4 68 0000000000 TNRA CN2 469840 00 000 00 C 6 1 1 4 68 0000000000 RTNR CN? .. 469840 00 000 00 0 6 1 1 4 68 0000000000 NPQR CN2 PU 469840 00 000 00 0 6 1 1 4 68 0000000000 RCNT CN? CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 RCFT CN2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 CNTC CN2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 CFTC CN2 CPS. 469840 00 000 00 0 6 1 1 4 68 0000000000 GR CN2 GAPI 469840 00 000 00 0 6 1 1 4 68 0000000000 CALI CN2 IN 469840 00 000 00 0 6 1 1 4 68 0000000000 TENS CN2 LB 469840 00 000 00 0 6 1 1 4 68 0000000000 eCL CN2 V 469840 00 000 00 0 6 1 1 4 68 0000000000 LSRH HL2 GtC3 469g40 00 000 00 0 6 1 1 4 68 0000000000 S5Rµ HL2 GtC3 469840 00 000 00 0 6 1 1 4 68 0000000000 PEFL HL2 469840 00 000 00 0 6 1 1 4 68 0000000000 PEFS HL2 469840 00 000 00 0 6 1 1 4 68 0000000000 PEr HL2 469840 00 000 00 0 6 1 1 4 68 0000000000 [,SW1 HL2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 LSw? HL2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 LSW3 HL? CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 LSW4 ~L2 CP5 469840 00 000 00 0 6 1 1 4 68 0000000000 LSWS HL2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 Ssw1 HL2 çps 469B40 00 000 00 0 6 1 1 4 68 0000000000 55W? HL2 CPS 469A40 00 000 00 0 6 1 1 4 69 0000000000 SSW) HL2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 5SW4 PL2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 Ssw5 HL2 CPS 469840 00 000 00 0 6 1 1 4 68 0000000000 RHOR HL2 G/C3 469840 00 000 00 0 6 1 1 4 68 0000000000 DPHO HL2 G/C3 469840 00 000 00 0 6 1 1 4 68 0000000000 CS HL7 FtHP 469840 00 000 00 0 6 1 1 4 68 0000000000 TFNS HL2 LB 46QS40 00 000 00 0 6 1 1 4 68 0000000000 CALI HL2 IN 469840 00 000 00 0 6 1 1 4 68 0000000000 GP HL2 GAPI 46984Q 00 000 00 0 6 1 1 4 68 0000000000 eCL HL2 v 469840 00 000 00 0 6 1 1 4 68 0000000000 25 PAGE: 6-AUG..1993 14:47 ~IS Tape Verification Listinq ;chlumberger Alaska Ccmputinq Center 6·AlIG-199314:4:7 PAce: 26 38 472 E.:NRA. ÇN2 S.48A CFEC.CN2 561.:702 ".·0 549.2~"O RCEN.CN2 2856.79- NPHI.CN2 51',505 4.228 RTNR .C~J2 4.394 NPOR.CN2 46098 301.156 CNTC.CN2 1321.370 CFTC.CN2 320: ,317 6.125 'fENS. C~J2 1745.000 CCL.CN2 0.006 2.994 PEFIJ. HL2 40.000 PEF5.HL2 25,078 163.125 L5W'2. HL2 360.750 L5W3.HL2 179000 579.000 SSW1.Hl/2 848.500 55W2.H1I2 2546:000 3044.000 S5W5.HL2 572.500 RHOB.HL2 2.292 283.250 TENS.HL2 1745.000 CALI.HL2 6.125 0.006 38.472 ENRA.CN2 5.481 CFEC.CN2 561,702 549.290 RCEN.CN2 2856.799 NPHI.CN2 51.505 4.228 RTNR..CN2 4.394 NPOR.CN2 46.099 301.1.56 CNTC.CN2 1321.375 CF'TC.CN2 3 2 O. ;3 1 7 4.359 TENS.CN2 2550.000 CCL.CN2 0.006 3.391 P.F.