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196-005
XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~ --- ~,~' File Number of Well History File PAGES TO DELETE RESCAN Complete 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:~ Dianna TO RE-SCAN Vincent Nathan Lowell Notes: Re-Scanned by: Be~,edy Dianna Vincent Nathan Lowell Date: Is~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for CT Sidetrack I Status of Well ClasSification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number Phillips Alaska Inc. 196-005 302-100 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22641-00 4. Location of well at surface 9. Unit or Lease Name 1332' SNL, 1756' WEL, SEC. 25, T13N, R08E, UM '~~~. At top of productive interval .j ~.....;~! Kuparuk River Unit 2012' SNL, 3636' WEL, SEC. 35, T13N, R08E, UMAt total depth L "' :i:: i!10' well Number~~,..~~ , 3M-29 / 2129' SNL, 3770' WEL, SEC. 35, T13N, R08E, UM ~11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River RKB = 68' ADL 025523 12. Date Spudded 01/19/1996 113' Date T'D' Reached 114' Date C°mp" Susp" °r Aband' 01/25/1996 4/24/2002 I15' water depth' if OffshOre N/A MSL .' 16. No. of Completions Zero 11866 6218 FT 11767 6142 FTI []Yes []No N/A MDI Approx. 1380'ss 22. Type Electric or Other Logs Run GR / CDR 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP Bo'FrOM S~ZE CEMENTING RECORD AMOUNT PULLED 16" 62.58# H-40 Surface 121' 24" 270 sx Arcticset I , 9-5/8" 40# L-80 Surface 5827' 12-1/4" 1230 sx AS II1~ 730 sx Class 'G' 7" 26# L-80 Surface 11856' 8-1/2" 200 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) None 3-1/2", 9.3#, L-80 11530' 11503' MD TVD MD '['VD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11596' Cement Squeeze, Approximately 4 Bbls behind pi'pe, Sqzd to 2000 psi 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Not on Production! N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS'MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS'MCF WATER-BBL OIL GRAViTY-APl (CORR) Press. 24-HOUR RATE ~, CORE DATA Bdef description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ~PS., ~. ~.. No core samples were taken .... ,JUL ~laoka. Oi! &, Gas Anchorage., Form 10-407 Rev. 07-01-80 ~ i x,~ ~ FJ Fl N] $ B F L SEP R 3 ?,;,~ubmit In Duplicate ~29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered and Depth Depth gravity, GOR, and time of each phase. Kuparuk C 11592' 6010' Kuparuk A 11592' 6010' 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge _Signed TerdeHubble~/.~_~ ~~.~.~. Title TechnicalAssistant Date 3M-29 196-005 302-100 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 SCANNED Well: 3M-29A Rig Accept: 05/02/02 Field: Kuparuk River Unit Rig Spud: 05/05/02 APl' 50-029-22641-01 Rig Release: 05/16/02 Permit: 202-084 Drilling Rig' Nordic #1 PRE-RIG WORK 03/02/02 PRE-CTD, MITOA- FAILED, POT-T- PASSED, PPPOT-T- PASSED, POT-lC - FAILED. 04/08/02 MEASURED BHP AT 11600' RKB: 1167 PSI. GAUGED TUBING W/2.79" SWAGE TO 'D' NIPPLE. TAGGED FILL AT 11700' RKB, EST. 86' RATHOLE. PULLED GLV's AT 4502', 8264' AND 10190' RKB, SET DV AT 4502' RKB. 04/09/02 SET DV's AT 8264' AND 10190' RKB, SET 2.75" CAT SV AT 11520' RKB, PULLED OV AT 11449' RKB. 04/10/02 LOADED CASING WITH 250 BBLS DIESEL, SET 1.5" DV AT 11449' RKB, PRESSURE TEST TUBING AND I/A TO 2500# HELD, PULLED CAT SV AT 11520' RKB. 04/21/02 RIG UP AND RUN 2 FT 1-11/16 TUBING TAIL PUNCHER. SHOOT 4 SPF BELOW PACKER. TOP SHOT AT 11535'. 04/22/02 PUMPED INJECTIVITY TEST, 3 BPM AT 1100 PSI, 2 BPM AT385 PSI, 1 BPM AT 5 PSI AND FALLING. RIH, TAGGED PBTD, ADJUST CT DEPTH, PU 15' FLAGGED COIL. BRING ON CEMENTERS, PUMPED AS PER DESIGN, 17 PPG W/AGGREGATE. CEMENT AT NOZZLE, PLUGGED OFF NOZZLE. UNABLE TO REVERSE DUE TO LOW BHP, POOH AS FAST AS POSSIBLE. AT SURFACE, CUT APPROXIMATELY 95', GOT THROUGH PACKED OFF AGGREGATE IN ENTIRE BHA AND BOTTOM 10' OF COIL. FOUND FROZEN CEMENT TO 95'. FLUSH COIL AND ALL LINES, PUMPED 1 TUBING VOLUME (100 BBL) FLUSH INTO WELL FOLLOWED BY 20 BBL FREEZE PROTECT. STAND BACK. 04/24/02 PERFORMED A CEMENT SQUEEZE FROM 11723' TO 11542'. APPROX. 4 BBLS GOOD CEMENT PUSHED BEHIND PIPE. WAS ABLE TO ACHIEVE 2000# WHP DURING HESITATIONS. FREEZE PROTECT WELL TO 2500'. 04/26/02 TAGGED CEMENT TOP AT 11545' RKB. TESTED TUBING / CEMENT TO 1000 PSI. OKAY. 04/28/02 TAGGED CEMENT TOP 3 TIMES AT 11526' WLM, UNABLE TO CORRECT TO 'D' NIPPLE DUE TO CEMENT IN TUBING. PHILLIPS PETROLEUM CO. Page 1 ~ Operations Summary Report Legal Well Name: 3M-29 Common Well Name: 3M-29A Spud Date: 1/20/1996 Event Name: REENTER+COMPLETE Start: 4/30/2002 End: Contractor Name: NORDIC CALISTA Rig Release: 5/16/2002 Rig Name: NORDIC 1 Rig Number: Date From -To Hours Task Code NPT Phase Description of Operations 4/30/2002 00:00 - 00:00 24.00 MOB N WAIT PRE Begin Standby Rate at 00:00 hrs on 4/30/02. Parked on 3C-04A while WOW (Phz I 30-40 mph winds, drifting snow). Also, we mousehole to be drilled on 3M-29. Weather conditions @ Phz 3 by midnight. 5/1/2002 00:00 - 00:00 24.00 MOB N WAIT PRE Continue to standby on 3C-04A while WOW & for mousehole to be drilled @ 3M-29. Normal driving conditions on main road & Phz 2 on all other roads as @ midnight. 5/2/2002 00:00 o 08:30 8.50 MOB N WAIT PRE Continue to standby on 3C-04A while WOW & for mousehole to be drilled @ 3M-29. 08:30 - 09:00 0.50 MOB P PRE SAFETY MEETING. Reviewed rig move procedure and all road / other conditions for rig move with all personnel. Ended rig standby for weather at 08:30 hrs. 09:00 - 15:30 6.50 MOB ~ PRE Moved rig to 3M Pad. 8.5 miles. No problems. Meanwhile field crew drilled 21 ft deep rathole and set 16" casing, 5 ft 3 in. center to center from front of tree. 15:30 - 16:00 0.50 MOB ~ PRE SAFETY MEETING. Reviewed rig back over well procedure, WHP and Flowline press bleed to 0 psi. 16:00 - 18:00 2.00 MOB ~ PRE ACCEPT NORDIC #1 ON KRU 3M-29A AT 16:00 HRS, 05/02/02. Perform general rig-up. Spot trailers, etc. 18:00 - 21:30 3.50 BOPSUF ~ DECOMP i Nipple up BOPE. Made visual inspection of 2-3/8" pipe / slip rams, rubber still in new condition after drilling 2 sidetracks. Prep for BOPE test. Meanwhile spot & berm cutting tank & flowback tanks. 21:30 - 00:00 2.50 BOPSUF~ ~ DECOMP PJSM. Pressure tested BOPE to 3500psi as per drilling permit. Witnessing of test waived by State Rep John Spaulding. 5/3/2002 00:00 o 00:30 0.50 BOPSURP DECOMP Continue P/testing BOPE. Check valve on kill line leaking ~ will rebuild/retest @ end of other tests. Meanwhile observe short in e-line. Bulkhead @ reel tests OK. Open up UQC & found wet e-line core. 00:30 - 01:00 0.50 BOPSUF N SFAL DECOMP Suspend BOPE test. P/U injector & cut 55' of CT/e-line to locate dry e-line core. 01:00 - 02:00 1.00 BOPSUF:P DECOMP Valve crew removed IA VR plug. 02:00 - 08:00 6.00 BOPSUF:P DECOMP Resume P/testing BOPE. Meanwhile take-on 210bbls of used 8.7ppg KCL/NACL milling FlooPro mud. Also M/U new BHI CTC & carried out successful continuity tests on e-line system. Pull test CTC to 20k & press test with inner reel valve to 3500psi - OK. 08:00 - 08:15 0.25 STWHIP P WEXlT SAFETY MEETING. Reviewed well plan and BHA M/U procedure and hazards. 08:15 - 09:15 1.001 STWHIP ~ WEXlT M/U straight motor and 2.80" HC, D331 Mill #1 [ Parabolic diamond mill]. 09:15 - 11:40 2.42 STWHIP ~ WEXlT RIH with BHA #1. Straight motor and 2.80" D331 Mill #1. 11:40-12:40 1.00 STWHIP ~ WEXIT !Tagfillat11524'CTD, correctto 11,542ftBKB,[+18ff], assuming at D Nipple. Started milling. 