~Ff..l.HL2 39.469 PEFS.HL2 38.750 149.250 LS~-J2 .HL2 318.000 LSW3.HL2 670.500 466.000 SSW 1. HI.,,2 522.000 SSW2.HL2 1841.000 1983.000 SSW5.HL2 194.000 RHOB.HL2 2.145 902.500 TENS. Ht!2 2550.000 CALI.HL2 4.359 0.006 27.467 ENRA.CN2 4.395 CFEC.CN2 853.054 820.778 RCEN.CN2 3398.770 t\tPHI.CN2 32.271 3.173 RTNR.CN2 3.241 NPO~.CN2 27.463 559.091 CN'1~C. CN2 1813.039 CP"TC.CN2 609.292 4.492 TENS.CN2 2610.000 CCI".CN2 0.010 3.502 PEFL.HL2 27.109 PEFS.HL2 30.031 1.34.000 L5W2.HL2 280.000 x..SW3.HL2 536.500 331.250 SSwl.HlJ2 524.000 55W2.HL2 1820.000 1939.000 SSWS.HL2 215.375 RHOB.HL2 2.282 904.500 TENS.Ht,2 2610.000 CALI.HL2 4.492 0.010 24.867 ENRA.CN2 4.111 CFEC.CN2 923.854 863.776 RCEN.CN2 3488.981 NPHI.CN2 30.757 3.090 RTNR.CN2 3.113 NPQR.CN2 30387 532.054 CN'l'C. CN 2 1864.089 CFTC.CN2 608:002 4.496 TENS.CN2 2600.000 CCL.CN2 "0.021 3.510 PEFIJ. HL2 35.500 PEFS.HL2 29.203 97.000 LStI2. HL2 217.875 I~SW 3. HL2 463.750 309.000 SSW1.HL2 531.500 Ssw2.HL2 1809.000 1970.000 S5w5.HL2 217.250 RHOB.HL2 2.352 921.500 "('EN S. HL2 2600.000 CALI.HL2 4.496 -0.021 25.503 FNFA.CN2 4.181 crEC.CN2 1018.497 987.106 PCEN.CN2 4023.152 NPHI.CN2 20.521 2.517 RTNR.CN2 2.659 NPQR.CN2 19.883 762.472 CNTC.CN2 2020.690 CFTC.CN2 784.867 4.488 TEN5.CN2 2485.000 CCL.CN2 "0.006 3.633 PEfL. HTJ2 40.000 PEFS.HL2 29.797 79.81.3 LSVoi2.HIJ2 163.250 LSW3.HL2 380.000 ENPH.CN2 RCFF'.CN2 TNRA.CN2 RCF"r. Cþ.J 2 CAIJI.CN2 SSRH.HL2 [¡SW1.HtJ2 t,SWS. HI" S5W4. Ht!2 cs. HT.J2 eCL. rH.l2 ENPH.CN2 RCE:r. CN 2 TNfì.A.CN2 RCFT.CN2 CALI.CN2 SSP-H.111$2 t/SW 1.. H[J2 IJSW5.HL2 SSW 4. HL!2 CS-.HL2 CCL.HL2 EI\fPH.CN2 RCEF.CN2 TNRA.CN2 RCFT.CN2 CALI.CN2 SSRH.HL2 LSW 1. HL,2 LSW5.HL2 5 S w 4. H T..I 2 C5.HL2 CCL.HL2 ENPH.CN2 RCFF.CN2 TNRA.CN2 RCFT.CN2 CALI.CN2 SSRH.HL·2 LSW1.HLJ2 LSW5.HL2 SSW4.HL2 CS.HL2 CCL.HfJ2 ENPH.CN2 RCEF.CN2 TNRA.CN2 RCFT.CN2 CALI.CN2 SSRf4.HL2 LSW 1 . HTJ2 8225.500 3078.630 46.098 3339.010 83.875 2.5713 40.000 589.000 6428.000 .0.2B8 83.875 8200.000 3078.630 46.099 1339.010 83.875 2.658 39.469 499.500 4876.000 "0.514 83.875 8l00.000 3749.108 27.323 1830.021 62.563 2.785 27.109 377.750 4552.000 ·0.503 62.563 8000.000 3797.919 28.695 1805.375 70.000 2.830 35.500 320.250 45R4.000 -0.478 70.000 7900.000 4258.846 21.428 2155.506 43.438 2.895 40.000 DEPT. CNE;C. CN2 !'NPH. CM2 RCNT. CN2 GP.CN'2 J..I$RH. HL2 PE:F . HL2 LSW4.HL2 SSW3.HL2 f)RHO" HL,2 GR .HleJ2 DEPT. CN(tC.CN2 TNPH.CN2 RCN'r. CN2 GR.CN2 ["SRH" HL2 PEF.HL2 t"SW4.HlJ2 S5W3.HL2 DPHO.HL2 GR.HtJ2 DEPT. CNEC.CN2 TNPH.CN2 RCN'T'.CN2 GR.CN2 LSRH. HIJ2 PEF.HL2 LSW4.HL2 SSW3.HlJ2 DRHO.HL2 GR.HL2 DEPT. CNEC.CN2 T ~¡ PH" C N 2 RCf\JT .CN2 GR.CN2 LSR~.HL2 PEFi".HL2 LSW4.HL2 SSW3.HL2 o P He. µ J..l 2 GP.HL2 DFPT. C~JEr. .CN2 TNPH.CN2 RCNT.CN2 GP.CN2 LSRH.HL2 PE~. Ht¡2 JIS Tape Verification Listing ;chlumberger Alaska Computing Center 6"'AUG-1993 1.4:47 PAGE: 27 26S.000 SSW1.f.iL~ 474,750 SSW2.HL2 1619.0~O 1769.000 