1.5 / 1.5 bpm, 2800 psi, 700 WeB. Milling like cement. Slower milling from 11546 - 11548 ft. but unable to clearly see D Nipple milling. Milled to 11,548 ft. 7K dwn wt, 23K up wt. Back ream to 11532 ft. 12:40-13:10 0.50 STWHIPiP WEXlT Log GR tie-in at GR spike at11500 ft. Ref. PerflogGR/CCL. -6 ft CTD. Corrected TD at 11,542 ft. Which is the D Nipple depth off the Printed: 5120/2002 3:16:13 PM PHILLIPS PETROLEUM CO. Page 2 ~ Operations Summary Report Legal Well Name: 3M-29 Common Well Name: 3M-29A Spud Date: 1/20/1996 Event Name: REENTER+COMPLETE Start: 4/30/2002 End: Contractor Name: NORDIC CALISTA Rig Release: 5/16/2002 Rig Name: NORDIC 1 Rig Number: Date From -To Hours I Task Code NPT Phase Description of Operations 5/3/2002 12:40- 13:10 0.50 STWHIP P WEXIT perf record log. 13:10-13:50 0.67 STWHIP P WEXIT Milldownfrom 11542-11550ft. Milling like cement. 20fph, 2000~ WOB, 1.5/1.5 bpm, Ream D nipple up / down twice. Milling Summary: Milled cement from 11536-11542 ft. Milled D Nipple at 11542-11543 ft. Milled firm cement 11543-11550 ft. 20 fph with 2200~ WOB. 13:50 - 15:20 1.50 STWHIP P WEXlT POOH with milling BHA #1. Open circ valve and circ at 1.3 bpm, 1900 psi. 15:20 - 15:40 0.33 STWHIP P WEXlT Lay out milling BHA #1. 15:40 - 16:10 0.50 STWHIP P WEXlT SAFETY MEETING. Held pre-spud Safety Meeting with crews and Phillips personnel. 16:10 - 17:00 0.83 STWHIP P WEXIT M/U BHA #2 with 1.75 deg motor and Mill #1 RR, 2.80", HC, D331 diamond mill. Added orienter to BHA. 17:00 - 19:15 2.25 STWHIP P WEXIT RIH with milling BHA #2. Open circ sub. Pump 0.3 bpm, 800 psi while RIH. RIH to 11500'. Meanwhile held prespud mtg with D. Venhaus &nite crew covering scope, objectives, critical issues, risks & contingencies of 3M-29A DOCTD operations. 19:15 - 19:45 0.50 STWHIP P WEXIT Log GR tie-in @ GR spike from 11500' & add 8' to CTD. RIH & tag TOC @ 11550'. Close EDC. 19:45 - 20:45 1.00 STWHIP P WEXIT Orient to 165-180TF & backream to 11524' (original tag). Mill down to 11552' (TT). Repeat milling passes @ 4 different quadrant TFs to cleanout cmt patches. 20:45 - 21:35 0.83 STWHIP P WEXIT Orient to 180TF & drill pilot hole interval from 11552' to 11588' @ 1.6/1.6bpm, 4k WOB, 3200/3460psi & 40fph ave ROP. Cmt quality is considered good as ROP drops to <20fph @ 2~3k WOB. 21:35 - 21:50 0.25 STWHIP P WEXIT Orient to HS TF & drill 8' cement ramp to 11596' @ ' 1.6/1.6bpm, 3.5k WOB, 3200/3550psi & 30fph ave ROP. Didn't see much erratic TF expected with a mechanical orienter. 21:50 - 00:00 2.17 STWHIP P WEXIT Paint EOP flag @ 11500'. Open EDC & POOH with milling BHA #2 @ 1.6bpm, 2500 psi. 5/4/2002 00:00 - 00:10 0.17 STWHIP P WEXIT L/D milling BHA #2. 00:10 - 00:30 0.33 STWHIP P WEXIT P/U window milling BHA #3 with HCC 2.8" DP0064 DSM (with brass ring guide) & 2.5 degs fixed motor. 00:30 - 06:30 6.00 STWHIP P WEXIT Open EDC & RIH with window milling BHA #3 @ 0.3 bpm, 800 i Psi. Stack out @ almost every tbg connection from 4524' i(GLM) ~ orienting TF to rollover & fall thru. Continue working !BHA in hole to 8630 ft. 06:30 - 07:15 0.75 STWHIP P WEXlT Close EDC, pump min. rate of 0.2 bpm, RIH easily, no more tags. RIH to Flag and correct +9 ft CTD. 07:15 - 07:30 0.25 STWHIP P WEXIT Log down across GR marker at 11,500 ft. Correct +1 ft to CTD. Total corr. = +10 ft. Up Wt. = 21K, Dwn Wt. = 7K 07:30-10:00 2.50 STWHIP'P WEXIT RIH. Dry Tag PBTD at11596 ft. Pickup, Circl.5bpm. TFat 0 deg. Tag at 11595', correct to 11596 ft. Flag CT. Pick up 1 ft. Time mill window as per time schedule. Start time milling at 07:40 hrs, at 11595 ft. 1.5 / 1.5 bpm, 3330 ~si, TF = 0 deg. Milled to 11595.6'. 10:00 - 13:00 3.00 STWHIP P WEXIT Time Milling Window as per time schedule. TF = 5R, 1.5 / 1.5 bpm, 3300 psi, Printed: 5/20/2002 3:16:13 PM PHILLIPS PETROLEUM CO. Page 3 ~ Operations Summary Report Legal Well Name: 3M-29 Common Well Name: 3M-29A Spud Date: 1/20/1996 Event Name: REENTER+COMPLETE Start: 4/30/2002 End: Contractor Name: NORDIC CALISTA Rig Release: 5/16/2002 Rig Name: NORDIC 1 Rig Number: Date From -To Hours Task Code NPT Phase Description of Operations 5/4/2002 10:00 - 13:00 3.00 STWHIP P WEXIT 400-2200~WOB, Milled to 11597.1 ft. 13:00 - 14:30 1.50 STWHIP P WEXIT Time Milling Window. 1.5 / 1.5 bpm, 3380 psi, TF -- 5L, 2500# - 1800# WeB, Milled to 11,598.6 ft. WeB is decreasing indicating mill is past l half way point thru casing. 14:30 - 15:00 0.50 STWHIP P WEXIT Time Milling Window. 1.5 / 1.5 bpm, 3380 psi, TF = 5L, 1800 - 1200 # WeB, i Exit casing with mill at 11,598.8 ft. ITop of window at 11,596 ft, Bottom of window at 11,599 ft. 15:00 - 17:00 2.00 STWHIP P WEXlT IMilling Formation, 1.5 / 1.5 bpm, 3220 psi, Stacking wt. Drill with 4000-5000# WeB. Drilled to 11608 ft. Back ream clean. Lost 5 bbls to formation while Drilling formation. 3 bbls / hr. fluid loss. 17:00 - 18:55 1.92 STWHIP P WEXlT POOH for Taper mill to dress window. Stop at 10500 ft and perform flow check. No Flow. POOH to 500 ft. Close EDC & check for flow ~ no flow. POOH to surface. ~18:55- 19:15 0.33 STWHIP P WEXlT OOH. L/D window milling BHA #3. Wear on mill center indicates crossing csg wall. !19:15- 19:40 0.42 STWHIP P WEXIT iP/U window dressing BHA#4 with Baker cut-rite crayola mill& 1.75 degs motor. 19:40 - 21:50 2.17 STWHIP P WEXIT i Open EDC & RIH with window dressing BHA #4 @ 0.2 bpm, ; 560 psi. RIH to 11500'. 21:50 - 22:05 0.25 STWHIP P WEXIT Log GR tie-in @ GR spike from 11500' & add 8' to CTD. Clsoe EDC. 22:05 - 00:00 1.92 STWHIP P WEXIT ' Drift thru pilot hole @ 180TF & thru cmt ramp @ HS TF. Stack out @ window. PUH to 11588'. RBIH to 11594' & bring on pumps. Stall 3x @ 11596.5', lx @ 11597.7', 3x @ 11601.2', 2x @ & 11601.5' while reaming to btm @ HS TF, 1.5/1.5bpm, 3150/3600psi. Ream open hole to 11605'. 5/5/2002 00:00 - 02:30 2.50 STWHIP P WEXIT Ream to btm @ 11608.4'. Make several backream passes @ various TFs & dress window clean. Drift window without pumping 6x ~ OK. Meanwhile swap hole to recycled 8.7ppg Formate Fie-Pro mud & take-on 250bbls of 10.4ppg KWF into upright. 02:30 - 04:30 2.00 STWHIP P WEXIT Open EDC & POOH with window dressing BHA #:4 @ 0.8bpm, 1500 psi. IP/AP ~ 4135/3510psi. 3bph losses. POOH to 500 ft. Close EDC & check for flow ~ no flow. POOH to surface. 04:30 - 05:00 0.501 STWHIP P WEXIT OOH. L/D window milling BHA #3. Mill wear indicates successful dry passes. 05:00 - 05:15 0.25 DRILL P PROD1 Stab injector on well with UQC on. M/U & test drilling BHA #5 on catwalk. 05:15 - 05:30 0.25 DRILL P PROD1 PJSM for slack management. 05:30 - 06:00 0.50 DRILL P PROD1 R/U for slack management. 06:00 - 06:30 0.50 DRILL P PROD1 Crew change & pre tour safety meeting. 06:30 - 07:15 0.75 DRILL P PROD1 Reverse circ 2 CT volumes at max rate of 3.1 bpm at 3900 psi. for E-line slack management. Pumped 81 bbls. 07:15 - 08:30 1.25 DRILL P PROD1 M/U Coiltrak BHA #4 with 2.80 deg motor and 2.75" DPI Bit #5. Check BHA for electric continuity. OK. CIO 2" CT pack-off. 08:30 - 10:40 2.17 DRILL P PROD1 RIH. Pump full rate down CT thru open Circ sub. OK, still have continuity. RIH. 10:40 - 11:00 0.33 DRILL P PROD1 Log tie-in with RA marker at 11,500 ft. Added 11 ft to CTD. RIH, Orient to high side. Close EDC. Went thru window clean Printed: 5/2012002 3:16:13 PM PHILLIPS PETROLEUM CO. Page 4 ~ Operations Summary Report Legal Well Name: 3M-29 Common Well Name: 3M-29A Spud Date: 1/20/1996 Event Name: REENTER+COMPLETE Start: 4/30/2002 End: Contractor Name: NORDIC CALISTA Rig Release: 5/16/2002 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/5/2002 10:40 - 11:00 0.33 DRILL P PROD1 at 30R TF. 11:0L) - 11:30 '0.50 DRILL P PROD1 Drill build s~:tion. Tag TD at 11607 ft with pumps on. Drilling, TF = 5R, 1.5/1.5 bpm, 3400 psi, 120 fph, Drilled to 11632,,,fl/ and stalled motor. Fluid loss of 3 BPH. ~r Short in Coiltrak at stall. Pull up thru window. // ~11:30 - 14:30 3.00 DRILL N DFAL PROD1 CoilTrak has short. Pump bottoms up. Check surfac~ bulkhead for short. Bulkhead connection was dry./,3'hort is in BHA. POOH to check BHA. ~ 14:30 - 14:45 0.25 DRILL N DFAL PROD1 SAFETY MEETING. Reviewed CT cutting pr~edure and hazards. 14:45 - 18:00 3.25 DRILL N DFAL PROD1 At surface, lay out CoilTrak BHA. Foun/~/wet cable on BHA end of cable. Cut CT and E-Line until?rry, total of 32 ft. Re-head. Press test CTC. 18:00 - 18:40 0.67 DRILL N DFAL PROD1 M/U Coiltrack BHA. 2.80 deg rr~or and 2.75" Bit fi5. 