58W5.HL 194.625 RHOB.HL2 2.3 6 920.000 TENS. HIJ2 2485.000 CALI.HIJ2 4.488 -0.006 27.791 ENF: A.CN2 4.429 CFEC,.CN2 870.704 879.714 RCKN. CN2 3571.238 NPHI.CN2 31.140 ,3.111 RTNR.CN2 3.013 NPOR.CN2 25.179 577.407 CNTC.C~2 1847.650 CFTC.CN2 630.257 4.441, TENS.CN2 2535.000 CCL.CN2 o 012 3.512 PEFL.HL2 40,000 PEFS.HL,2 ]3:469 114.750 Lsw2.HL2 281.500 LSW3.HL2 591.000 365.250 SSW1.HIJ2 515.500 SSW2.HL2 1670.000 1923.000 SSW5. H{J2 200.500 RHOa.HL2 2.174 920.500 TENS.HL2 2535.000 CALI.HL2 4.441 0.012 42.918 ENRA.CN2 5.872 CFEC.CN2 482.640 492.970 RCg.r,¡. CN2 2580.453 NPHl.CN2 47.785 4.024 RTNR,CN2 4.000 NPOR.CN2 40.065 292.590 CNTC.CN2 1203.973 CFTC.CN2 326.209 4.500 TEN5.CN2 2535.000 CCL.CN2 .0.139 3.328 PF:FIJ. HL2 38.156 PEFS.HL2 34 344 161.875 LSvJ2. HL2 397.250 I~SW 3.HL2 801:000 485.500 5SWl.HL2 550.500 S5W2.HL2 1915·.000 2046.000 S5W5.HL2 21'1.750 R.HOB.HL2 2,090 918.000 TENS.HL2 2535.000 CALI.HL2 4.500 "'0.139 41.562 ENRA.CN2 5.756 Cf'EC.CN2 511.091 517.576 RCEN.CN2 2692.677 NPHI.CN2 48.083 4.040 RTNF.CN2 4.369 NPOR.CN2 39.539 301.976 CN'rc. CN2 1179.010 CFTC.CN2 307.987 4.473 TENS.Cf\!2 2370.000 CCl~.CN2 0,010 3.398 PEFL.HL2 40.000 PEFS.HL2 36.438 156.625 LSW2.HL2 333.250 LSW3.HL2 741.000 453.000 SSW1.HL2 536.500 SSW2.HL2 1741.000 2013.000 SSWS.HL2 215.000 RHOB.HL2 2.097 922.000 TENS.HL2 2370.f\OO CALI.HL2 4.473 0.010 4~.O86 F.NRA.CN2 6.298 CFEC.CN2 458.283 462.066 RCF:N. CN2 2690.049 NPHI.CN2 63.241 4.872 RTNR.CN2 5.348 NPOR.CN2 63.189 192.944 CNTC. CtJ2 970.900 CFTC.CN2 205.127 4.328 'lIENS. CN2 2460.000 CCL.CN2 0.006 4.273 PEFL.HL2 40.000 PEFS.HL2 40.000 77.875 LSW2.HL2 148.875 LSW3.HL2 364.750 245.250 SSW 1 . HI.,2 263.250 SSW2.HL2 734.000 986.500 SSW5.HL2 174.250 RHOB.HL2 1.932 919.000 TFNS.HL2 2460.000 C~LI.HL2 4.328 o.OOf. L5W5.HL2 SS\Ai4.HL2 CS. rJt12 eCL. Hl<2 ENPH.CN2 RCEF.CN2 TNPA.CN2 RCFT. C~(2 CAhI. CN2 SSRH.HL2 L5Wl.HL2 L5W5.rHJ2 SS"¡4. HI¡2 C5. HJ.J2 CCIJ.HL2 ENPH.CN2 RCE:f". CN2 TNRA.CN2 RCf'T.CN2 ClU/I. CN2 SSRH. HIJ2 l,Sv.i 1. HIJ2 LSW5.HI.l2 SSW4.HL2 C'5.HL2 CCL.HlJ2 ENPH.CN2 Hce'F. Cl\f2 TNRA.CN2 HCFT. C~12 CALl.CN2 S5RH.HL2 L5Wl.f-JL2 LSW5. fHJ2 SSW4.HL2 cs. Ht!2 CCIJ.HIJ2 ENPH.CN2 RCFF.CN2 TrJR~. CN 2 RCFT.CN2 CALI,CN2 SSRH.HI·2 LSW1.HI12 r.sw5.HL2 SSW4.HL2 CS.HL2 eCL.HIJ? 285.500 4200.000 ·0.51.9 43.438 7800.0ûO 3856.751 26.660 1954.636 40.563 2.727 40.000 417.250 4372.ÜOO .0.553 40.563 7700.000 2834.21.4 38.661 11B2.952 78.375 2.600 38.156 576.000 5048.000 ·0.511 78.375 7600.000 2941.597 40.966 1232,235 73.875 2.633 40,000 537.500 4720.000 -0.538 73.875 7539.000 2886,092 66.129 1028.5'7 47.938 2.902 40.000 306.250 2219.000 -0.971 47.938 DEPT, CNE'r.CN2 'f~.!Pµ.CN2 R(NT.CN2 GR.CN2 l! S PH. H L 2 Pf,F.HL2 L5W4.HL2 S~t..¡3.HL2 DRHO,I4L2 GR.HLJ£ 1.1~HjI;4" HL2 SSÏ}13. Ht12 DRHO.HL2 GR.HL2 DEPT. CNEC.CN2 TNPH" Cf\S2 RCN'f .CN2 GR.CN2 LSRH.HL2 PEF.HL2 t,SW4.H[J2 SS\A/3. HL2 DRHO.HL2 GR.HL2 DEPT. CNE:C.CN2 'l'NPH .CN? RCN'f" CN2 GR.CN2 f.!SRP. HI..I2 PEF . HI..!? I.lôW4.Hl.,2 SSv13. HI,2 DFHO, HL!2 GR . Ht!2 DFP'T, CNEr.CN2 TNpH.CN2 RCNT"CN2 GR.CN2 LSRJJ.HL2 PE:F . HL2 L5W4.HL2 S5\~ 3. HL2 DPHI1.HL2 GP.HL2 LIS Tape Verification Listing Schlumberger Alaska Computing Center # lJOG HEADER DATA DATE LOGGED: 80PTwARE VERSION: TIME LOGGER nN BOTTOM: 1'0 DRIllLER CFT): TD LOGGER(F'I): TOP LOG INTERVAL CFT): AOTTOM LOG INTERVAL CfT): LOGGING SPEF:D (FPHR): DE;PTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENnOR TOOL CODE TOOL TYPE TOOL NUMBER 16"Jl1L"91 CP 32.6 1745 16-JUll-93 8282.0 8261.0 7550.0 8222.0 900.0 NO STOP DEPTH .-.._----- 7538.5 7538.5 8229.5 8229.5 ---------------. FI[,F HEADER FILE NUM8ER RA1~ CURVES Curves and log header data for each pass in separate PASS NUMBER: 3 DEPTH INCREMENT: -.5000 # FILE SUMMARY VENDO~TOOL COD~ START DEPTH -----.-.-.... tiles: raw baCkground pass 1n last f1 7 HEADf~R **** : EDIT .007 : FLIC : 001COl : 9,3/081 6 : 1024 : LCJ : 'rHAIIJE:R **** : EDIT .006 : FLIt : 001 CO,. : 93/08/ 6 : 1024 : 1.,0 . It # CNTG PIJDT S **** FII"E F'ILE NAM~: SERVICE VERSION DATE: MAX REC SIZE F'lLF' TYPE LAST FIl,E **** FIIJE F'1'L€ NA"'1E' SE:RVICt~ VERSION DATE MAx RE:C SIZE FILE TYPE L,AST FIIIE ** END OF DATA ** 28 PAGE: 6·AUG-1.993 14:47 J15 TaDe verification Listing 5chlumberger Alaska Computing Center # LIS FORHAT DATA FIELD E~GINEER'S REMARKS: TIED INTO SWS DIL DATED 26-JUNE-1993 . THREE PASSES MADE @ 600 FPH FACH. $ RE~MAPf<S : BLUELtNE COU~T RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW CFT): PIJUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 75 ~EAR COUNt RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20 TOOL ST~NDOFf (IN): EPITHERMAL SANDS!fONE 2.65 BRINE 11,.70 162.Q 4599.0 .............-.. C AJ¡""YA 3 () Tce-a 290 SGC·SA 261 CBC...EB 86 CBS·PA 86 CEF.:C-C 956 CESS-~ 763 Ht¡DT .20 29 PAGE: 6"'AÜG-l993 1.4:47 ~IS Tape Verification Listing Schlumberqer Alaska Computln~ Center CN/PC C~JTG CNTG CNTG CNTG CNTG CNTG HI- D'r $ AOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH eFT): LOGGERS CASING DEPTH (FT): 80REHOLE CONDITIONS ft"LU I D TYPE:: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGr): FLUID SALINITY (PPM): FLUID LEV~L CFT): FLUID RATE AT WELLHEAD CBPM): WATER CUTS (PCT): GAS/OIL RA'rIO: CHOKE (DEG): NEUTRO~ TOOIJ TOOt) TYPE (EPITHE;RMAlJ OR THERMAl.): MATRIX: MATRIX DF':NSITY: HOLE CORRECTION (IN): CALIPER TELEME~RY CARTRIDGE GAMMA RAY COMPENSATED NEUTRON COMPENSATED NEUTRON COMPENSATED NEUTRON COMPENSATED NEUTRON HOSTILE LITHO.DENS. .....--....... -.-.._....-_..~..-""" # # # # # # # ..---.