18:40 - 20:40 2.00 DRILL N DFAL PROD1 Open EDC & RIH with drillin~g/BHA fi5 @ 0.1 bpm, 560 psi. RIH to 11500'. ~ 20:40-20:50 0.17 DRILL N DFAL PROD1 Log GR tie-in @ GR sp~e from11500' & add 9' to CTD. Upwt ~ 24k, Dn wt ~ 6k. ~r 20:50 -- 21'10 0.33 DRILL N DFAL PROD1 RIH thru window~HS without bobbles. Close EDC. S/D pumps & obi2 50psi but coming down. Hydrostat'~gure it takes a while for pre~ in gelled mud. RIH to btm. 21'10 - 22:20 1.17 DRILL = PROD1 Drill b~, .5/1.5bpm, 3125/3500psi, 3k DW,~ & 50f~ent motor stalls & ratty uild section 't /-93degs ~ncl @ TD & decided to OOH for lateral BHA. 22:20 - 23:20 1.00 DRILL = I PRODI~' Open EDC & POOH with drilling BHA fi5 @ 1.5 bpm, 2780 psi & following 650psi pressure schedule for POOH to minimize pressure swings on shales. POOH to 5600' & re-evaluate shale stability risk while changing out BHA. Decide to RBIH & circulate in KWF. 23:20 - 00:00 0.67 DRILL = PROD1 RBIH & start circ KWF @ 7600'. RIH to 11000'. 5/6/2002 00:00 - 00:15 0.25 DRILL P PROD1 Continue RIH to 11524'. .00:15 - 00:35 0.33 DRILL P ~ PROD1 Circulate 5 bbls of KWF out of EDC @ 1.5bpm 2400psi. 00:35 - 02:25 1.83 DRILL P~ PROD1 POOH with drilling BHA #6 circulating 1:1 & holding 50psi j WHP. 02:25 o 02:55 0.50 DRILL// P PROD1 OOH. L/D drilling BHA tis. Observe wear ring on bit gauge chamfer & backreaming cutters -,- explains ratty PlUs which may be due to piece of metal junk from the window. However no marks on other BHA component. 02:55 - 03:20 00.,~ DRILL ~ P PROD1 P/U lateral drilling BHA #7 with HYC 2.75" x 3.0" bi-center bit & .o0 1.1 degs motor. 03:20 - 05:20 DRILL P PROD1 Open EDC & RIH with drilling BHA #7 circ KWF @ 0.3 bpm, 185psi (suprisingly Iow). Can't confirm loss rate as MM out is / by-passed for taking returns to clean tigger tank. RIH to 11500'. 05:20 0.17 DRILL ~ PROD1 Log GR tie-in @ GR spike from 11500' & add 6' to CTD. Start .'~30 - swaping 10.4ppg KWF to 8.7ppg mud. Pumped a total of 170bbls of KWF. 05:45 0.25 DRILL ~ PROD1 RIH thru window @ HS without bobbles. Close EDC. RIH to btm. 05:45 - 07:15 1.50 DRILL ~ PROD1 Drill lateral @ 90-100TF, 1.5bpm, 3050/3350psi, 3k DWOB. Incl = 93.5 deg. 60 FPH. Drilled to 11,772'. Printed: 5/20/2002 3:16:13 PM 2002 STATE OF ALASKA ALASKA talL AND GAS CONSERVATION COMM~,.'SSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator Phillips Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1332' SNL, 1756' WEL, SEC. 25, T13N, R08E, UM At top of productive interval 2012' SNL, 3636' WEL, SEC. 35, T13N, R08E, UM At effective depth 2087' SNL, 3722' WEL, SEC. 35, T13N, R08E, UM At total depth 2129' SNL, 3770' WEL, SEC. 35, T13N, R08E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) RKB = 68' 7. Unit or Property Name Kuparuk River Unit 8. Well Number 3M-29 9. Permit Numbe~ 196-005 ',," 10. APl Number 50- 029-22641-00-- 11. Field and Pool Kuparuk River 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 11866 feet/ 6218 feet 11767 feet 6142 feet Length 121' 5827' 11856' Size 16" 9-5/8" 7" Plugs (measured) Junk (measured) Cemented 270 sx Arcticset I 1230 sx AS III, 730 sx Class 'G' 200 sx Class 'G' MD 121' 5827' 11856' TVD 121' 3421' 6211' Perforation depth: measured true vertical 11594'-11614' 6011'-6026' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 to 11530' Packers and SSSV (type and measured depth) Baker SAB-3' packer at 11503'; Camco 'DS' Landing Nipple at 514' 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation April 1, 2002 16. If proposal was verbally approved Name of approver Date Approved [] Detailed Operations Program [] BOP Sketch 5. Status of well classifications as: [] Oil [] Gas [] Suspended Service Contact Engineer Name/Number: Mark Johnson, 564-5666 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is triced correct to the best of my knowledge Signed ~'~// ,/ ,/~ / ~ . Title CT Drilling Engineer Date~////~/O . Mark Johnson ,,,//L...-[..,4//.,~. (,..,/. ~ ~----------- · . '. - ': i :· Plug integrity SOP Test ~ Lo'~;tion C~e~atran"~'"' I Approval No. Mechanical Integrity Test __ Subsequent form required 10- ~"~ Approved by orderofthe Commission Original Signed B~"~"i i~i;:,i~'~ i\: ,/~ I Commissioner Date Form 10-403 Rev. 06/15/88 tummy Uecl~sli [.~, '~; !~ ! ~" ~ ~' " ~ ~ '~- ~ ', ~---- Submit In Triplicate bp March 19, 2002 To: Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Attention: Subject: Tom Maunder Petroleum Engineer KRU 3M-29 CTD Sidetrack Prep BP Exploration Alaska Inc. Drilling & Wells Coiled Tubing Drilling Team KRU well 3M-29 is scheduled for a sidetrack to be drilled with coiled tubing. The following summarizes the procedure required to prep 3M-29 for drilling and is submitted as an attachment to Form 10-403. The new sidetrack 3M-29A will be a producing well. A schematic diagram of this proposed completion is attached. The cement P&A of 3M-29 will be performed by service coil as preparation for the CTD sidetrack. P&A Steps: 1. Slickline - Drift tubing and tag bottom. Dummy all GLMs. Pressure test inner annulus to 2500 psi. 2. Service coil tubing - P&A Kuparuk A-1 perforations by pumping - 15 Bbls of 17 ppg class G cement (7.1 Bbls for liner volume 11715'-11530', -5 Bbl behind pipe, Bbl cleanout excess). Squeeze to 1000 psi. Cleanout and target top of cement at 11530' at tubing tail (-66' above planned sidetrack KOP of 11596'). 3. Slickline - Tag TOC. PT cement P&A to 1000 psi. CTD Drill & Complete 3M-29A program: Planned for April 20~ 2002 (see drilling p ,ermits) 1) Mill 2.74" pilot hole and cement ramp for kickoffat 11596'. 2) Mill window through 7" at 11596' and mill 10' of openhole. 3) Drill 2.7x3' bicenter hole horizontal sidetrack 3M-29A from window to N13280' TD targeting Kuparuk A sand interval. 4) Complete with 2 3/8" pre drilled liner (4 holes per foot) from TD to -10 above tubing tail. 5) Post CTD rig - Bring on production. The service coil operations are expected to commence 4/1/02. Drilling coil is expected to begin the sidetrack drilling on April 20, 2002. Mark O. Johnso_ff/// CT Drilling En~feer 564-5666 office, johnsomo~bp.com 240-8034 cell KRU 3M-29A PROPOSED CT HORIZONTAL SIDETRACK ~Camco DS landing nipple 514' 9-5/8" Shoe @ 5827' 3-1/2",9.3#,L-80 Production Tubing to Surface 3-1/2" x 7" Baker SAB-3 Packer @ 11504' Top of 2-3/8" Liner @11520' (proposed) Tubing Tail~ @ 1153o' P&A Cement Top 11530' Perfs 11594-11614' ILast tag fill at 11715' 7" Shoe @ 11856' Mill Window in 7" Casing @ 11596' 3" Open hole 0000 000© 0000 7" Liner & Perfs P&A'd with 17.0 ppg Cement / 2-3/8" STL 4.6# pre drilled liner 4 holes per foot TD @ 13280' MOJ 3/19102 PHILLIPS Alaska, Inc. A Subsidiary o1' PHILLIPS PETROLEUM COMPAHY NIPPLE (514-515, OD:3.500) Gas Lift MandrelNalve 1 (4502-4503, OD:5.390) Gas Lift MandrelNalve 2 (8264-8265, OD:5.390) Gas Lift MandrelNalve 3 (10190-10191, OD:5.390) Gas Lift Mandrel/Dummy Valve 4 (10925-10926, OD:5.390) Gas Lift Mandrel/Dummy Valve 5 (11248-11249, OD:5.390) Gas Lift MandrelNalve 6 (11449-11450, OD:6.018) NO GO (11495-11496, OD:3.500) SEAL ASSY (11503-11504, OD:3.500) NO GO (11520-11521, OD:3.500) TUBING (0-11530, OD:3.500, ID:2.992) SHEAR OUT (11529-11530, OD:3.500) Perf (11594-11614) .__ KRU 3M-29 APl: SSSV Type: Annular Fluid: Reference Log: Last Tag: Last Tag Date: 500292264100 Camco 'DS' Landing Nipple 11707 11/23/00 Well Type: Odg Compltn: Last W/O: Ref LOg Date: TD: Max Elole pRoD 1127196 Angle @ TS: Angle @ TD: 42 deg L~ 11592 40 deg @ 11866 Rev Reason: Tag Update; JWP. Last Update: 12/18/00 11866 ftKB 68 deg @ 7829 Angle: Description J Size J Top Bottom I TVD J. Wt ] Grade J Thread CONDUCTOR I 16-0001 0l 1211 121 62.58 H-40 I SURF CAS~NG 19.625t 01 58271 3422 36.00 J-55 I PRODCASING 17.0001 01 118561 6211 26.00 J-5 I Tdbifig~iiSt'i~i.