-..-.------------.-.--.- ** SET TYPE - CHAN ** ---.-------------------------.------------.----.-------------------.-.------------.--.- NAME SF.:RV UNIT SE;RVIC~: API API API API FILF NtiMB NUMB SIZE REPR PROCESS IO ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ----------------------------------------.-.-------------------------------..--.------.- DFPT FT 469840 00 000 00 0 7 1 1 4 68 0000000000 ENPH CN3 PH 469B40 00 000 00 0 7 1 1 4 68 0000000000 FNRA CN3 469840 00 000 00 0 .., 1 1 4 68 0000000000 CFEe CN3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 CNEC CN3 CPS 469840 00 000 00 0 7 1 ! 4 68 0000000000 RCEF' CN) CPS 469840 00 000 00 0 '7 1- .1 4 68 0000000000 RC"EN CN3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 iVPHI CH3 Pl1 469B40 00 000 00 0 7 1 1 4 68 0000000000 TNpH C'N3 PU 469840 00 000 00 0 7 1 1. 4 68 0000000000 TNRð CN3 469840 00 000 00 0 7 1 1 4 68 0000000000 RTNR CN3 469840 00 000 00 0 7 1 , 4 68 0000000000 NPOQ CN) PH 469840 00 000 00 0 7 1 i 4 68 0000000000 RCNT eN] CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RCF! CN3 CPS 469940 00 000 00 0 7 1 1 4 68 0000000000 CNTr CN) CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 CFTC CN3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 GR CN3 GAPI 469840 00 000 00 0 7 1 1 4 68 0000000000 CALI c~,~~ IN 469840 00 000 00 0 7 1 1 4 68 0000000000 TFNfi CN3 LB 469840 00 000 00 0 7 1. 1 4 68 0000000000 eCL Ch3 v 469840 00 0(\0 00 0 7 1 1 4 68 0000000000 LSRH HL3 G/C3 469840 00 000 00 0 .., 1 1 4 68 0000000000 SSRH HL3 G/C3 46Q840 00 000 00 0 7 1 1 4 68 0000000000 p F f l. t-1 L 3 469640 00 000 00 0 7 1 1 4 68 0000000000 PJi:F5 H[J3 469840- 00 000 oc () 1 1 1- 4 68 0000000000 TYP€ REPR CODE VALUE --..-.------.---.------.-.-.-. 1 66 0 2 66 0 3 73 168 4 66 1 5 66 6 73 7 65 8 68 0,5 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 o 66 1 -.--------.-.------------.-.-- ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** 30 PAGE: 6""AUG-1993 14:47 JIB Tape Verification Listing ;chlumberger Alaska Computing Center ** DATA ** DEPT. B229.500 ENPH.CN3 37.708 ENRA.CN3 5.411 crEC.cN3 580561 CNEC.CN3 3141.482 RCEF.CN3 561.732 RCEN.CN3 2915.123 NPHI.CN3 31 32 'rMPH . CN 3 33.339 TNRA.CN) 3.450 RTNR.CN3 3.585 NPOR.CN3 33 339 HCNT.CN3 1357.774 RCF1'. CN 3 374.514 CNTC.CN3 1339.888 CFTC.CNJ 398 342 GR.CN3 95.1BB CAt,I. CN 3 6.125 TENS.CN3 1720.000 eCL.CN3 0010 LSPH.HL3 2.553 SSRH.HL3 2.93·4 PEFl~. HL 3 40.000 PEF5.HL3 40·000 PEF.HL3 40.000 LSW1.HL3 195.750 LSW2.HL3 422.750 LSW3.HL3 857:500 LSW4.HL3 683.500 LSW5.HL3 563.000 SSW1.HL3 823.500 SSW2.HL3 2602.000 SSW3.HlJ3 6580.000 SSW4.HL3 3246.000 SSW5.HL3 616.500 RHOB.HL3 2.289 DRHO.HL3 -0.264 CS.HL3 335.500 TENS.HL3 1720.000 CALI.HL3 6.125 GR.HL3 RS.la8 CCL.HL3 0.010 DEPT. B200.000 ENPH.CN3 40.628 ENRA.CN3 5.674 CFEC.CN3 552.218 C·JEC.CN3 3133.193 RCEF.CN3 538.094 RCEN.CN3 2904.062 NPHI.CNJ 41.381 T"JPH .CN3 37.864 TNRA..CN3 3.673 RTNR.CN3 3.874 NPOR.CN3 38.065 RrNT.CN3 1361.612 RCF'T.CN3 361.993 CNTC.CN3 1349.778 CFTC.CN3 370.543 GR.CN3 RS.188 CALI.CN3 4.324 TENS.CN) 2630.000 eCL.CN3 0.010 IJSRH. HL3 2.660 SSRH.HtJ3 3.500 PEFIJ. HJ.J3 31.594 PEFS.HL3 21.813 PEJi'.HL3 37.594 LSW1.HL3 155.750 LSW2.HL3 341.250 LSW3.HL3 678.500 LSW4.HL3 506.500 L5W5.HL3 454.500 SS~1. .HL3 503.750 SSW2.HL3 1639.000 SSW3.HL3 4512.000 SSW4.HL3 1725.000 SSW5.HL3 162.625 RHOB.HL3 2.070 DPHO.HL3 ..0.591 CS..HL3 902.000 TE~'S. HL3 2630.000 CALI.HL3 4.324 G~.HL3 85.188 CCL.HrJ3 0.010 DFPT. ijl00.000 F.NPI~.CN3 26.512 ENRA.CN3 4.292 CFEC.CN3 859.309 CNEC.CN3 3688.100 RCEF.CN3 880.399 RCEN.CN) 3428.887 NPHI.CN3 29.375 ,!'HPH. CN 3 26.5R2 TNRA.CN3 3.014 RTNR.CN3 3.146 NPQR.CN3 26.681 RCNT.CN3 1830.875 RCFT.CN3 598.039 crlTC. CN 3 1811.848 CFTC.CN3 619.130 ._._--.-~----------_...__._-----_._.._--_.._.._---._---_.-----..---------..---------.--.-.-- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODr (HEX) ------..------..-------------.----...------..-.-------------...----....-.-..----....--......... P~F HL3 469840 00 000 00 0 7 1 1 4 68 0000000000 LSW1 HL3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 LSW2 HL3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 LSW3 HL3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 LSW4 HL3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 Lsw5 HLJ CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 Ssw1 HL3 CPS 469940 00 000 00 0 7 1 1 4 68 0000000000 SSW2 HL3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 SSW3 HL3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 SSW4 HL3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 saws HL3 CPS 469840 00 000 00 0 7 1 1 4 68 0000000000 RHOS HL3 G/C3 469840 00 000 00 0 7 1 1 4 68 0000000000 DRHO HL3 G/C3 469840 00 000 00 0 7 1 1 4 68 0000000000 CS HL3 F/HR 469840 00 000 00 0 7 1 1 4 68 0000000000 TENS HL3 LB 469840 00 000 00 0 7 1 1 4 68 0000000000 CALI HL3 IN 469840 00 000 00 0 7 1 1 4 68 0000000000 GP HL3 GAP! 469840 00 000 00 0 7 1 1 4 68 0000000000 eCL HL3 v 469840 00 000 00 0 7 1 1 4 68 0000000000 ----.-~_._---.-.._--_.......-.---.-_.._.._-.......-----_.-.-..-.......--.---.....-...-.......-........ 3'. PAG!~ : 6-AUG-1993 14:47 LIS Tape Verification ListlnQ Schlumberger Alaska Computing Center :·1 S Tap eve r i f 1 cat 1 0 n T"I. i s t 1, n q Schlumberqer Alaska Computing Center GR.CN3 t¡8RH. HL 3 Pff~F .Hr.