~g~S';i~!All::~ i i:I'.: '~ :: ::~ ~!::::~ :: : ' · -...i Isize I Top J J TVD J Wt Grade I Thread TUBING 115301 59641 9.30 I L-80 IEUEORDAB ' I I J IMOD Interval 'i'VD I Zone I statusl Ft ISPFI Date I Type I comment 11594 - 6012 - 6027 I A-1 I 20 4 5/3/96 IPERF 2 1/8" EnerJet, 180 deg 11614 I ph; Odented 90 deg CW I I I I I I I& CCW F/Low GaSLifi~Mahdrel~alves~ : :... ~ ~:-;; : St MD ~Di Man Man V Mfr V Type V OD Latch Port TRO Date Vlv I Mfr I Type Run Cmnt 1 145°2128731Camc°1 KBMMI I GLV I 1'°1 BK 10.15~113411 6/4/96I 2 /8264143911CamcoI KBMMI I GLV I 1-01 BK 10.156113421 6/4/96I 3 110190l 51931Camcol KBMM t I GLV I 1.0 I BK I 0.250 114831 6/4/96 I 4 I1092515564Icamcot KBMM I I DMY I 1.0 I BE-5 10.0001 0 14/19/96 I 5 j11248J57701Camcoj KBMM J I DMY I 1.0 IBK-5J0.0001 0 14/19/96J 6 ~114491 59O51 Camco I MMM I I OV I 1.5 IRK ] 0.250 I 0 I 6/3/96 I Otheri(plugs;: equiP,, DepthI TVD Type 514 15131 NIPPLE 11495159381 NOGO 1150315944 I SEAL I IAsSY 11504159451 PKR 115201 5957 I NO GO 115291 5~631 SHEAR I I°UT 115301 5964 I TUBING I I TAIL GeneraINotes : · Date Note 7/1/99 SBHP = 1043 psi. ~tc,). JEWELRY Description Camco 'DS' Landing Camco ~/V' Nipple Baker 'KBH-22' Baker 'SAB-3' Hyd. Camco 'D' Nipple Baker 2.812 3.250 3.250 2.750 2.992 2.992 Johns(~n, Mark 0 From: Sent: To: Cc: Subject: Tom Maunder [tom_maunder@admin.state.ak. us] Thursday, March 07, 2002 4:53 PM Dan Venhaus JohnsoMO@bp.com; Michael B Mooney; R Marty Lemon Re: KRU permits to BP office Card for Tom Maunder Thanks Dan, this will do just fine. Dan Venhaus wrote: Tom, The Kuparuk CTD program starting up in April consists of 3 wells: 3H-16A, 3C-04A, and 3M-29A. Well 3H-16A's permit was submitted by Phillips and has been approved. This well is a combination rotary/CTD sidetrack with the rotary part completed in November 2001 with Phillips' Nordic 3 rig. Wells 3C-04A, 3M-29A (and the 3H-16A extension) are to be drilled solely with BP's Nordic 1 CTD unit. BP's CT drilling services are being provided to the operator Phillips via a Shared Service operation. As such, Phillips authorizes the delivery of 3C-04A and 3M-29A permits to BP (Terry Hubble). Phillips does request that BP provide a copy of the approved permits. If you need anything else, let me know. Dan Venhaus Phillips Alaska, Inc. CT Drilling Engineer 263-4372 work 230-0188 cell Forwarded by Dan Venhaus/PPCO on 03/07/2002 02:36 PM "Johnson, Mark O" <JohnsoMO@BP.com> 03/06/2002 07:14 AM To: Dan Venhaus/PPCO@Phillips CC: Subject: KRU permits to BP office Dan, I was talking to Tom Maunder this morning. It does not look like he can make a DOCTD meeting today and he will get back with me on an alternate date. Tom needs a e-mail from you authorizing delivery of the Phillips operated well permits to the BP office (even though they originated from me) Content 1) Please send KRU CTD sidetrack permits to BP office (normal Terrie Hubble address) 2) Background on why they need to go to BP. (CTD is a shared service (BP & Phillips) with the rigs operated by BP, but sidetracking KRU wells.) 3) Three well program in 2002 (list well names). 6 5 4 2 COILED 'I'UBINI3 UNIT BOP EOUI PHENT 1. ~000 PSi ?" WELLHCAD CONNECTOR FLANGF. 2. 5000 PSI 4 1/16" PiP[ RA)d$ 3. 50(0) PSI 4 1/6" HYT)FLaJJLIC: SLIPS 4. 5000 PSt 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAkIS 6. 5000 PSI 4 1/16" STUrrINO BOX . . . ..... I.__ 2 I I imm H]REL]NE BOP EOUIPMENT i i i 1. 5000 PSI ?" W£LLH~a~) C;C)NNECIOR rL^~C; 2. 5000 PSi WIRELINE RAMS (VARIABLE SIZE) .1. 5DDO PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/(~" fLOW TUBE P^C:K-orr Kuparuk Shged Services Subject: Kuparuk Shared Services Date: Wed, 20 Mar 2002 13:51:30 -0600 From: "Hubble, Terrie L" <HubbleTL@BP.com> To: "Tom Maunder (E-mail)" <Tom_Maunder@admin.state.ak.us>, "Jody Colombie (E-mail)" <jody_colombie~admin. state.ak.us> CC: "Steve Davies (AOGCC) (E-mail)" <steve_davies~admin.state.ak.us> Hi Tom & Jody, I apologize... I did forget to include my little notice at the top of the 10-403 for 3M-26 and 10-401 for 3M-26A to return the approved documents to BP. Additionally, I just noticed that I included the BP Bond number on the 10-401 instead of the Phillips Bond #(59 52 180). This caused me to check the other Kuparuk Permits that we have submitted. I submitted a 10-403 yesterday for 3M-29 and this one too needs the note at the top to return approved documents to BP. Obviously, I am having trouble remembering to treat these permits differently and again I apologize for my errors. By they time I get it drilled into my memory, we'll probably be done with this program at Kuparuk! BP's CT drilling services are being provided to the operator Phillips via a Shared Service operation. If you have any questions regarding this please contact Dan Venhaus at Phillips, 564-4372. Thanks! Terrie Hubble GPB Drilling & Wells 564-4628, MB8-1, Cube 830 , ^~ 1 3/20/02 11:09 AM THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON-OR' BEFORE JANUARY 03,- M PL A T E IA L E U 2001 W N~ D E R T H ISM A R K E R C:LORBMFILM.DOC ' PERMIT 96-005 96-005 96-005 DATA CDR 7208 CDR 10 -407 DAILY WELL OPS AOGCC Individual Well Geological Materials Inventory T DATA PLUS JSEPIA ,-.a~'COU~TZO~ DATE _p/~ / ~/ ~ )/~/~/ TO .~'/~ /~/ Page: 1 Date: 05/13/98 RUN DATE RECVD 1 04/26/96 04/11/96 04/11/96 ~1 la~ ~/ ~ //~ /¢~ / Are dry ditch samples required? yes ~~And received? Was the well cored? yes ~~alysis & description received? Are well tests required? yes ~~eeeived? Well is in compliance Initial COMMENTS yes ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 9, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3M-29 (Permit No. 96-005) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3M-29. If there are any questions, please call 263-4622. Sincerely, 'W. Isaacson Drilling Engineer Kuparuk Drill Site Development WSUskad RECEIVED AUG 1 2 1996 Alaska 011 & ~.~ Oon,~, ~.mm~io~) STATE OF ALASKA ALA5KA OIL AND GAS CONSERVATION COMM,dSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~] GAS ~ SUSPENDED [~ ABANDONE[~ SERVICE [---'] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 96-005 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 ~.~.r.~} 50-029-22641 4 Location of well at surface l,m~ 9 Unit or Lease Name ~ ~ ~;'. Kuparuk River Unit 2013' FNL, 1645' FVVL, 8ec.35, T13N,R8E, UM .~ i,/[~lF~;:,, i .¢ _,..~ [ 3M-29 2127' FNL, 1510' FWL, Sec. 35, T13N, R8E, UM ................... ~.~:i'_~ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. Rig RKB 41' Pad 27' ADL25523 ALK2559 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if o~hore 116 No. oi Completions 19-Jan-96 25-Jan-96 03-May-96 (perf'd) NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set I 21 Thickness of permafrost 11866' M D & 6218' TVD 11767' M D & 6142' TVD YES X~J NO ~ NA feet MD[ = 1380' ss APPROX 22 Typo Electric or Other Logs Run GR/CDR/ 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.58# H-40 SURF. 121' 24" 270 sx AS I 9.625" 40.0# L-80 SURF. 5827' 12.25" 1230 sx AS III Lead, 730 sx Class G Tail 7" 26.0~ L-80 SURF. 11856' 8.5" 200 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET IMD) 3.5" 11530' 11503' 11594'-11614'MD 4spf 6011'-6027'TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11594'~11614' I1904# total fluid & 203437# prop (12855# 20/40, 174467# 12/18 & 16115# 10/14) 27 PRODUCTION TEST Date First Production IMethod of Oporalion (Flowing, gas lift, etc.) 06-6-96I Flowin~ Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL cHOKE SIZE I GAS-OiL RATIO 7/9/96 4 TEST PERIOD I~ 1 8 8 303 4 176I 1613 Flow Tubing ICasing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 390 845 24-HOUR RATE I~ 1127 1817 24 =24° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED AUG 1 2 199~ Alaska 011 & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 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 Kuparuk C 11592' 6010' Top Kuparuk A 11592' 6010' Freeze protect annulus 31. LIST OF ATTACHMENTS Daily Drilling History, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date' 6/17/96 ARCO ALASKA INCORPORATED WELL SUN, MARY REPORT Page: 1 WELL:3M-29 RIG.PARKER 245 WELL ID: AK8413 AFC: AK8413 TYPE' -- STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:01/19/96 START COMP: BLOCK: FINAL: WI' 55% SECURITY'0 AFC EST/UL:$ OM/ 1690M API NUMBER: 50-029-22641-00 01/20/96 (1) TD: 1461' (1461) SUPV:RLM DAILY: 01/21/96 ( 2} TD: 4942' (3481) SUPV:RLM DAILY: 01/22/96 (3) TD: 5837' (895) SUPV:RLM DAILY: 01/23/96 (4) TD: 5837' ( 0) SUPV:RLM DAILY' 01/24/96 (5) TD: 9953' (4116) SUPV:RLM DAILY: 01/25/96 ( 6) TD: 11620' (1667) SUPV: RLM DAILY: 01/26/96 ( 7) TD:11866' (246) SUPV:RLM DAILY: 01/27/96 { 8) TD:11866' ( 0) SUPV:RLM DAILY: MW: 9.3 PV/YP: 21/22 APIWL: 12.8 DRILLING Move rig. Accept at 1330 hrs. 1/19/96. Spud at 1800 hrs. Directional drill from 121' to 1461' $99,455 CUM: $99,455 ETD- $0 EFC: $99,455 MW: 10.1 PV/YP: 24/28 APIWL: 6.2 POOH FOR WASHOUT Directional drill from 1461' to 4942'. Lost 1200 psi, check all surface equipment. POOH wet looking for washout. $80,633 CUM: $180,088 ETD' $0 EFC' $180,088 MW: 10.0 PV/YP: 20/22 APIWL: 5.2 POOH TO RUN CASING Change bit and RIH. Directional drill from 4942' to 5837' More oil than usual in the Ugnu and West Sak formations. Circ and condition mud prior to running casing. POOH. $80,653 CUM: $260,741 ETD: $0 EFC: $260,741 MW: 10.0 PV/YP: 18/16 APIWL: 7.2 MAKE UP BHA Held pre-job safety meeting. Run 9-5/8" casing. Cement casing, CIP at 1950 hrs. 1/22/96. Test all lines and valves, rams and hydril to 300/3000 psi. Make up BHA. $246,950 CUM: $507,691 ETD: $0 EFC: $507,691 MW: 9.2 PV/YP: 7/ 3 APIWL: 8.8 DRILLING Test casing to 2000 psi for 30 minutes. Drill cement, float collar at 5739, cement, float shoe at 5827' and 10' new hole to 5847'. Perform FIT to 12.5 EMW. Directional drill from 5847' to 9953' $78,964 CUM: $586,655 ETD: $0 EFC: $586,655 MW' 10.7 PV/YP: 14/ 9 DRILLING Directional drill from 9953' to 11620' -- $93,173 CUM: $679,828 ETD: $0 EFC: AP IWL: 5.2 $679,828 MW: 10.8 PV/YP' 20/15 APIWL: 4.6 RUNNING 7" CASING Directional drill from 11620' to 11866'. Held pre-job safety meeting. Run 7" casing. $202,719 CUM: $882,547 ETD- $0 EFC: $882,547 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 LAY DOWN DRILL PIPE Continue running casing to 11856. Cement casing, CIP at 1513 hrs. 1/26/96. Freeze protect annulus. $111,896 CUM: $994,443 ETD: $0 EFC: $994,443 Date' 6/17/96 ARCO ALASKA iNCORPORATED WELL SUHHARY REPORT Page: 2 01/28/96 ( 9) TD'11866' ( 0) SUPV:RLM DAILY: MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Finish lay down 5" drill pipe and release rig at 0800 hrs. 1/27/96. $6,892 CUM: $1,001,335 ETD: $0 EFC: $1,001,335 RECEIVED AUG 1 2 1996 Alaska 011 & r~as Cons. ~mmi~ion Anchorage Date: 6/17/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 3 REMEDIAL AND COMPLETION OPERATIONS WELL:3M-29 RIG:PARKER 245 WELL ID: AK8413 AFC: AK8413 TYPE- STATE.ALASKA AREA/CNTY- NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:01/19/96 START COMP: BLOCK' FINAL: WI: 55% SECURITY:0 AFC EST/UL:$ OM/ 1690M API NUMBER: 50-029-22641-00 04/18/96 (10) TD:11866' PB:11767' SUPV:DEB DAILY: 04/19/96 (11) TD:11866' PB:11767' SUPV:dLW DAILY: 04/20/96 (12) TD:11866' PB:11767' SUPV:dLW DAILY: N/U TEST BOP & LOAD TBG MW: 8.5 Accept rig @ 0100 hrs. 4/18/96. N/D tree. N/U BOP's function test. SW $26,500 CUM: $1,054,335 ETD' $0 EFC' $1,054,335 SET BAKER PKR @ 11504' MW: 0.0 Test 7" casing to 3500 psi for 15 min. OK. Run 3.5" tbg w/jewelry. M/U hanger, drop ball, pump out stack and land tubing. Circulate ball down pressure up to 2500 psi on tbg set Baker packer @ 11504', hold pressure @ 2500 psi for 30 minutes, OK. $136,719 CUM: $1,327,773 ETD: $0 EFC: $1,327,773 RIG RELEASED MW: 0.0 After setting Baker packer @ 11504' and tubing test to 2500 psi, bleed pressure back to 500 psi. Pressure up on 7" x 3.5" annulus to 2500 psi for 15 min. OK. N/d BOP's, N/U tree test 250-5000 psi. OK. Secure well. Release rig @ 1030 4/19/96. $8,809 CUM: $1,345,391 ETD: $0 EFC: $1,345,391 End of WellSummary for Well:AK84i3 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '' K1(3M-29(W4-6)) WELL JOB SCOPE JOB NUMBER 3M-29 PERFORATE, PERF SUPPORT 0501961240.1 DATE DAILY WORK UNIT NUMBER 05/03/96 PERFORATE A SAND DAY OPERATION COMPLETE SUCCESSFUL IKEY PERSON SUPERVISOR 1 YES YES I SWS-WARN ER GOLDEN '- lh~l'Tb~press-i--FTi~'lTbgPress il-ni~iaiinnerAnn IFinal inner Ann ilnitialOuterAnn I Final Outer Ann 0 PSI 200 PSI 0 PSI 200 PSI 0 PSI 100 PSI DAILY SUMMARY PERFORATED A SAND 11594'-11614' ( 4 SPF, 180 DEG PHASING, 90 DEG CW & CCW F/LOW SIDE). TIME 15:00 15:45 16:45 18:45 19:45 20:50 21:3O , , LOG ENTRY MIRU SWS & HOT OIL. PT LUBRICATOR TO 3500 PSI. RIH W/GR, CCL, 20' 2-1/8" ENERJET (2 SPF, 90 DEG CCW F/LOW SIDE, BIG HOLE CHARGES) STOPPED FALLING AT 9300'. ESTABLISHED INJECTION AT 1 BPM (TAKING RETURNS UP BACKSIDE). PUMPED 5 BBL OF DSL. ABLE TO GET GUN MOVING DOWNHOLE. TIED INTO CDR DATED 1/25/96. TBG TAIL LOCATED AT 11552' BASED UPON CDR. WHP (BEFORE) = 30 PSI, PERFORATED 11594'-11614', WHP (AFTER) = 30 PSI.POOH. ASF, PT LUBRICATOR TO 3500 PSI.RIH W/CCL, 20' 2-1/8" ENERJET (2 SPF, 90 DEG CW F/LOW SIDE, BIG HOLE CHARGES) STOPPED FALLING AT 9340'. A I1EMP/P__D TO PUMP INTO WELL (BACKSIDE SHUT IN). WELL PRESSURED UP TO 2500 PSI- NOT TAKING ANY FLUID. ABLE TO GET GUN MOVING MOVING DOWNHOLE.TIED INTO CDR DATED 1/25/96. WHP (BEFORE/ = 50 PSI, PERFORATED 11594'-11614', WHP (AFTER1 = 50 PSI.POOH. ASF. Al I EMPT~D TO PUMP INTO WELL. WELL PRESSURED UP TO 3000 PSI (NOTTAKING FLUID). SD PUMP MONITORED WHP FOR 10 MIN- WHP BLED TO 2100 PSI. BLED WHP TO ~'FRO - BUILT BACK TO 200 PSI IN 10 MIN. RD SWS & HOT OIL. PAGE NO, *********** SUR~EY PROGRAM COMPANY ARCO ALA$1A~ INC, WELL NAME 3M-29 LOCATION I [UPARU[ COCATION 2 ACA$~A MAGNETIC DECLINATION 27.85 GRID CONVERGENCE ANGLE 0.00 DATE: 25-JAN-96 WELL NUMBER 29 AFE A~8413 API WELL NO: 50-029-22641-00 WELL HEAD LOCATION: LAT(N/-S) 0.00 AZIMUTH FROM ROTARY TABLE TO TARGET IS TIE IN POINT(TIP) : MEASURED DEPTH 121.00 TRUE U£RT DEPTH 121.00 INCLINATION 0.00 AZIMUTH 0.00 LATITUD£(N/-S) 0,00 DEPARTURE(£/-W) 0,00 D£P(E/-W) 230.33 0,00 3M-29 ************* ANAORILL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC MEASURED INTERVAL VERTICAL O~PTH DEP?H ft ft ft 121.00 0,0 121.00 171.00 50.0 171.00 256.00 85,0 255.99 349,00 93.0 348,93 467.14 118,1 466.65 TARGET STATION AZIMUTH LATITUDE SECTION INCLN, N/-S 0,00 0.00 0,00 0,00 0.33 0.75 236.00 -0.18 1.79 1,25 219.00 -1,21 5,00 2,75 224.00 -3o61 14.59 6,58 230,53 -9,95 DEPARTURE DISPLAC£H£NT at g/'W 0,00 0.00 -0.27 0,33 -1o32 1.79 -3,50 5,03 -I0.70 14.62 AZIMUTH 0.00 236.00 227,29' 224,16 227,08 DLS deg/ lOOft 0.00 1.50 0,68 1,62 3,27 555,08 87,9 553,74 652.21 97.1 649.15 744.44 92.2 738,81 836.16 91.7 826.54 928,20 92,0 912,24 26.70 9,29 236.10 -17,12 44,82 12.28 233.02 -27.70 66,37 14,82 235.18 -40.34 93,02 19.02 231,91 -56,27 126,47 23,66 227,32 -78.05 -20,49 26.70 230,12 3.20 -35.25 44.83 231.83 3.13 -52,77 66,42 232.60 2,81 -74,18 93.10 232,82 4,70 -99.57 126,52 231.91 5,35 1005.04 1098.17 1191.50 1285.76 1379.32 76.8 981,71 93,1 1063,85 93.3 1145.07 94.3 1226,27 93.6 1304.93 159.27 26,92 228.69 -100,00 203,13 29.30 230,03 -128o55 249,09 29,74 232,91 -157,19 296,94 31,33 232.48 -186.21 347.55 34,22 230,96 -217.60 -123.98 159,28 231,11 4.31 -157.28 203,14 230,74 2,65 -193,25 249,11 230,88 1,59 -231.34 296.97 231.17 1.70 -271,06 347.60 231,24 3,21 1469.95 1565.92 1659.53 1753.66 1848.37 90,6 1378,99 96,0 1454,24 93.6 1523.91 94.1 I592,61 94,7 1661,87 399.76 36,14 231,01 -250.47 459,29 40,56 231,23 -287,83 521.79 43.23 231,59 -326.82 586,12 43,02 231,93 -366,65 650.70 42,98 231,17 -406.81 -311.63 399.81 231,21 2,13 -357.98 459.35 231o20 4,61 -406,85 521,86 231,23 2,86 -457,39 586,20 231,28 0,34 -507,97 650,79 231,31 0,55 1941.92 2035.97 2130.50 2223.04 2317.98 93.6 1728,99 94.0 1791.99 94,5 1849,05 92.5 1899.67 94.9 1946,55 715,85 45.32 230,92 -447,78 785.64 50.54 231.12 -491.67 860,96 55.17 230,68 -539,18 938.42 58.50 231.10 -588.04 1020,94 62,3I 231,81 -639.47 -558.65 715.95 231,29 2.51 -612.90 785.74 231,26 5,55 -671.36 861,07 231,23 4,92 -731,46 938,53 231,20 3,61 -796,02 I021,06 231,22 4,07 2502,80 2686.19 2968,86 3251,31 3528,74 3809,47 4088,34 4371,72 4650,67 4928.30 164,8 2029,46 183,4 2109,30 282.7 2227,97 282.5 2342,54 277.4 2459,64 280,7 2581,80 278.9 2701,24 283.4 2820,07 278,9 2933.09 277,6 3045.21 1186.06 64.36 231.43 -742,01 1351,13 64,03 231,64 -844.72 1607.60 66.32 231,52 -1004.I5 1865,65 65,82 232,58 -1162,91 2116,93 64,25 232.81 -1315o32 2369,54 64.16 231,68 -1470.07 2621.50 65.12 230.74 -1627.95 2878,76 65.30 230,13 -1791,80 3133.70 66,90 228,03 -1958,85 3387,54 65,46 228,85 -2127.36 -925,49 1186.22 231.28 -1054,76 1351.33 231,31 -1255,74 1607.85 231.35 -1459.31 1866,00 231,45 -1659,37 2117,44 231,60 -1859,21 2370,I9 231,67 -2055.62 2622,17 231.62 -2253.95 2879,38 231,52 '2446,61 3134,16 231.32 '2636,64 3387,85 231,10 1,13 0.21 0,81 0,39 0,57 0,37 0,46 0,20 0,90 0.59 5209,89 5491,49 5751.75 5965,98 6243,25 281,6 3162.39 281,6 3280,81 260.3 3389,90 214,2 3480,50 277.3 3592,92 3643.43 65.36 227,84 -2297,54 3898,85 64.91 230.94 -2463,82 4135.05 65,53 232.78 -2609,74 4329.07 64.43 231,64 -2728,69 4582,33 67.72 232,95 -2883.63 -2827,94 3643,61 230.91 -3021,87 3898,98 230,81 -3207,71 4135,23 230,87 -3361,12 4329,31 230,93 -3561,65 4582,65 231,01 0,33 1,01 0.68 0,70 1,26 P~6£ MEASURED !HTERUAL VERTICAL TARGET STATIOH AZIMUTH LATITUDE DEPTH OEPTH S£CTIOH I~CLN. ft ft ft ft de~ de9 ft 6525.12 281.9 3701.61 4842.29 66,92 230,85 -3044.08 6806,45 281.3 3812,94 5100,62 66,46 228.46 -3211.32 7175,66 369.2 3959,62 5439.38 66.73 232,29 -3427,34 7454,85 279,2 4066.86 5696,16 67.19 232,02 -3564,96 7829,13 374,3 4212,02 6041,88 67,85 231,56 -3798.87 8200,78 8573,97 8951.70 9326,59 9698,73 10072,40 10260.93 10354,86 10443,43 10539,70 10631,16 10725,34 I0817,43 10912,37 11005.01 11099,23 11193,31 11287.50 11377,31 I1468.00 11550,29 11739,06 11790,50 11866°00 371,7 4363.01 6381,38 64,20 230.23 -4012,99 373.2 4527,94 6716.13 63,34 229,48 -4226.81 377,7 4693,06 7055,60 64,81 229.42 -4449.66 374,9 4846,79 7397,60 66.77 228.52 -4674,12 372,1 4992,04 7739,78 67.29 226,39 -4905,78 373,7 5143,37 8080,15 64.93 224.5I -5145,40 188,5 5223.04 8250,07 65,08 224,08 -5267.71 93,9 5262.91 8334,86 64,70 228,06 -5326,70 88,6 5302.15 8414,21 62,70 228,49 -5379,55 96,3 5347.80 8498.95 60,70 230,45 -5434.63 91,5 5394,26 6577,72 58.24 230,66 -5484,68 94,2 5445,79 8656.54 55,41 231.19 -5534,37 92,1 5499.08 8731.64 53.87 230,64 -5581,71 94,9 5555,76 8807,78 52.78 231,00 -5629.82 92,6 5613,41 8880,29 50.28 231.57 -5675,19 94,2 5673.73 8952.68 50,12 229,92 -5721,00 94.1 5734,06 9024.86 50,09 228.99 -5767,93 94.2 5795,11 9096,54 49,10 228,22 -5815,34 89,8 5855,03 9163,41 47,20 228.84 -5859.65 90,7 5918,49 9228,16 43.95 229.97 -5901.80 82,3 5978.72 9284.24 41,97 229.28 -5938.13 I88,8 6120.85 9408.42 40.33 228.90 -6019,46 51.4 6160,19 9441.54 39,88 229,12 -6041,19 PROJECTED TO TO - 75,5 6218,13 9489,95 39,88 229,12 -6072,88 3M-29 DEPARTURE DISPLACEMEH? at E/'W ft ft -3766.31 4842.67 '3963,22 5100.95 -4224,16 5439.69 -4427,05 5696,55 -4698,78 6042,35 AZIMUTH de9 231,05 230,98 230,95 231,00 231,05 -4962.27 6381,87 231,04 -5218,18 6716,56 230,98 -5476.30 7056,16 230,91 -5734,20 7397,87 230,82 -5986,6! 7739,91 230,67 -6230.08 8080.17 230,45 -6349,40 8250,07 230,32 -6410.64 8334.87 230.28 -6469,90 8414.22 230,26 -6534,30 8498,96 230,25 -6595.13 8577,73 230.25 -6656,32 8656,55 230,26 -6714,62 8731.64 230.26 -6773.63 8807.78 230.27 -6830.22 8880,30 230.28 -6886,27 8952,69 230.28 -6941.12 9024,86 230.27 -6994,92 9096.55 230.26 -7045,05 9163,42 230,25 -7094.21 9228,17 230,24 -7136.94 9284,25 230.24 -7230.82 9408.43 230,22 -7255.83 9441,56 230.22 -7292,43 9489,96 230,21 deg/ lOOft 0,74 0,80 0,96 0,19 0,21 1,03 0,29 0,39 0.56 0,55 0,22 3,87 2,30 2,74 2,69 3.04 1,75 1,19 2,74 1.36 0,75 1,23 2,18 3,69 2,47 0.88 0,91 0,00 ARCO Alaska, Inc. Date' April 1 8, 1996 Transmittal #' 9358 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 hole items. Please acknowledge receipt and return one signed copy of this transmittal. 3M-29 CDR 01/25/96 ~~-~'~ r),¢- ARC,5~ ¢~' 12/28/95 Acknowledged .~~/~ DISTRIBUTION' 50-029~22641-00 5742-10295 Date: ,~(0 ~¢ ¢'J~ Mr. Vernon E. Pringle Jr. DeGIoyler and MacNaughton One Energy Square Dallas, TX 75206 Sharon AIIsup-Drake DS Development ATO - 1205 Clifton Posey Geology ATO - 1251 ChapmanZu~pan NSK Wells Group NSK 69 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10124 Company: 4/1 1/96 Alaska Oil & Gas Cons Comm Attn- Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape 3M-29 96058 CDR 960125 I 1 1 3Q-22 96008 ARC5 951 228 I I I SIGNED- Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ALASK OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 January 12, 1996 Michael Zanghi, Ddll Site Develop Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3M-29 ARCO Alaska, Inc. Permit No 96-005 Surf Loc. 1332'FNL, 1756'FEL, Sec. 25, T13N, R8E, UM Btmhole Loc. 2094'FNL, 1519'FWL, Sec. 35, T13N, R8E, UM Dear Mr. Zanghi: 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 conta~m-~io,n petroleum field inspector 659-3607. David W. Johnston Chairman \ · BY ORDER OF THE. '" COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl : : ]. ,STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 /LAC 25.005 la. Type of Work Drill X Redrill r=l i b Type of Well Exploratory D Stratigraphic Test [--~ Development Oil X Re-Entry [~] Deepen [--~ Service [~ Development Gas D Single Zone X Multiple Zone [-1 2, Name of Operator 5, Datum Elevation (DF or KB) 10, Field and Pool ARCO Alaska, Inc. RKB 41', Pad 27' feet Kuparuk River Field 3, Address 6. Properly Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25523, ALK 2559 4. Location of well at surface 7, Unit or property Name 1 1, Type Bond (see 2o AAC 25,O25) 1332' FNL, 1756' FEL, Sec. 25, T13N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1965' FNL, 1674' FWL, Sec. 35, T13N, RSE, UM 3M-29 #U-630610 At lotal depth 9, Approximate spud date Amount 2094' FNL, 1519' FWL, Sec. 35, T13N, R8E, UM 1/15/96 $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 3M-22 11897' MD 1519 @ TD feet 11.6' @ 200' feet 2560 6249' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 65.82° Maxirnumsurface 2023 psig At total depth (TVD) 3450 pslg 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length IVD 'rVD IVD TVD (include stage data) 24' 16' 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 12.25" 9.625" 40.0# L-80 BTC 5811' 41' 41' 5852' 3418' 1230 Sx Arcticset III & HF-ERW 730 Sx Class G 8.5' 7' 26.0# L-80 BTCMO£ 11856 41' 41' 11897' 6249' 150SxClassG 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 ~, ~.'.~ V. D Surface Intermediate Production LinerJAN 04 Perforation depth: measured true verticalAlaska Oil & Gas Cons, Commission An~hora0e 20. Attachments Filing fee X Property plat D BoP Sketch X Diverter Sketch X D~lling program X Drilling fluid program X Time vs depth plot I--! Refraction analysis i--~ Seabed report r-I 20 AAC 25.050 requirements X 21, I hereby ce,~~7 ../~that the.~ going is true and correct to the best of my knowledge Signed /VI~ ~,,~ Title Drill Site Develop. Supv. Date · \ [ Commission Use On~ Perrrdt Number APl number I Approval date I See cover letter for ~'/~ ' (~O,~' '~' I 50- ~).~-~,~-.~.--2- ~' ~ / /--- /"~..,- ?(,,,~ other requirements Cor~ditionsof approval Samples required r'~ Yes J~ No Mud logrequired D Yes [] No Hydrogen sulfide measures ,[~ Yes D No Directional survey required ,~ Yes r~ No Required working pressure for BOPE E] 2M [] 3M D 5M D 10M D 15M Other: ur ginal Signed By Approved by Oommissioner the commission Date Form 10-401 Rev. 7-24-89 ~ ,. il{ in triplicate · · . . . . , . 10. 11. 12. 13. 14. 15. 16. 17. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3M -29 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5,852')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE to 3000 psi. 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 (11,897') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing string. (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.) ND BOPE. NU tubinghead & either full opening valve (if logging planned) or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Run completion assembly. Set packer and pressure test tubing and annulus. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well KRU 3M-29 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casin~t 9.0-10.0 15-25 15-35 50-80* 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 General Notes: Weight up to TD 11.5 10-18 8-12 35-50 2-4 4-8 4-5 through 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 2,023 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3M-29 is 3M-22. As designed, the minimum distance between the two wells would be 11.6' @ 200' MD. Drillin~l Area Risks: , Risks in the 3M-29 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 7" casing will be topset above the Kuparuk and Nordic Rig #1 will drill out a 6-1/8' hole, and run a 5" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.5 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. JAN 04- ~96 ANNULAR PUMPING OPERATIONS WELL KRU 3M-29 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 an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3M-29 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 3M-29 be permitted for annular pumping occurring as a result of the drilling project on DS 3M, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 3M surface casing shoes will be set +_200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure - (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi 3M-27 Max Pressure = 3640 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 9.625 40 L-80 3 BTC 3090 2627 5750 4 8 8 8 7.000 26 L-80 3 BTC-M 5410 4599 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associat?~wi~h drilling a well as defined in 20 AAC 25.254 (g) (1). ARCO ALASKA, Inc. Pad 3M 29 slot #29 Kuparuk River Unit North Slope, Alaska CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 29 Version #5 Our ref : prop1429 License : Date printed : 20-Dec-95 Date created : 17-0ct-95 Last revised : 20-Dec-95 Field is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on nTO 27 32.522,w149 56 8.843 Slot location is nTO 27 19.420,w149 57 0.426 Slot Grid coordinates are N 6016165.605, E 506112.446 Slot local coordinates are 1332.00 S 1756.00 W Reference North is True North Main calculation performed with 3-D Minimum Distance method Object wellpath PGM$ <O-13240'>,,28,Pad 3M PGMS <O-12750'>,,23,Pad 3M PGMS <0-9625'>,,26,Pad 3M PGMS <0-7222'>, lO,Pad 3M PGMS <0-7959'>, 11,Pad 3M PGM$ <0-10940'> PGM$ <0-9734'> PGM$ <0-7244'> PMS$ <0-7593'> PM$S <0-7486'> PGMS <0-8713'> PGM$ <0-8523'> PGM$ <0-8965'> PGM$ <0-11080'> PMS$ <10300-10826 PGM$ <0-8480'> PGM$ <0-9976'> ,12,Pad 3M 13,Pad 3M 14,Pad 3M 15,Pad 3M 16,Pad 3M 17,Pad 3M 18,Pad 3M 19,Pad 3M ,20,Pad 3M >,,21,Pad 3M ,,2,Pad 3M ,,4,Pad 3M PGM$ <0-7365'>,,1,Pad 3M PGMS <0-9730'>,,22,Pad 3M PGMS <0-6880'>,,9,Pad 3M PGM$ <0-8065'>,,3,Pad 3M PGMS <0-9110'>,,5,Pad 3M PGMS <0-7460'>,,6,Pad 3M PGM$ <0-8555'>,,7,Pad 3M PGMS <0-10383'>,,8,Pad 3M PGMS <0-12490'>,,24,Pad 3M PMSS <5361 - 10888'>,,25,Pad 3M PGMS <0-8912'>,,25A,Pad 3M 27 Version #5,,27,Pad 3M Closest approach with 3-D minimum distance method Last revised 19-Apr-94 4-Mar-94 4-Mar-94 25-Se~-91 25-Se~-91 25-SED-91 25-Sea-91 25-Se~-91 25-Se~-91 25-Se~-91 25-Se~-91 25-Se~-91 25-Se~-91 25-Se)-91 25-Se)-91 25-Se~-91 25-Se~)-91 25-Se)-91 25-Se)-91 25-Se~-91 25-Se)-91 25-Se)-91 25-Se)-91 25-Se~-91 25-Sep-91 4-Mar-94 24-Mar-94 24-Mar-94 20-Dec-95 Distance M.D. Diverg 50.0 300.0 300 350.4 300.0 300 421.2 325.0 325 313.8 300.0 6140 339.0 60.0 120 363.2 300.0 300 388.6 300.0 11592 413.4 140.0 11880 438.4 300.0 300.0 462.5 325.0 11509.6 487.8 300.0 300.0 513.4 60.0 11760.0 535.6 650.0 650.0 563.2 60.0 9960.0 13.0 300.0 2400.0 63.8 100.0 5320.0 113.8 60.0 120.0 38.8 160.0 160.0 11.6 200.0 9700.0 237.0 300.0 8740.0 89.0 100.0 120.0 138.5 20.0 10202.2 162.1 300.0 11600.0 188.4 100.0 300.0 213.1 60.0 120.0 375.7 0.0 0.0 401.8 20.0 100.0 401.8 20.0 9680.0 475.2 300.0 300.0 lng from M.D. .0 .0 .0 .0 .0 .0 .7 .0 :, ~.................~ ~ ARCO ALASKA, Inc. Structure : Pad 3M Well : 29 Field : Kuparuk River Unit Lo¢otioa : I, Iodh Slope, Alaska < West Scole 1 · 300.00 7800 7200 6600 6000 5400 4800 4200 3600 3000 2400 1800 1200 600 0 600 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 iCreoted by : jones For: D PETRASH IDole ptotted : 24-Dec--95 i IPIot Reference is 29 Version #5. iCoordmates are in feet reference slot ~29. jTrue Vertical Depths are reference RKB (Parker ~245). j S 50.33 DEG W 9Z63' (TO TARGET) 6OO ESTIMATED SURFACE LOCATION: 1332' FNL, 1756' FEL SEC. 2,5, T15N, RSE .600 Q _ _ _ 0 --~ o. 0 0 _ 600 0 -- _1200 0 600 1200 -I'--- - 180o_ - --~ 2400_ - k_ 3000_ >- _ (1) 5600_ t,_ - ~--- 4200_ I - [ 4800_ V -- 5400_ 6000_ 6600_ _1800 ~ o - _2400 C I -- _3000 TD LOCATION: _3600 2094' FNL, 1519' FWL _ SEC. 35, T15N, RSE _4200 _ _4800 flo. EST. RKB ELEVATION: 68' TARGET LOCATION: 3.00KOP TVD=500 TMD=.300 DEP=O 1965' FNL, 1674' FWL - 9.oo SEC. ,35, T13N, RSE _5400 % _ ooo 9.00 SOUTH 5913 - oo B/ PERMAFROST TVD=1718 TMD=1898 DEP=630 WEST 7130 _6600 ~oo EOC TVD=2042 TMD=2494 DEP=1127 ~GNU SNDS -[VD=2218 TMD=2925 DEP=1519 ~ T/ W SAK SNDS TVD=2718 TMD=4143 DEP=2632 ~ _ B/ W ~~4/ W~ 5/8" CSG PT TVD=3418 TMD=5852 DEP=4191 ..... "~'""'"~- MAXIMUM ANGLE 65.8~ DEC BEGIN ANGLE DROP TVD=52 62 oo 58'5~44.00 DROP 2 DE(; / 100' T AI~GET ANGLE TAR~T / UNIT C (~,0~2 40 DEG 0 600 1200 1800 2400 3000 3600 4200 . 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 Scale 1 · 300.00 Vertical Section on 230.33 azimuth with reference 0.00 N, 0.00 E from slot #29 ARCO ALASKA, Inc. Creat~-d by : jones For: D PETRASH Date plotted : 24-Dec-95 '.Plot Reference is 29 Version frS. iCoordinote$ are in feet reference slot ~29. True Verticol Depths are reference RKO (Porker ~24-5). o ~ 80 -1 _ co 40 4o 80 ] Structure : Pad SM Well : 29 Field : Kuparuk River Unit Location : Horlh Slope, Alaska 120 West ~co,~ ~. ~o.oo 600 560 520 480 440 400 560 520 280 240 200 i60 120 80 40 0 40 80 12OO 1 lO0 12o, C- '~6o ] t 0 I I V 24OO 22OO 900. 5C 20OO 1300 '~400 ~, 1500 ;00 1600~ 200 i[~'"'/ 140 ~.2 320 _ 1~,,,~' ~oo~ '~ / / .. 440 520 560 ] ,~0o 560 600 ~ 60O ~ ~ 4*0 600 560 520 480 4~0 400 560 320 280 240 i 0 120 80 40 0 80 120 40 _ 0 _ 120 _ _ 160 ~ - 0 _ 200 ('"' I 240 _ 320 V _ 360 _ 400 _ 440 _ _ 480 520 ~dPARUK RIVER UNI~ 20" DIVERTER SCHEMATIC 6 4 [ 5 3 2 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. , MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE 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 ONE 16' OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16' DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20' - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 I 6 5 4 > > 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. I 4. 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 SPCXDL W/ CHOKE AND KILL LINES 6. 13-5/8" - 50(30 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR 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. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. AIL OTHERS OPEN. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3(X:X) PSI AND HOLD FOR 3 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 CH(:~E LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ~ VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 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'TOM PIPE RAMS. TEST BOI-I'OM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZEFIO 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 FOR 3 MINUTES. 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. VBRS WILL AC, CC~ODATE 3-1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. T col~tP~vY ~~ ~'~ INIT CLASS~.~/ WELL NAME PROGRAM: exp [] I?lgo redrll [] aery [] wellbore se9 [] ON/OFF SHORE O~J. tached .................. ~ppropriate ............... ame and number .............. in a defined pool ............ proper distance from drlg unit boundary. proper distance from other wells ..... reage available in drilling unit ..... is wellbore plat included ........ affected party ............. appropriate bond in force ........ issued without conservation order .... issued without administrative approval. approved before 15-day wait ....... REMARKS :lng provided ............... ~ N ~g protects all known USDWs ........ ~ N late to circulate on conductor & surf csg.. Y~ N late to tie-in long string to surf csg . . . Y all known productive horizons ...... ~ N 1 adequate for C, T, B & permafrost .... N :age or reserve pit ............. N L, has a 10-403 for abndnmnt been approved. Lbore separation proposed .......... ~ N :equired, is it adequate .......... ~ N id program schematic & equip list adequate .~ N ;e ..................... ~ N ,ting adequate; test to ~ .psig~..N-~ ~ur without operation shutdown...~.~ .~N ~/ ~f H2S gas probable ....... /.:....Y~ N ~ issued w/o hydrogen sulfide measu Y N ~d on potential overpressure zones .... i . Y N/ ysis of shallow gas zones ........ I ' Y tion survey (if off-shore) ....... } . Y/ N ~phone for weekly progress reports ~ N [exploratory only] ~ N :NG INEERING: COMMI SS ION: IDH ~ JDN Comments/Instructions: ,~"~ ~ ~-,? O,~J~ ' m Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, informatiOn of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHL~4BERGER ....... COMPANY NAME : ARCO ALASKA, INC, WELL NAME : 3M-29 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22641-00 REFERE~ICE NO : 96058 Oa~e~ LIS Tape Ve~.fication Listing Schlumberger Alaska Computing Center 9-APR-1996 15:05 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/04/ 9 ORIGIN : FLIC REEL NAME : 96058 CONTINUATION # : PREVIOUS REEL : COlW~4F_JqT : ARCO ALASKA INC., KUPARUK 3M-29, API #50-029-22641-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/04/ 9 ORIGIN : FLIC TAPE NAME : 96058 CONTINUATION # : 1 PREVIOUS TAPE : COlV~4ENT : ARCO ALASKA INC., KUPARUK 3M-29, API #50-029-22641-00 TAPE HEADER KUPARUK RIVER MWD/MAD LOGS WELL NAME: API NUFiBER: OPERATOR: LOGGING COMPA~¥Y: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: BIT RUN 1 ......... 96058 KADRMAS N/A WELL CASING RECORD iST STRING 2ND STRING 3M-29 500292264100 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 9-APR-96 BIT RUN 2 BIT RUN 3 .................. 25 13N 8E 1332 1756 68. O0 68. O0 26.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 5827.0 8.500 LIS Tape Vezification Listing Schlumberger Alaska Computing Center 9-APR-1996 15:05 3RD STRING PRODUCTION STRING Well drilled 23-JAN through 25-JAN-96 with CDR only. Ail data was collected in a single bit run. No depth adjustments were performed as per instructions from Dave sharer of ARCO. $ $ PAGE: **** FILE HEADER **** FILE NA~4E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/ 9 MAX REC SiZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SOWIMARY LDWG TOOL CODE START DEPTH STOP DEPTH CDR 5830.0 11823.0 GR 5785.0 11812.0 ROP 5748.0 11866.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: This file also contains the Very Enhanced QRO resisitivity with 2' average that was processed at GeoQuest/Anchorage. One bit run only; no MAD data. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... BIT RUN NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-APR-1996 15 '. 05 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT I1 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ArO?4B SAMP ELEM CODE (HEX) DEPT FT 549018 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD 0H~4549018 O0 000 O0 0 1 i 1 4 68 0000000000 RP ~D OHIO4 549018 O0 000 O0 0 1 1 ! 4 68 0000000000 VRA Mi, FD OHI~ 549018 O0 000 O0 0 1 1 1 4 68 0000000000 VRP M~D 0H~94 549018 O0 000 O0 0 1 ! 1 4 68 0000000000 DER MWD OP~4~ 549018 O0 000 O0 0 1 I i 4 68 0000000000 ROP ~D FPHR 549018 O0 000 O0 0 1 1 2 4 68 0000000000 GR $K~D GAPI 549018 O0 000 O0 0 I 1 i 4 68 0000000000 FET MI,~D HR 549018 O0 000 O0 0 i 1 1 4 68 0000000000 ** DATA ** DEPT. 11865.500 RA.~4~z~ -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.~FD -999.250 ROP.MWD 125.598 GR.MWD FET.~D -999.250 DEPT. 5785.000 RA.~WD -999.250 RP.MWD -999.250 VRA.MWD VRP.~D -999.250 DER.R5'~ -999.250 ROP.M!~D -999.250 GR.MWD FET.~f~D -999.250 -999.~50 -999.250 -999.250 41.320 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-APR-1996 lb:05 PAGE: ** EaVD OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT . 001 SERVICE : FLIC VERSION · O0!CO1 DATE : 96/04/ 9 M_AX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O0!COI DATE · 96/04/ 9 ~&XREC SIZE : i024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUP~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 5830.0 11823.0 CDR $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DO~rHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: ~,IAXI~FUM ANGLE: 25-JAN-96 4.0C FAST 2.5 MEMORY 11866.0 5785.0 11866.0 39.9 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-APR-1996 15:05 PAGE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISTIVITY/GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS z~JD TYPE: MUD DENSITY (LB/G): ,~JD VISCOSITY (S) : MUD PH: z~JD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (Oh?4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): TOOL NUMBER CDR059 8.500 5827.0 LSND 10.70 45.0 9.0 3.110 70.0 2. 880 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) A-WR FREQUENCY (HZ) REMARKS: ************ BIT RUN 1 ************* DRILLED INTERVAL 5837' - 11866' WELL INCLINATION AT TD: 39.88 DEG. RES TO BIT: 42.91 '; GR TO BIT: 53.33 ' TD WELL @ 10:57 25-JAN-96 MUD FIL: 4.8; PH: 9.0; VISC: 45; CHLORIDES: 700PPM DATA FROM DOWNHOLE MEMORY, V4. OC SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 I LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-APR-1996 PAGE: 6 TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - ~HAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB S~4P ELEM CODE (HEX) DEPT FT 549018 O0 000 O0 0 2 1 1 4 68 0000000000 ATR LW1 0~%~4~549018 O0 000 O0 0 2 1 1 4 68 0000000000 PSR LW1 OP~v~4549018 O0 000 O0 0 2 1 1 4 68 0000000000 ATVR LWI OH~ffq549018 O0 000 O0 0 2 1 1 4 68 0000000000 PSVR LW1 Ot{~I4549018 O0 000 O0 0 2 1 1 4 68 0000000000 DER LW1 OHN2~ 549018 O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LW1 F/HR 549018 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 549018 O0 000 O0 0 2 1 1 4 68 0000000000 TAB LW1 HR 549018 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11865. 500 A TR . LW1 PSVR. LW1 - 999. 250 DER. LW1 TAB. LWi - 999. 250 -999. 250 PSR. LW1 -999. 250 ROPE. LW1 -999.250 ATVR.LW1 -999.250 125. 598 GR. LW1 -999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-APR-1996 15:o5 PAGE: **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/04/ 9 ORIGIN : FLIC TAPE NAME : 96058 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC., KUPARUK 3M-29, API #50-029-22641-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/04/ 9 ORIGIN : FLIC REEL NAME : 96058 CONTINUATION # : PREVIOUS REEL : COMMENT · ARCO ALASKA INC., KUPARUK 3M-29, API #50-029-22641-00