~3 LSW4.HL3 S5W3.HL3 DRAD.Hr..!) GR.HL,3 Dr:P'T . CNE:r. CN3 !'NPH. CN 3 RCNT.CN3 GR,CN) LSRH.HL3 Þr;F . HfJ3 tj5!;~4,HL3 S5W3.Hr.J3 DRHO.I1[,3 GR.HlJ3 Df~PT . CrIEr.CN3 TNPH.CNJ RCNT,CN3 GR.CN3 t.!5RH.HLJ3 "Eft' . Hl..! 3 LSW4.HL3 SSW3.Ht,3 O~HO.HL3 G ~ , H J.J 3 DEPT. CNEC.CN3 T~,tPH. CN 3 RCNT.CN3 GÞ.CN3 LSRH. HIJ3 PEF.HL3 LSW4.HL3 Ssw3.HL] DRHO.HL3 GR. H IJ 3 DEPT. CNE(".CN3 T~JpH. CII..; 3 R r. NT. Cf':: 3 GR.CN3 LSRµ.HrJ3 PF'" . HIJ 3 LSW4.4L3 SSW3.HlJ3 DRHf'. HIJ3 GR.HL,3 62.469 2.777 33.500 .369.250 4584.000 -0.501 62.469 8000.()OO 3842.667 24.084 1768.963 67.375 2.8t3 33.063 343.000 3564.000 ..0.674 67.375 7900.00(':' 3973.738 23.160 2483.673 40.500 2.859 34,438 330,750 4496.000 -0.48& 40.500 7800.000 3782.864 27.450 1.921.128 45.969 2.770 35.156 377.500 4668.000 ....0.485 45.969 7700.000 2869.434 40.347 1235.321 7B.313 2.60Q 33.031 544.500 4916.000 -0.52, '78.313 C.AL,I.CN3 SSRH.Ht,3 IASW1.HL3 [,sw5. HL3 S5w4.Hr.J3 CS.HI13 eCL. tlt,3 ~:NPH.CN3 RCEF.CN3 TNRA.CN3 RCFT.CN3 CALI.CN3 SSRH.HL3 L5W1.HL3 r~SW5.HL3 S5W4.HL3 CS.HL3 CCI.t. BL3 ENPH.CN3 RCEF.CN3 TNPA.CN3 RCFT.CN3 CAllI. Cl\'3 SSRH.HL3 I.1.Sfw\11. HIJ3 LSW5. HJ.J3 SSW4.H[.3 CS.HL3 eeL. H 1, 3 E!\!PH. CN 3 RCEF.CN3 T!·JRA.CN3 RCFT.CM3 CALI.CN3 S5RH.HL3 LS~tl.HL3 L S y1 5 . H L 3 Ssw4.HL3 CS.HL3 CCL.HL3 ENPH.CN3 RCEF.CN3 TNRA.CN3 RCFT.CN3 CALI.CN3 SSRH. HTJ3 £JSVJ1.HL3 t,SW5. PL3 SSW4:.HL3 CS.HlJ3 rçL.HL3 6"AUG-l993 14:47 PAGE: 32 4.504 '¡'ENS.CN3 2580.000 cel.l. CN J "0.037 3.490 PEFt,.HL3 33.500 PEFS. BIA 3 30.,141 108.750 lJsw2.HL3 262.500 L5W3.HL3 545000 320.250 ssw 1. f'JL3 527.500 SSW2.HL3 1792:000 1953.000 SSW5.HL3 223.750 RHOB.HL3 2.277 904.500 T~:N5. HL3 2580.000 CAt)!. HL3 4.504 80.037 25.340 F:NR A., CN 3 4.164 crEC.CN) 922.941 890.253 BCEN.CN) 3537.853 NPHI.CN3 28.299 2.955 RTNR.CN) 3.185 NPOR.CN3 25.656 595.599 CNTC.CN3 1829.406 CFTC.CN3 663,308 4.508 TENS.CN) 2630.000 CCIJ. CN. 3 -0.007 3.768 PEFL.. Hr..!) 33 063 PEFS.HL3 40.000 110.938 IJ5W2.. HL,) 252:750 LSW3.HL3 513.500 294.750 SSW 1 . HJ.,I3 386.250 55W2.HL3 1345.000 1524.000 SSW5.HL3 156.000 RHOB.HL3 2. ·1 39 919.000 TEN5.HL3 2630.000 CALI.At3 4.508 -0.007 20.311 E~JR A .Ct\13 3 586 CFEC.CN3 11~8'i4t 1079.760 RCEN.CN3 3648:575 NPHt.CN3 3. 1 2.709 RTNR.CN3 2,. 656 NPOR.CN3 20.392 789.271 CNTC.CN3 2241.593 CFTC.CN3 831.855 4.453 TENS.CN3 2570.000 eCL.CN3 0.060 3.551 PEFL.HL3 34.438 PEFS.HL3 29.734 100.313 LSW2.. Hr.,3 203.500 LSW3.HL3 439.250 262.500 SSW1.HL3 507.500 SSW2.HJ..I3 1755.000 1890.000 S5W5.HL3 l89.500 RHOB.HL3 2.374 919.000 TENS,HL3 2570.000 CALI.HL3 4.453 0.060 27.353 F.NRA.CN3 4.383 CPEC.CN3 863.140 814.063 RCEN.CN) 3554.880 NPHI.CN3 30.922 3.099 RTNR.CN3 3.206 NPOR.CN3 26.492 560.909 CNTC.CN3 1845.053 CFTC.CN3 618.309 4.387 TENS.CN3 2495.000 eCL.CN3 -0.019 3.461. PEFL.HL3 35.156 PEFS,HL3 35.969 l26.688 LSW2.HL3 262.500 L5W3.HL3 549.500 350.500 SSW1 .HL3 529.000 SSW2.HLJ 1794.000 2014.000 SSW5.HI./3 237.875 RHQB.HL3 2.285 918.500 TENS.HL3 2495.000 CALI.HL3 4.387 -0.019 44.047 ENRA.CNJ 5.968 CFEC.CN3 480.814 456.088 PCEN . c~' 3 2681.431 NPHt.CN3 41.310 3.998 RTtIJR.CN3 4.151 NPQR.CN3 39.574 292.590 C ~I T C " eN 3 1198.698 CFTC.CN3 316.155 4.508 TfNS.CN3 2580.000 CCL.CN3 ..0.120 3.354 P E f' J.I . H L 3 33.031 PF.FS.HL3 39.594 165.375 L,5W2. HL3 378.000 LSW3.HL3 799.000 485.750 SSW1.HL3 537.000 SSW2.HL3 1878.000 2035.000 S5W5.HL3 215.375 RHOS. HI..l3 2.089 Q16.500 rr F N S . H I.. 3 2580.000 CALI.HL3 4.508 -0.120 JIS Tape verification LlstinQ ;chlumberger Alaska Computinó Center DEpT. CNE;C.CN3 TNPH .CN3 RCNT.CN) G'R.CN3 LSRH.HL3 ÞEF.HL3 IJSW4.HL3 SS\~3.HL 3 DRHO.HL3 GR.rHJ3 DEPT. C1\IEC . CN 3 '1'NPH. CN 3 RCNT.CN) GR.CN) LSRt-f.HL3 PEF.HL3 I.!SW4.HL3 SS\.v3.HL3 DRHO.HlJ3 GR.~HJ3 7600.000 2975.176 39.831 1219.736 72.438 2.623 40.000 56B.OOO 4724.000 "0.542 72.438 753B.500 2845.206 64.B06 953.938 50.53! 2.910 40.000 297.25() 22j2.000 -().975 50.531 ** END OF DATA ** **** FILE FILE ~}AME SF.'RVICE VFRSION DATE ~T1X REC SIZE FTLF" TYPE L·A.ST FILE; ENPH.CN3 RCEF.CN3 'rNRA.CN3 HCFT.CN3 CAl,I.CN3 SSRH.HL3 LSWt.HL3 I",SW5.. Ht!) SS\t14.. Hl,) CS.HL3 CCL.HL3 ENPH.CN3 RCF:F. CN 3 TNRA.CN3 RCFT.CN3 CAlII.CN] SSRH. HIJ 3 I.¡S\\ft. Hl,3 LSW5.HL3 S S ~r 4. H 1.1 3 CS. Hl.l3 CCL.HL3 TRAItlER **** : EDIT .007 : f.T'LIC : 001COl : 93/08/ 6 : 1024, : T.JO : 6-AUG-1993 14:47 44.246 488.870 4.083 312.990 4.461. 3.395 162.375 465.750 t984.000 919.500 -0.057 53.991 416.846 4.802 190.748 4.318 4.285 74.000 246..625 983.500 917.000 -0.035 ENRA.CN3 RCEN.CN) RTNR.CN3 CNTC.CN3 TENS.CN] PEFt". HL3 IJSW2. HL3 ssw 1. f..J lJ 3 S5\~5 .HL3 TENS.HL3 ENRA.CN3 RCKN,CN3 RTNR.CN3 CN1'C, CN 3 TENS.CN) PEFL.HL3 LSW2" HtJ3 Ssw 1 "HI,,3 5SW5.HL3 TENS.HL3 5.985 2784.965 4.116 1146.608 2380.000 40.000 352.750 502.250 203.750 2380.000 6.749 2640.453 5.000 948.120 2415.000 40.000 138.125 272.500 164.375 2415.000 **** SERVICE D~TF ORIGIN T,Aþ~ NAME C 0 !'IJ 'T' I N U A. T ION # PP EV I OU5 T .rd'E rOt"~"'ENT TAPE TRAILER **** f~ AM_E : EI)IT : 93/0BI 6 : FLIC : 93l1B : 1 : : ARca AJ.ASKA, INC.,KUPARUK RIVER,1Y-24,50-029-22371-00 CFEC.CN3 NPHI.CN3 NPOR.CN3 Cb"tTC. CN) eCL.CN) PEFS.HL3 L5W3.HL3 SSW2.HL3 RHOB.HI..) CALI.HL3 crEC.CN) NPHI.CN3 NPOR.CN3 CFTC.CN3 CCL.CN) PEFS.HL3 LSW3.HL3 SSW2.HL3 RHOB.HL3 CAlJI.HL3 PAGEt 3) 497.145 48.869 37'.648 304.883 ·0.OS7 40,000 745,500 1730.000 2.081 4.461 421, .578 61.967 65.282 201·,463 -0.0')5 31.063 351.750 695.500 1937 4:348 TRAlt.JER **** : EDIT : 93/08/ 6 : F'LIC : 93318 · · · i ARCa ALASKA, INC.,KUPARUK RIVER,1Y-24,50-029-22371·00 **** REEL SERVICE: Nt\ME DA'.tF ORIGIN RE~~L NAME CONTINIJATION# pREVIOUS REF:L COM M f: \J'r 34 6""AUG-1.993 1,4:4:7 ~IS Tape Verification Listing 5chlumberger Alaska Computing Center PAGE:
