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Home My WebLink About194-111Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I~ OI - I~ ) 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: Beve~ incent Nathan Lowell Date: [~ --3 Isl TO RE-SCAN Notes' Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for Sidetrack 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service ~,,.,~. ~ ~-: 2. Name of Operator ~.~:iOt,~§~ 7. Permit Number BP Exploration (Alaska) Inc.'"'" ~c,.~~' ~ 194-111 302-307 3. Address ;~~ 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20020-01 4. Location of well at surface 9. Unit or Lease Name 750' SNL, 1245' WEL, SEC. 09, T11 N, R13E, UM x = 643107. Y = 5970596 Prudhoe Bay Unit At top of productive interval 540' SNL, 1390' WEL, SEC. 09, T11N, R13E, UM x = 642957, Y = 5970803 At total depth 10. Well Number J-01A 108' NSL, 1766' WEL, SEC. 04, T11N, R13E, UM x=642567. Y= 5971443 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 77.25' ADL 028281 12. Date Spudded 09/23/1994 113' Date T'D' Reached 114' Date C°mp" Susp" °r Aband' 09/26/1994 10/9/2002 ' 115' water depth' if OffshOre N/A MSLI, 116' N°' °f C°mpleti°ns Zero 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 9900 9056 ETI 9300 9037 ETI [] Yes [] NoI N/A MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD 2;~. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 30" Stove Pipe Surface 10ff 36" 280 sx Permafrost 20" 94# H-40 17' 950' 26" 1800 sx Fondu 13-3/8" 68# / 61 # K-55 / J-55 17' 4258' 17-1/2" 1600 sx Class 'G' 9-5/8" 47# N-80 17' 8558' 12-1/4" 2155 sx Class 'G' 5-1/2" 17# L-80 8089' 9900' 6-3/4" 315 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 4-1/2", 12.6#, L-80 8084' 8019' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8845' Set Whipstock, P&A w/17 Bbls Class 'G' & 16.5 Bbls Class 'G', Sqz to 1200 psi 8681' Set 2nd Whipstock 8664' Set 3rd Whipstock 27. PRODUCTION TEST Date First Production 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 I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER'BBL OIL GRAVITY'API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Nocoresamplesweretaken. RECEIYFD SCANNED F' B 1 0 2003 J&N 2 ? 20 Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. 30. Geologic Markers 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. Zone 3 8714' 8711' Zone 2C 8769' 8764' Zone 1B 9148' 9019' Alaska 0ii & Gas C~,~:~. 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 T.rrieHubb,e ,~,~ ~ Title TechnicalAssistant Date U-01A 194-111 802-807 Prepered By Name/Number: Terrie Hubble, 564-48£8 Well Number Permit No. / Approval No. Drilling Engineer : AlistairShen~ood, 564-43?8 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'. SCANNED FEB .~ 0 2003 Form 10-407 Rev. 07-01-80 ~- Well: J-01B Field: Prudhoe Bay Unit APl: 50-029-20020-02 Permit: 202-201 Rig Accept: 10/22/02 Rig Spud: N/A Rig Release: 10/27/02 Drillin~ Rig:,~, Nordic, #2 This first attempt it~ Sider[ack the welt was not successfUl; pre;Rig Summary for that.attempt i~ followed · ,, by the Pre-Rig Summa~ for thesecond, successful attempt. Well: J-01B Rig Accept: 11/16/02 Field: Prudhoe Bay Unit Rig Spud: 11/17/02 APl: 50-029-20020-02 Rig Release: 11/24/02 Permit: 202-201 Drilling Rig: Nordic #1 PRE-RIG WORK 10/05/02 SHUT-IN WELL, IT WAS FLOWING WHEN WE ARRIVED ON LOCATION. PUMPED KILL FLUIDS AND FREEZE PROTECTED FLOWLINE. SET WHIPSTOCK WITH TOP @ 8845'; ORIENTED 20 DEG ROHS. STOP CCL AT 8821.8 FT. CCL TO TOP OF WHIPSTOCK: 23.25.2 RA TAGS SET AT 8855'. SET 15' BELOW REQUESTED DEPTH WITH DRILLING ENGINEER'S CONCURRENCE DUE TO ORIENTING PROBLEM. 10~08~02 PRESSURE TEST LUBRICATOR 200/4000 PSI. I O~O9~O2 LOAD & KILL WELL WITH 200 BBLS FILTERED 2% KCL, FOLLOWED WITH 110 BBLS CRUDE. RIH WITH 3" BALL DROP CEMENT NOZZLE. TAG WHIPSTOCK AT 8845' ELMD, PICK UP TO 8835' ELMD AND FLAG PIPE. PUMP 4 BBLS 15.8 PPG NEAT, 8 BBLS W/18 PPG AGGREGATE, 5 NEAT. SQUEEZE 14 BBLS PAST THE WHIPSTOCK AT 150 PSI BUMP PRESSURE OPENED CHOKE FULL AND LAY IN THE REMAINING 3 BBLS. SQUEEZED 0.5 BBLS MORE LAYING IN CMT. PULL TO SAFETY AND HESITATE. LOST AN ESTIMATED 7 MORE BBLS BEHIND PIPE MOSTLY FROM THE HYDROSTATIC PRESSURE OF THE FLUID IN THE COIL AND PUMPING PERIODICALLY TO MOVE FLUID AND FILL THE VOIDAGE IN THE COIL. AFTER CMT TIMED OUT PUMP 10 BBL BIOZAN. TAG WHIPSTOCK @ 8845'. MAKE CONTAM PASSES FROM WHIPSTOCK TO 8800', CHASE OUT OF HOLE @ 80%. FP COIL AND 500' OF WELLBORE. ESTIMATE THE TOC TO BE ~9035' STANDBY FOR BATCH #2. RIH OBTAIN INJ RATE OF .9 BPM AT 1000PSI. LINE UP TO RE-CEMENT. JOB IN PROGRESS. 10/10/02 PUMP 16.5 BBLS 15.8 PPG CEMENT. (ESTIMATE 4 BBLS BEHIND PIPE). BUILD AND HOLD SQUEEEZE PRESSURE OF 1200 PSI FOR 60 MINUTES. CONTAMINATE TO TRAY. CIRCULATE OUT USING XSLK KCL. POH AT 80% JETTING JEWELRY AS POH. FREEZE PROTECT WELL TO 2500 WITH 60/40 MEOH. RDMO. NOTIFY PAD OPERATOR THAT WELL REMAINS SHUT IN FOR SIDE TRACK. 10/13/02 TIO= 250/800/250 BLEED WELL TO 0 PSI. (FOR RWO). BLED OA FROM 250 PSI TO 0 PSI. BLED IA FROM 800 PSI TO 0 PSI. BLED TBG FROM 250 PSI TO 0 PSI. MONITOR FOR 30 MIN, NO INCREASE IN PRESSURES. FINAL WHP'S 0/0/0. TAG TOP OF WHIPSTOCK W/3.25 CENT, AND SAMPLE BAILER @ 8832' WLM. PT CEMENT PLUG TO 1000 PSI. (SUCCESSFUL MIT) BLEED TUBING BACK TO 245#. LEAVE WELL SHUT IN. 10/14/02 TIO= 20/200/60 (OA PROJECT) POST TBG, IA & OA BLEED. TBG INCREASED 20 PSI, IA INCREASED 200 PSI & OA INCREASED 60 PSI. SCANNED FEB I 0 2003 J-01 B, Coil Tubing Drilling Page 2 10/15/02 PRE-CTD SIDETRACK PRESSURE TEST OF MASTER, SWAB, AND WING VALVE PASSED TO 3500 PSI. MIT OA TO 2000 PSI. MIT FAILED ESTABLISHED LLRT OF 2.1 GALS/MIN. 10/16/02 T/I/O = SI/360/460. PPPOT-T PASSED.[OA WAIVER EVAL] PRESSURED VOID TO 5000PSI. VOID LOST 150PSI IN 30 MIN. PPPOT-IC FAILED. PRESSURE WOULD NOT BLEED OFF TEST VOID. NO LDS TO TORQUE FOR RE-ENERGIZING. 11/12/02 ATTEMPT TO SET WHIPSTOCK, UNABLE TO GET DEEPER THAN 60' BELOW GROUND LEVEL DUE TO ICE PLUG, PUMPED METHANOL 1 BBL PRESSURE INCREASED FROM 0 PSI TO 1000 PSI. PUMPED TUBING PRESSURE TO 1500 PSI WITH METHANOL. COIL TO CHASE ICE PLUG. WELL LEFT SHUT IN. 11/13/02 CHANGE OUT INJECTOR PACK-OFFS. RIH W/2.22" DJN. RIH JETTING 60/40 METHANOL TO 2500'. SAW SLIGHT RESISTANCE BETWEEN 60' AND 110'. POOH CIRC METH AT 90%. RIG DOWN. NOTIFY PCC AND PAD OPERATOR. JOB COMPLETE. SET BAKER 5.5" GEN I WHIPSTOCK FACE 24 DEGREES LEFT OF HIGHSIDE AT 8664' WITH 3 RA TAGS LOCATED AT 8672.9', BOTTOM OF WHIPSTOCK AT 8676' CORRELATED TO AWS GR/CCL 03/09/95. DRIFTED TO TAG TD AT 8681' WITH CCL/GR TIE IN. SHUT IN. SCANNED FEB 1 0 2003 BP EXPLORATION Page 1 of 11 Operations Summary Report Legal Well Name: J-01 Common Well Name: J-01 Spud Date: 5/14/1969 Event Name: REENTER+COMPLETE Start: 11/25/2002 End: 11/24/2002 Contractor Name: NORDIC CALIST^ Rig Release: 10/27/2002 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 10/21/2002 10:00 - 11:30 1.50 MOB P PRE Back rig off of J-20b, move across pad, park on pad near J-01. 11:30 - 00:00 12.50 MOB N RREP ;PRE Continuing to modify Nordic 2. Rig Mods in Progress: Install articulating gooseneck, tweak hydraulic pump on CT side, Modify cellar doors to close w/S-riser attached. 10/22/2002 00:00 - 02:00 2.00 MOB N RREP PRE Continue modifying cellar doors (zero rig rate). 02:00 - 13:00 11.00 MOB N HMAN PRE Unable to bleed flowline between J-01 and manifold building. Several leaking valves. Rig on standby. 13:00 - 14:00 1.00 MOB P PRE Position rig over well. 14:00- 15:30 1.50 RIGU P PRE NU BOPE. 15:30 - 18:00 2.50 RIGU N RREP PRE Attempt BOP test. Test hose blew. No backup. Decide to install new gooseneck (back on zero rig rate until pipe is stabbed). 18:00 - 18:45 0.75 RIGU P PRE Crew change safety and TL meeting. 18:45 - 23:30 4.75 RIGU N RREP PRE Stab pipe. Free tugger cable from new windwall section. Agreed to accept rig at 20.15 hrs. As we were simultaneously completing contractor modifications and RU on well. 23:30 - 00:00 0.50 BOPSUF P PRE Safety meeting for BOP test. 10/23/2002 00:00 - 01:00 1.00 BOPSUI; N SFAL PRE Perform initial BOP test. Witness waived by AOGCC's Chuck Scheve. Tree valves leak. Call greasers. 01:00 - 03:30 2.50 BOPSUF P PRE Test choke manifold while greasing tree valves. 03:30 - 08:00 4.50 BOPSUF P PRE Resume test on stack. 08:00 - 09:15 1.25 BOPSUF N SFAL PRE HCR failed test. Grease it. Retest OK. 09:15 - 09:30 0.25 BOPSUI; P i PRE RD test equip. 09:30 - 10:15 0.75 STWHIP P WEXIT Safety/TL meeting. 10:15 - 12:00 1.75 STWHIP P WEXIT PU inj. Install CTC. Pull test. Circulate coil and PT. 12:00- 12:45 0.75 STWHIP N SFAL WEXlT Attempt to open tree valves. Grease locked. Get grease crew back here. 12:45 - 13:00 0.25 STWHIP P !WEXlT Bleed well (40 psi). Fill hole (1 bbl) 13:00- 14:45 1.75 STWHIP P WEXlT MU milling BHA. 14:45 - 16:15 1.50 S'FWHIP P WEXIT RIH taking returns to cuttings tank. Did not see XN. Continue RIH. Did not see whipstock. Stop at 8950' CTM. Mechanical shows minus 850' (yes, 9800' discrepancy). Up wt indicates maybe 5000' of coil in the hole. Switch encoders. 3400' popped up. Use this for now. Continue RIH slowly. Ft/min about twice the actual speed, E-depth looking OK. Mechanical acting like meters (but backward). RIH tag XN 8084' CTM. Correct to 8088' ELMD. 16:15- 18:00 1.75 STWHIP N SFAL WEXlT NPT for RIH counter trouble 18:00 - 20:00 2.00 STVVHIP P WEXlT Mill XN 20:00 - 20;30 0.50 STWHIP P WEXlT Dress nipple and make dry passes. 20:30 - 21:30 1.00 STWHIP P :WEXlT RIH slow while adjusting hydraulic pressure on power pack. RIH tag whipstock 8849'. Flag pipe. Correct depth -3'.Half hour attributable to power pack issue. 21:30 - 00:00 2.50 STWHIP P WEXIT Mill window 2.4/2.4bpm 1780 psi on, 1670psi off 1K wob, Mill from 8846 to 8848.2. 10/24/2002 00:00 - 02:30 2.50 STWHIP P WEXIT Mill window from 8848.2 @2.4/2.4bpm, 1670 psi off, 1860 psi on,3-4K WOB, UP 39K, DN 29K. to 8849.3. 02:30 - 04:30 2.00 STWHIP P WEXlT Continue milling from 8849.3 to 8850'. 04:30 - 05:00 0.50 STVVHIP P WEXlT Stall. PU and ream back to bottom. 05:00 - 05:30 0.50 STWHIP P WEXlT Continue milling at 8850 @ 2.4 / 2.4 bpm, 2128 psi on, 1670 psi off, WOB 3K, Up wt 39K, Dn wt 29K. Stall. 05:30 - 08:30 3.00 STWHIP N STUC WEXlT Bit stuck. Work pipe with and without pump. Pull to 90 K without pump. BP EXPLORATION Page 2 of 11 Operations Summa Report Legal Well Name: J-01 Common Well Name: J-01 Spud Date: 5/14/1969 Event Name: REENTER+COMPLETE Start: 11/25/2002 End: 11/24/2002 Contractor Name: NORDIC CALISTA Rig Release: 10/27/2002 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 10/2412002 08:30 - 09:30 1.00 STWHIP N STUC WEXIT Pressure BS to 1600 psi. Little to no bleed-off. Workpipe. lAP = 177 psi. Dump pressure while working. No movement. repeat. Nope. Circulate. Note that circ conditions changed 1.5/1400 initial; 1.2/1900 current. Concerned about damaging motor and plugging bit. Circ at minimum rate. 09:30 - 14:30 5.00 STWHIP N STUC WEXlT Wait on acid crew, flowback tank, etc. 14:30 - 15:15 0.75 S'I'WHIP N STUC WEXlT RU iron for acid job. 15:15- 16:00 0.75 STWHIP N STUC WEXlT Safety meeting. 16:00 - 16:30 0.50 STWHIP N STUC WEXlT PT line to divert tank. Put 40 bbls of soda ash water in tank. 16:30 - 16:45 0.25 STWHIP N STUC WEXlT PT treating lines to 5500 psi. PVT = 388. 16:45 - 17:15 0.50 STWHIP N STUC WEXlT Load 30 bbls of 12-3 HCL-HF acid at 1.0 BPM 1700 psi into coil. Zero MM on lead. Chase with 10 bbls of cleanup water. 17:15 - 17:30 0.25 STWHIP N STUC WEXlT Chase acid with rig pumps. Blew pop-off at 1000 psi. Switch to pump 2. Pump at2.1 BPM; 2800 psi. At 56 bbls, 2.1 BPM 3250 psi. 17:30 - 19:00 1.50 STWHIP N STUC WEXIT At 60 bbls (6 bbls out mill), SD pump and let soak while working pipe to 90k. Let soak for 20 minutes. Pump another 5 bbls, let soak 20 mintues -- working pipe. Pump one bbl at a time, soak 5 minutes --working pipe. With 15 bbls ac~d out and 90k, pulled free. 19:00 - 20:00 1.00 S'I-WHIP N STUC WEXIT Circulate out acid to divert tank. 2.2bpm @ 1170 PSI. 20:00 - 21:30 1.50 STVVHIP N STUC WEXlT POH to surface. Pulled out of coil connector. 21:30 - 00:00 2.50 S1-WHIP N STUC WEXIT Wait on fishing tools. While waiting had to order additional soda ash solution to neutralize acid. PH still in the 1-2 range after initial attempt to neutralize. 10/25/2002 00:00 - 02:30 2.50 STWHIP N STUC WEXIT Wait on fishing tools. 02:30 - 04:30 2.00 STWHIP N STUC WEXIT PU fishing BHA (2-3/8" spear) 04:30- 05:15 0.75 STWHIP N STUC WEXIT Stab injector. 05:15 - 07:45 2.50 STWHtP N STUC WEXlT RIH with fishing BHA. 07:45 - 08:15 0.50 STWHIP N STUC WEXIT Latch fish. Jar 12 times up. 08:15 - 08:45 0.50 S'I'WHIP N STUC WEXIT WOO. 08:45 - 09:15 0.50 STWHIP N STUC WEXlT Jar 15 times down to max down (-10k). 09:15- 10:00 0.75 STWHIP N STUC WEXlT Jar 23 times up, to 80k. No movement 10:00 - 10:30 0.50 STWHIP N STUC WEXIT Drop a 7/8" ball to disconnect. Circulate to seat. Shear disconnect. 10:30- 12:30 2.00 STWHIP N STUC WEXIT POOH. 12:30 - 13:45 1.25 STWHIP N STUC WEXIT LD fishing BHA. 13:45- 14:30 0.75 STWHIP N STUC WEXIT Waiton E-line. 14:30 - 15:00 0.50 STVVHIP N STUC WEXIT Safety meeting with E-line crew 15:00 - 23:00 8.00 STWHIP N STUC WEXIT RU E-line for USIT log. Log the interval 8050' - 8760'. 23:00 - 00:00 1.00 STWHIP N STUC WEXIT MU Whipstock install pip tag. MU E line BHA 10/2612002 00:00 - 02:20 2.33 STWHIP N STUC WEXIT RIH with whipstock. Depth correct +6'. Log into position and set with Top of Whipstock at 8681' 15 right of high side. RA tag 8690'. Tag to confirm. 02:20- 03:15 0.92 STWHIP N STUC WEXIT POH to surface. 03:15- 04:00 0.75 STVVHIP N STUC WEXIT LD whipstock running tools. 04:00 - 04:30 0.50 STWHIP N STUC WEXIT MU milling BHA for second attempt. 04:30 - 05:15 0.75 STWHIP N STUC WEXIT Change out CTC and pull test to 30,000~. 05:15- 06:00 0.75 STVVHIP N STUC WEXIT Stab injector 06:00 - 06:45 0.75 STWHIP N STUC WEXlT RIH. Safety/TL meeting. 06:45 - 07:30 0.75 STVVHIP N SFAL WEXIT Chicksan connection backed off inside reel. Tighten, secure, clean-up bio water in reel house. 07:30 - 08:30 1.00 STWHIP N STUC WEXIT RIH. Tag pinch point dry 8677' CTM. PU. Come up on SCANNED FEB ! 0 20[}3 Pnnted 12J6/2002 I 55'38 PM BP EXPLORATION Page 3 of 11 Operations Summa Report Legal Well Name: J-01 Common Well Name: J-01 Spud Date: 5/14/1969 Event Name: REENTER+COMPLETE Start: 11/25/2002 End: 11/24/2002 Contractor Name: NORDIC CALISTA Rig Release: 10/27/2002 Rig Name: NORDIC 2 Rig Number: N2 Date From o To Hours Task Code NPT Phase Description of Operations 10/26/2002 07:30 - 08:30 1.00 S'I'WHIP N STUC WEXIT pumps. RIH. Start milling at 8676', corrected to 8682'. 08:30 - 15:15 6.75 STWHIP N STUC WEXIT Two stalls getting started, then smooth milling to 8686'. Mill 2.3/1600 FS. Average motor work 500 psi. Average WOB 3500 lbs. Pumped three 10 bbl sweeps (4 ppb biozan) while milling. 15:15- 16:30 1.25 STWHIP N STUC WEXIT Stall at 8686'. PU clean. Ease into it. Couple of pressure bumps and mill off on bottom, then stall again. Stuck. Deja vu same milled footage, same # stalls, same result as last whipstock. Work pipe to 93k a couple of times. 16:30 - 19:00 2.50 STVVHIP N STUC WEXlT Swap well to FIo-Pro (5% lubetex). Also, order 20 bbl FIo-Pro pill with 20% lubetex. 19:00 - 20:00 1.00 STWHIP N STUC WEXIT Wait on arrival of Lubtex pill. 20:00-21:50 1.83 STWHIP N STUC WEXlT Pump 20 bbl lubtex pill to mill and spot15 bbl of pill in open hole. work pipe -15 to 93 K. NO GO. Attempt to pressure backside. NO GO. Prep to drop ball. 21:50 - 22:20 0.50 STWHIP N STUC WEXIT Drop ball 15/16" and circulate to disconnect 22:20- 00:00 1.67 STWHIP N STUC WEXIT POH to surface. 10/27/2002 00:00 - 01:30 1.50 STWHIP N STUC WEXlT Set back injector. LD BHA 01:30 - 01:35 0.08 S'I~/VHIP N STUC WEXIT MU fishing BH^. Time change Fall back one hour. 01:35- 02:00 0.42 STWHIP N STUC WEXIT Stab injector 02:00 - 03:40 1.67 STWHIP N STUC WEXIT RIH with GS spear fishing assembly. 03:40 - 04:15 0.58 STWHIP N STUC WEXIT Up w-r 39K. Tag top of fish 8665'. Stack out 5K pull 10K overpull 5 jar licks NO GO. Pull 20K over 5 licks NO GO. Pull 40K overpull 3 jar licks. Pull free. Either pull fish free or stripped the GS spear. Next fishing option 2.32" Itco Spear to catch ID of lower disconnect. 04:15- 06:00 1.75 STVVHIP N STUC WEXIT POH to surface. 06:00- 06:15 0.25 STWHIP N STUC WEXIT Crew change. 06:15 - 08:00 1.75 STWHIP N STUC WEXlT LD fishing BHA. Motor broke where output shaft pin screws into rotor. Rotor and motor housing recovered. TOF at 8683' (2' below top of whipstock). 08:00 - 09:30 1.50 STWHIP N STUC WEXlT Discuss options. 09:30 - 10:00 0.50 STWHIP N STUC WEXlT Safety/TL meeting - swap to KCL and RDMO. 10:00 - 10:45 0.75 STWHIP N STUC WEXIT RU nozzle on MHA. 10:45- 12:00 1.25 STWHIP N STUC WEXIT RIH to 8660'. 12:00-15:30 3.50 STWHIP N STUC WEXlT Swap well to 2% KCL water. POOH. Freeze protect top 2000' with 25 bbls MeOH. 15:30- 16:00 0.50 STWHIP N STUC WEXIT LD BHA. 16:00- 22:00 6.00 RIGD N STUC POST RD equipment. Empty and clean pits. ND BOPE. NU and test tree cap. Release rig 22:00 hrs. 11/16/2002 06:00 - 08:00 2.00 MOB P PRE Rig Released from J-27A @ 06:00 on 11/16/02. PJSM. Prep to move rig to J-01. Warm moving system. Roll-up tarps. Disconnect green tank & inspect rig. 08:00 - 08:30 0.50 MOB P PRE Held pre-move safety meeting. Review & discuss recent lifting incident & stress need to take time to double-check things before we jump into operations. 08:30 - 09:00 0.50 MOB P PRE Move rig from J-27 to J-01 & line up to well. WHP, lAP, OAP = 0psi. Flowline pressure = 2400psi from freeze protection. Pad operator bled flowline down to 0psl. Lateral valve is double blocked ~ thus no possibility of sending fluids down the flowline during operations. 09:00 - 09:30 0.50 MOB P PRE Carry out post-operations pad inspection on J-27 & pre-operations pad inspection on J-01. ,SCANNED FEB ~. 0 2003 Printed 12/6/2002 I 55 38 PM BP EXPLORATION Page 4 of 11 Operations Summa Report Legal Well Name: J-01 Common Well Name: J-01 Spud Date: 5/14/1969 Event Name: REENTER+COMPLETE Start: 11/25/2002 End: 11/24/2002 Contractor Name: NORDIC CALIST^ Rig Release: 10/27/2002 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 11/16/2002 09:30 - 10:00 0.50 MOB P PRE Install spill dike. Remove tree cap & install X/O & spacer spool. 10:00 - 12:00 2.00 BOPSUF P DECOMP ACCEPT RIG @ 10:00 HRS on 11/16/2002. N/U BOPE. Spot :railers & tanks. 12:00 - 18:30 6.501 BOPSUE P DECOMP Grease-lock swab valve & perform initial BOPE ~ressure/function test. AOGCC test witness waived by John Crisp. Meanwhile fill rig pits with 2% KCL bio-water. 18:30 - 19:15 0.75 BOPSUE N RREP DECOMP Blind/shear rams not testing. Rebuild. 19:15 - 20:15 1.001 BOPSUI~ P DECOMP Press test Blind / Shear rams - OK. Press test inner reel valve. 20:15 - 21:00 0.75 BOPSUE P DECOMP Change out CT pack-off. 21:00 - 21:20 0.33 S'I'WHIP P WEXlT PRE-SPUD AND SAFETY MEETING. Reviewed well plan and special considerations. Reviewed procedure, hazards and mitigation for M/U of window milling BHA. 21:20 - 22:20 1.00 STWHIP P WEXIT M/U window milling BHA #1 with HC 3.80" diamond speed mill, 2-7/8" straight motor, MHA, 2 jts PH6, XO and CTC. BHA total length = 82.2 ft. 22:20 - 23:50 1.50 STVVHIP P WEXIT RIH with BHA #1. Circ 2# Biozan water at 0.2 bpm, 200 psi, take well bore returns to green tank. 23:50 - 00'00 0.17 STVVHIP P WEXIT Wt. chk at 8610'. Up wt = 32.5K. Dwn Wt. = 25.5K. Circ. at 2.5 bpm, 1900 psi, Tag whipstock pinch point at 8668' ctd. Correct depth to 8665'. Flag CT at 8665'. 11/17/2002 00:00 - 01:30 1.50 STWHIP P WEXIT Milling window. Flagged CT at 8665'. Free spin 2000 psi, 2.5 bpm, 4 stalls to get started at top of whipstock. Started milling at 8665.0 ft. 2.5 / 2.5 bpm, 2000-2300 psi, 1K WOB. Milled to 8665.5 ft. 01:30 - 02:30 1.00 STVVHIP P WEXIT Milling, 2.5 / 2.5 bpm, 2000 - 2250 psi, I K WOB. Milled to 8666.5'. 02:30-03:30 1.00 s'rVVHIP P WEXIT Milling, 2.5/2.5bpm, 1900-2150psi, I KWOB. Milledto 8667.7'. Steady easy milling. 03:30-04:45 1.25 STVVHIP P WEXIT Milling, 2.5/2.5bpm, 1900-2150psi, I KWOB. Milledto 8668'. Pick up easy at 29K up wt. No overpull. Free spin = 1900 psi. Dwn wt = 21.7 K. Milled to 8669'. 04:45 - 06:00 1.25 STWHIP P WEXlT Milling, 2.5 / 2.5 bpm, 1900 - 2150 psi, 1 K WOB. Milled to 8670'. Steady easy milling. 06:00 - 07:20 1.33 STWHIP P WEXIT Milling, 2.5 / 2.5 bpm, 1900 - 2150 psi, 1 K WOB. Milled to 8671'. 07:20 - 08:20 1.00 STWHIP P WEXIT Milling, 2.5 / 2.5 bpm, 1900 - 2150 psi, 1 K WOB. Milled to 8672'. 08:20 - 09:30 1.17: STWHtP P WEXlT Milling, 2.5 / 2.5 bpm, 1900 - 2050 psi, 1 K WOB. Milled to 8673.4'. Observe CT pressure drop to 1900psi ~ mill must have popped out of window btm. 09:30 - 10:40 1.17 STWHIP P WEXIT Vlill formation with 2.5/2.5bpm, 1900/2250psi, 2K WOB & increased ROP. Milled to 8683.5'. 10:40 - 10:50 0.17 S'I'VVHIP P WEXIT Back ream clean up to 8660'. 10:50 - 12:10 1.33 STWHIP P WEXlT POOH window milling BHA#1. 12:10 - 12:20 0.17 STWHIP P WEXlT L/O & inspect DSM. Mill gauge 3.79" & wear on face indicates crossing of Csg wall. 12:20 - 12:40 0.33 STWHIP P WEXlT M/U another good used DSM with 3.80" String Reamer. M/U same 2-7/8" straight extreme motor, MHA, 2 jts PH6, XO & CTC. I~HA OAL -- 83.2'. 12:40 - 14:30 1.83 STWHIP P WEXIT RIH with window dressing BHA #2 to 8600'. Up wt check ~ 31.5k. Run-in wt ~ 23k. Bring pumps up 2.5bpm/2010psi. Continue RIH & tag @ 8669.8'. Assume SR @ TOW & subtract 4.3' from CTD to place SR @ TOW (8665'). SCANNED FEB O 2003 Pnnted. 12/6/2002 1.55:38PM BP EXPLORATION Page 5 of 11 Operations Summa Report Legal Well Name: J-01 Common Well Name: J-01 Spud Date: 5/14/1969 'Event Name: REENTER+COMPLETE Start: 11/25/2002 End: 11/24/2002 Contractor Name: NORDIC CALISTA Rig Release: 10/27/2002 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 11/17/2002 14:30 - 14:45 0.25 STWHIP P WEXlT Stall lx @ 8665.5'. Ease-in from 8664' @ 0.1'/3rains. Continue reaming window with 2.5/2.5bpm, 2000/2150psi & lk WeB. Stall lx @ 8668.6. P/U clean & ease-back into milling again. 14:45 - 15:30 0.75 STWHIP P WEXIT Continue reaming with 2.5/2.5bpm, 2000/2050psi & lk WeB. Milled to 8670' & observe CT pressure drop to 1900psi ~ string reamer is out of window btm. 15:30 - 15:40 0.17 STWHIP P WEXIT Ream formation & tag up @ 8679.9' with 2.5/2.5bpm, 1950psi. Correct CTD to 8683.5'. 15:40 - 16:30 0.83 STWHIP P WEXlT Dress/drift window & make several backream passes with & without pumping. Window looks clean. TOW = 8665' & BOW = 8673.5' & TD = 8683.5'. Meanwhile swap wellbore to recycled Flopro mud. 16:30 - 18:00 1.50 S'I-WHIP P WEXlT Paint EOP flag @ 8400' & POOH window dressing BHA#2. 18:00 - 18:45 0.75 STWHIP P WEXIT L/O BHA#2 & inspect SR. SR gauge 3.80". 18:45- 19:00 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for MWD BHA M/U. ~19:00 - 19:45 0.75 DRILL P PROD1 M/U BHA #3, Sperry MWD build BHA with 1.04 deg motor and used Smith 3.75" M09 bit. 19:45 - 20:20 0.58 DRILL P PROD1 Grease and check injecter head chains. OK. 20:20 - 22:00 1.67 DRILL P PRODI RIH with MWD BHA #3, Shallow hole test OK RIH. 22:00 - 22:30 0.50 DRILL P PROD1 Orient TF to high side. RIH thru window clean. Orient to 70R. zz:~u - uu:uu 1 ..50IJI~ILL P PROD1 Tagged TD at 8,687' CTD, correct to TD of 8683.5' BKB [-3.5~,,, CTD]. Drilling, 2.5/2.5 bpm, 3170 -4000 psi, TF = 70R. S~v~ral stalls, ReP = 30 FPH ;Drilled to 8,720 ft. 11/18/2002 00:00 - 02:30 2.50 DRILL P PROD1 Drilling Zone 3, 2.5 / 2.5 bpm, 3200 - 41~0~si, 60R, many !stalls, 15 fph, Drilled into Zone 3 at, ut 8722'. Drilled to i8749'. 02:30 - 04:15 1.75 DRILL P PROD1 Drilling Zone 3, 2.5 / 2~0- 4100 psi, 30R, many stalls, 10 fph, Drilled 04:15 - 05:30 1.25 DRILL P PROD1 Drilling Zone 3, 2~00 -4100 psi, 201:{, many stalls, 10 f'ph,/D~l]led to 8775'. 05:30-06:00 0.50 DRILL P PROD1 DrillingZ~,,. m, 30704- 100psi, 20R, many stalts,~,,~'fph, Drilled to 8783'. 06:00 - 07:00 1.00i DRILL P PROD1 ~', 20R, 10 fph, Drilled t'o 8789' 07:00 - 08:30 1.50 ' DRILL P PROp,t/ Continue drilling to 8795' with 36R TF, 2.7/2.7bpm, 3300/3600psi. Decide to pull for BHA change. 08:30 - 09:00 0.50 DRILL P / PROD1 Wipe clean to 8510'. 09:00 - 10:15 1.25 DRILL P/ PROD1 Log down @ 60fph & tie-into PDC log GR marker. Add 18' to CTD. 10:15 - 10:40 0.42 DRILL PROD1 RBIH. Kill pumps & RIH thru window to 8700'. 10:40 - 11:10 0.50 DRIL P PROD1 Log down @ 60fph & see RA pip tag depth @ 8691' (18' deeper). 11:10 - 12:30 1.~3 P PROD1 POOH drilling BHA#3. 12:30- 13:00,~n.5~On DRILL ;P PROD1 L/O used M09 Bit (grades 4,6,1) 0.50 DRILL P PROD1 Adjust motor bend to 1.69degs & M/U drilling BHA #4 with new 13:00 - ~ design Smith MOO bit. M/U injector. 0,x'15:15 1.75 DRILL P PROD1 RIH with BHA ~4. SHT MWD & odenter ~ OK. Continue RIH to 87OO'. 15:15 - 16:00 0.75 DRILL P PROD1 Tie-into RA pip tag & add 12' to CTD. 16:00 - 16:15 0.25 DRILL P PROD1 RIF~& tag TD @ 8810'. ,SCANNED FEB 0 7.003 Pnnted 12/6/2002 1 5538PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 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 BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 750' SNL, 1245' WEL, SEC. 09, T11N, R13E, UM At top of productive interval 4740' NSL, 1390' WEL, SEC. 09, T11 N, R13E, UM At effective depth 4872' NSL, 1461' WEL, SEC. 09, T11N, R13E, UM At total depth 108' NSL, 1766' WEL, SEC. 04, T11 N, R13E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE: 77.25' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / J-01A' 9. Permit Number 194-111 10. APl Number 50- 029-20020-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 9900 feet 9056 feet 9300 feet 9037 feet Length Plugs (measured) Junk (measured) 3-3/8" IBP PLUG AT 9300' MD (05/96) Size Cemented MD TVD 100' 30" 280 sx Permafrost 100' 100' 933' 20" 1800 sx Fondu 950' 950' 4241' 13-3/8" 1600 sx Class 'G' 4258' 4258' 9287' 9-5/8" 2155 sx Class 'G' 9304' 9037' 1811' 5-1/2" 315 sx Class 'G' 9420' - 9630' 8088' - 9056' Perforation depth: measured Above Bridge Plug: 9135'- 9150', 9214'; Below Bridge Plug: 9380', 9420'- 9630', 9660'- 9810' Sqzd: 9150' - 9170' true vertical Above Bridge Plug: 9016' - 9020', 9033'; Below Bridge Plug: 9036', 9036' - 9044', 9046' - 9054' Sqzd: 9020'- 9025' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 tubing to 8084'. Packers and SSSV (type and measured depth) 9-5/8" x 4-1/2" TIW HBBP Packer at 8019' and a 4-1/2" SSSV Landing Nipple at 2102'. 13. Attachments [] Description Summary of Proposal 4. Estimated date for commencing operation 10/01/02 ./ 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Alistair Sherwood, 564-4378 [] Detailed Operations Prog~ C ~ I~IVC~ ~/,/~tch Status of well classifications as: [] Oil [] Gas [] Su~:~r~e~. /J,' ~00~ Service /~_Lq~ka OM & Gas ~n.$; C0mmissi0~ Prepared By Name/Number: Sondra Stewman, 564-4750 17. I hereby certify that the foregping is trL~e and correct to the best of my knowledge Signed ///~' ¢~.., ( Title CT Drilling Engineer Alistair Sherwood Conditions of Approval: Notify Commission so representative ma,~,witness Plug integrity BOP Test /% Location clearance Mechanical Integrity~'~~.~~nt form required 10-. Approved by order of the Commission,.~.,~.///~'///~' ".,,/ .... ... ~ ,., Fo~r~ ~.~ ~ey.j. ~.~,,/1~/~ 2. 0 U ? ," I Approval No.,_~O ~., - ~0~ Commissioner Date (.~/Z~Z Submit In Triplicate To; Winton Aubert Sr. Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Alistair Sherwood CTD Engineer Date: September 20, 2002 Re: CTD Sidetrack of well J-01A The following describes prep work for a CTD sidetrack and is submitted as an attachment to Form 10-403. On or about the 5th October Nordic 2 CTD rig is scheduled to rig up on J-01 and drill a thru-tubing sidetrack, J- 01B to a new Z2A Ivishak reservoir target. In preparation, the following operations will be undertaken on J-01A. Note: a schematic diagram of the proposed sidetrack is attached for reference. 1. Run caliper survey to check the mechanical condition of the production tubing & liner. 2. Perform mechanical integrity tests (MIT) on the inner, (IA) & outer annulus, (OA) 3. Run & set 4F2 x 5Y2" thru tubing whip~fO~k @ 8,830' J 4. P&A perfs below whipstock witi~ 157ts/of 15.8ppg cement, (assume that 25% squeezed away) 5. Isolate & vent production flowline~s-C~emove the wellhouse & level the surrounding pad. Steps 1-5 will be performed between now and the planned arrival of Nordic 2 on the 5th October. Alistair Sherwood CTD Drilling Engineer CC: Well File Terrie Hubble TREE = 4" CAMERON WELLHEAD = CAMERON KB. ELEV = 77.25' 'i~-~';'"~'"~ ......................... -3'8:':4~ <OP = 8662' '~'~"An~i6"~ ....... 96@'~i~6~ "'ba~'~"'i~b'~ ................. 8'§9~'~ ~t'~"~'6'~ ................ ~6~.~.~ 13-3/8" CSG, 68#, ,D= 12.415" I-i 4258' J-01A So ,OTES: 2102' H4-1/2. OTIS HXO SSSV NIP, ID = 3.813" GAS LIFT MANDRELS Minimum ID = 3.725" @ 8072' 4-1/2" OTIS XN NIPPLE 7954' 8o19' H]4-1/2" OTIS X NiP, ID= 3.813"I 1-19-5~- x ~-~2' ~ H~-~ ~ ,o = ~.o" I 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" Id 8084' TOP OF 5-1/2" LNR Id 8089' PERFORATION SUMMARY REF LOG: GR/CCL ON 03/09/95 ANGLEAT TOP PERF: 73 @ 9135' Note: Refer to Production DB for historical perf data SIZE SF~ INTERVAL Opn/Sqz DATE 3-3/8" 4 9135- 9150 O 07/20/97 3-1/2" 4 9155 - 9170 O 04/19/97 3-3/8" 4 9214 - 9380 O/C 05/28/96 3-3~8" 4 9420 - 9630 C 05/28/96 3-3/8" 4 9660 - 9810 C - 05/28/96 IT°~°~c~ H 8055' 8072' 8084' HI4-1/2" OTIS X NIP, Id= 3.813"I F]4-1/2" OTIS XN NIP, ID= 3.725"I Hl4-1/2" WLEG, ID= 3.958"I 8100' Id FIMD 'Ir 03/09/951 MILLOUT WINDOW - 8558' - 8618' 9300' H3-3/8. BAKER IBP PLUG I 9817' ! 9-5/8" CSG, 47#, L-80, ID= 8.681" Iq 9304' NOV 0 5 I5.1/2" LNR'17#' L-80' 0.0232 bPf' ID = 4.892" Id 9900' I DATE REV BY COMMENTS DATE REV BY COMMENTS 12/79 ORIGINAL COMPLETION :10/03/94 MDO SIDETRA~ COMPLETION 03/14/01 SlS-QAA CONVERTED TO CANVAS 03/15/01 SIS-MD FINAL 07/20/01 RN/'I'P CORRECTIONS PRUDHOE BAY UNIT WELL; J-01A PERMIT NO: 1941110 APl No: 50-029-20020-01 SEC9, T11N, R13E BP Exploration (Alaska) ~ = '- 4" CAMERON WELLHEAD = CAMERON ACTUATOR = BAKER KB. ELEV = 77.25' BF. ELEV = 38.4' KOP = 8662' ~"~'~'i~'-~ .......... -9'6"'~'"~J-3'~'6i Datum MD = 8894' '~i'~'~'b"~ .................... J-01B I Proposed CTD Sidetrack SA. 2102' 3TES: HI4-1/2" OTIS HXO SSSV NIP, ID= 3.813" 13-3/8" CSG, 68#, ID= 12.415" Id 4258' GAS LIFT MANDRELS IMinimum ID = 3.725" @ 8072' 4-1/2" OTIS XN NIPPLE (Nipple Milled to 3.8" ID) J 3.5" XN Nip- 2.75" ID Jd 8040' J4-1/2" 'I'BG, 12.6#, L-80, 0.0152 bpf, ID - 3.958" Jd 8084' TOP OF 5-1/2" LNR Id 8089' T°P°FcEMENT H 8563' 9-5/8" CSG, 47#, L-80, ID= 8.681" Iff 9304' PERFORATION SUMMARY REF LOG: GR/CCL ON 03/09/95 ANGLE AT TOP PEP, F: 73 @ 9135' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9135 - 9150 isolated proposed 3-1/2" 4 9155 - 9170 isolated proposed 3-3/8" 4 9214 - 9380 isolated proposed 3-3/8" 4 9420 - 9630 isolated proposed 3-3/8" 4 9660 - 9810 Isolated proposed 5-1/2" LNR, 17#, L-80, 0.0232 bpf, D=4.892" Id 9900' I 7954' 8019' 8030' 8055' 8072' 8084' I 8100' OTISX NIP, ID = 3.813" J x 4-1/2" TIW HBBP-R PKR, ID = 4.0" J IdTop of 3-3/16" Liner H4.1/2. oTIS x NIP, ID= 3.813" J pi4-1/2" OTIS XN NIP, ID= 3.725"I pi4-1/2" WLEG, ID= 3.958"I Id ELMD 'IF 03~09~95 MILLOUT WINDOW - 8558' - 8618' ~!~0' IflTop of Cement I X-over I 3-3/16" X 2-7/8" cmt'ed and perfedld 10875' 8830' HMechanicaIWhipst°ck 9300' Id 3-3/8" BAKER IBP PLUG J I Id 9817' I DATE REV BY COMMENTS DATE REV BY COMMENTS 12/79 ORIGINAL COMPLETION 10~03~94 MDO SIDETRACK COMPLETION 03/14/01 SlS-QAA CONVERTED TO CANVAS 03/15/01 SIS-MD FINAL 07/20/01 RNFFP CORRECTK)NS PRUDHOE BAY UNrT WELL: J-01A PERMIT No: 1941110 AP1 NO: 50-029-20020-01 SEC9, T11N, R13E BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner ~/~ DATE: November 12, 2000 THRU: Blair Wondzell, P. I. Supervisor FROM- John Crisp, .le~,.~ ~. SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit J Pad November 12, 2000: I traveled to BP's Prudhoe Bay Field J Pad to witness Safety Valve System tests. Safety Valve tests had been ~elaye_d for 2 days--due to blowing sno,w Phase 3 weather conditions. I met with BP rep. Merv Littlelow & discussed SVS tests on J Pad. Merv & I decided that we could safely test valves as soon as Roads & Pads could clean a path to well houses & skid 52. Well houses had fair amount of snow inside the houses due to the extended blow. Testing was conducted in as safe & efficient manner as conditions would allow. The AOGCC test report is attached for reference. SUMMARY: I witnessed SVS tests on PBU J Pad. 8 wells, 16 components tested. No failures witnessed. ._8 Well houses inspected. '-- Attachments: SVS PBU J Pad 11-12-00jc cc; NON-CONFIDENTIAL Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BpX Operator Rep: Merv Littlelow AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Prudhoe Bay Field J Pad Separator psi: LPS 149 HPS 11/12/00 687 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE J-01A 1941110 6871 550 540 P P OIL J-02A 1690970 687 550 550 P P OIL J-03 1690450 J-06 1770200 J-07A 1960870 J-08 1770470 J-09A 1940990 J-10 1800160 J-11A 1961040 J-12 1800170 J-13 1800830 J-14 1830750 J-15A 1981750 J-16 1830880 J-17A 1990920 149 125 125 P P OIL J-18 1831080 687 550 525 P P OIL J-19 1861350 J-20A 1961060 J-21 1870240 J-22 1870170 J-23 1870310 J-24 1870020 J-25 1870680 J-26 1870590 J-27 1870580 687 550 550 P P OIL ,, J-28 1870410 687 550 525 P P OIL JX-02A 1941540 149 125 125 P P OIL J-05B 2000180 687 550 400 P P OIL Wells: 8 Components: 16 Failures: 0 Failure Rate: 0.0% [] 9o Day Remarks: 11/16/00 Page 1 of 2 SVS PBU J Pad 11-12-00jc.xls "~~~ coVER OR BEI ORE ~51A I I- rOI- ALAtJKA ALASka--OIL AND GAS CONSERVATION COMMISSlC~- FIEPORT C. SUNDRY WELL OPE ,ATION$ 1. Operations performed: Operation shutdown__ Stimulate Plugging__ Pull tubing__ Alter casing __ Repair well__ Perforate ~" Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchoraqe, Alaska 99519-6612 4. Location of well at surface 750' SNL, 1245' WEL, SEC. 9, T11N, R13E At top of productive interval 539' SNL, 1930' WEL, SEC. 9, T11N, R13E At effective depth 5242'SNL, 1722' WEL, SEC. 9, T11N, R13E At total depth 107' NSL, 1768' WEL, SEC. 4, T11N, R13E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KB = ~.4' 7. Unit or Property name Prudhoe Bay Unit feet 8. Well number J-OIA (34-4-11-13) 9. Permit number/approval number 94-111 / 10. APl number 50- 029-20020-01 11. Field/Pool Prudhoe Off Pool 12. Present well condition summary Total depth: measured 9900' true vertical 9056' Effective depth: measured 9817' true vertical 9052' Casing Length Size Structural -- Conductor 100' 30" Surface 912' 20" Intermediate 4220' 13-3/8" Production -- Liner 6278' Perforation depth: measured feet Plugs (measured) feet feet Junk (measured) feet Cemented Measured depth True vertical depth BKB 280 sx Permafrost 138 138 1800 sx Fondu 950 910 1600 sx Class "G" 4258 4218 5-1/2" 315 sx C/ass "G" 8089-9900 9135;9155'; 9155'-9170'; 9214;9380', 9420'-9630', 9660;9810' true vertical~ubsea 8938'-8944'; 8944'-8948'; 8956'-8959', 8959'-8967', 8969'-8977' 8048-9016 Tubing (size, grade, and measured depth)4-1/2", Lo80 to 8084' Packers and SSSV (type and measured depth)Packer @ 8019' SSSV @ 2102' 13. Stimulation or cement squeeze summarySee Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2181 28638 169 0 269 Subsequent to operation 2691 39569 221 0 1084 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Opera, ohs I OilX Gas Suspended 17. I herod, by ce.r~ thai the f¢~;"~loing is true,a~..'-~0%ect to the best of my knowledge. ~""!.//¢ 7 //" / Signed /"" ~" .f.,~.~_ ~~ /."~...,_~.~~.~ Title TechnicalAssistantlll Form 10-404 Rev 06/15/88 Service SUBMIT IN DUPLICATE J-01A DESCRIPTION OF WORK COMPLETED REPERF 04/19/97 SUMMARY The following interval were reperforated using 3 1/2" guns, 4 SPF, non orientation and 90° phasing. 9155' - 9170' MD ADDPERF O7/2O/97 SUMMARY The following additional interval were perforated using 3 3/8" guns, 4 SPF, random orientation and 60° phasing. 9135'- 9155' MD Attn. ALAS?tA OiL + GAS CONSERVATION 3001 PORCUPINE DRIVE Ali, 99501. Date: 5 June 1996 RE: Transmittal of Dana Sent by: PJLND CARRY Enclosed, please find the data as described below: - WELL # DESCRIPTION %7° ~f P-O5 1 PFC/PERF FINAL BL+RF /1 CCL FINAL BL+RF -1 PFC/PERF FINAL BL+RF ~ 1 CCL FINAL BL+RF Ul PLS FINAL BL+RF ~1 CCL FINAL BL+RF ~PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF --1 GR/CCL FINAL BL+RF Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 5073.08 5603.12 5786.05 5862.08 6273.02 6565.02 6692.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street SuiZe 20i Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: A 0,3,3 C I n <,;~ i: v '¥ d u a 'i W e 'i 'i 'r3eo'l ocJ'f ca 'l Ma'ter"'¥ ,.,'a 'i ::3 PERMIT DATA T DATA__F' L U S f;'. U i'..I D A T E ..... I.:: I:~ C'; V D 94'~1 '11 ,-4~..~275 T 8386~9064 CH/CNI_/GR 1 08 / 25 / 94 °,9t:.---'il 'l ~//70i6 T M¥,tD SF'ERRY~S FI,'I EVAL 94*~'111 t~.~-0'? R COHP DATE: 10/03/'94 .,...,--. 9a.~-Ill ~op R 09/10 10/'04/'ga,- 02 / 19 / 96 1'i/'0/~/94 1 '1/04/9!-: 94-~111 ~URVEY R 8555~-9899 SPERRY SUN MWD i I/0/~-/'94 96-~111 ~L. L 7990-~.8133 I 10/' 05/9 ~- · Ar'e dr'y d'itch samp'ies ~/as the we'li cor'ed? L 7850'-9148 '1 07,/ 17/"95 r"eqL~'¥ r'ed';' yes ~~cl r'ec¢"i' ved° yes ~Ana'Jys~'s & cJescr"~'pt'forl~/~:d'? yes r'lO STATE Of ALASKA ALAS~"~.OIL AND GAS CONSERVATION COMMISSIr'-- REPORT L..: SUNDRY WELL OPE, ,ATIONS · Operations performed: Operation shutdown Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well Other Oa, //~.~= 56.4' feet Uni Prudhoe Bay Unit 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 750' SNL, 1245' WEL, SEC. 9, T11N, R13E At top of productive interval 539'SNL, 1930' WEL, SEC. 9, T11N, R13E At effective depth 5242' SNL, 1722' WEL, SEC. 9, T11N, R 13E At total depth 107'NSL, 1768' WEL, SEC. 4, T11N, R13E 5. Type of Well: Development X Exploratory __ Stratigraphic Service 8. Well number J-O I A (34-4-11-13) 9. Permit number/approval number 94-111 / 10. APl number 50- 029-20020-01 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 100' Surface 912' Intermediate 4220' Production -- Liner 6278' Perforation depth: measured 9900' feet Plugs (measured) 9056' feet 9817' feet Junk (measured) 9052' feet Size Cemented 30" 280 sx Permafrost 20" 1800 sx Fondu 13-3/8" 1600 sx Class "G" 5-1/2" 315 sx Class "G" 9214'-9380', 9420'-9630', 9660'-9810' Measured depth 138 95O 4258 8089-9900 True vertical depth BKB 138 910 4218 8048-9016 true vertical subsea 8874'-8955', 8974'-9076', 9091'-9163' Tubing (size, grade, and measured depth) 4-1/2", L-80 to 8084' Packers and SSSV (type and measured depth) Paceker @ 8019' SSSV @ 2102' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure FEB 2 3 1996 Alaska Oil & Gas Cons. Commissio. Anchorage 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2181 28638 169 0 269 Subsequent to operation 2691 39569 221 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations I Oil X Gas Suspended__ 17. I hereb_b.y, ceCy that,the fo, r,4~0ing is tru.e a.nC'borrect to the best of my knowledge. S, g n ;d~"'/~//~ ~..~~///~_ ~/~~....~ Title TechnicalAssistantll, Form 10-404 Iqev 06/15/88 0 1084 Service /- WELL J-01a (34-4-11-13) Addperf 6/03/95 The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 9150'- 9170'MD RECEIVED MAR 17 1995 ~aska Oil & Gas Cons. ComrnjSSJ~/l Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 15 March 1995 RE .' Transmittal of Data Sent by: ANCH.EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: WELL '" :.~ l- / z/ ~-12 ~ Z~'--//6~ z-~0 DESCRIPTION PLS/STP FINAL BL+RF GR/CCL FINAL BL+RF GR/CCL FINAL BL+RF Run # 1 Run # 1 Run # 1 ECC No. 1393.03 6237.01 6273.01 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,v~MISSION WI=! ! COMP! L=TION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exp/oration 94-111 3. Address 8. APl Number P. O. Box 196612, Anchora~/e, Alaska 99519-6612 5o-029-20020-01 4. Location of well at surface 9. Unit or Lease Name ~~ Prudhoo Bay Unit 750'SNL, 1245'WEL, SEC. 9, T11N, R13E i' ":~i. ' ii':i,-i ~ 10. Well Number At Top Producing Interval //~"~-" ~'-~ ..........-"" ;: ;) ~~'~ ~ ]1 J-OIA (34-4-11-13) 539' SNL, 1930' WEL, SEC. 9, T11N, R13E '!i' ~ i/'~:.,~/,~0-- -;~ :7~'¥i } ;'~ ~r{.~"~ ~,~ 11.PrudhoeField andBayPOOl At Total Depth Fieid/Prudhoe Bay Pool 107'NSL, 1768' WEL, SEC. 4, T11N, R13E 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 77.25' ! ADL 28281 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 9/23/94 9/26/94 10/3/94] N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I0. Depth where SSSV set fl. Thickness of Permafrost 9900' MD/9056' TVD 9817' MD/9052' TVD YEs [] No [] 2102' feet MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Stove Pipe Surface 100' 36" 280 sx Permafrost 20" 94~ H-40 17' 950' 26" 1800 sx Fondu 13-3/8" 68#/61# K55/J55 17' 4258' 17-1/2" 1600 sx Class "G" 9-5/8" 4 7# N-80 17' 9304' 12-1/4" 2155 sx Class "G" 5-1/2" 17# L-80 8089' 9900' 6-3/4" 315 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 (MDI PACKER SET(MDt Gun Diameter 3-3/8" 4 spf 4-1/2", L-80 8084' 8019' MD TVD 9214'-9380' 8874'-8955' 9420'-9630' 8974'-9076' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9660'-9810' 9091'-9163' ~ ~ r\ ~ DEPTH INTERVAL(MD) AMOUNT& KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 10/9/94 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL DIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence et oil, gas or water. Submit core chips. RECEIVED NOV - 4 199~ A~skz Mil & Gas Cons. Commission Anch0rc. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS , ..,RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Top Zone 3 8714' 8638' Top Zone 2C 8769' 8690' Top Zone lB 9148' 8947' RECEIVE,O A!aska Oil & Gas Cons. C°rnrnission AnChorc 31. LIST OF ATTACHMENTS 32. I hereby certify, that the foregoing is true and correct to the best of my knowledge Signed /~~-~~ Title DriilinoEnoineorSuoervisor Date / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: J-01A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 09/16/94 06:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 14 WO/C RIG: DOYON 14 09/10/94 ( 1) TD: 9304 PB: 9145 09/11/94 ( 2) TD: 9304 PB: 9145 RIG MODIFICATION MW: 8.6 Seawater CLEAR FLOOR PU A LEG EQUIP. & RD AND PREPARE F/YRLY MAINTENANCE & MODIFICATIONS. LOWER DERRICK MOVE T/WEST SIDE PAD T/BEGIN WORK. RIG MODIFICATIONS MW: 8.6 Seawater RIG MODIFICATION AND REPAIR OF VARIOUS RIG COMPONENTS. 09/12/94 (3) TD: 9304 PB: 9145 RIG MODIFICATION MW: 8.6 Seawater RIG MODIFICATION & REPAIR OF SEVERAL RIG COMPONENTS. 09/13/94 ( 4) TD: 9304 PB: 9145 RIG MODIFICATION CONTINUING W/RIG MODIFICATION & REPAIR. MW: 8.6 Seawater 09/14/94 ( 5) TD: 9304 PB: 9145 RIG MAINTENANCE MW: 8.6 Seawater YEARLY RIG MODIFICATION & REPAIR T/VARIOUS COMPONENTS. 09/15/94 ( 6) TD: 9304 PB: 9145 RIG MODIFICATION MW: 8.6 Seawater RIG MODIFICATION & REPAIR T/VARIOUS RIG COMPONENTS. 09/16/94 ( 7) TD: 9304 PB: 9145 RIG MODIFICATION MW: 8.5 Seawater RIG MODIFICATION & REPAIR T/VARIOUS COMPONENTS OF RIG. RECEIVED NOV 19cj AJaska 0il & Gas Cons. Commission Anchorz ,, WELL : J-01A OPERATION: RIG - DOYON 14 PAGE: 2 09/17/94 ( 8) TD: 9304 PB: 9145 09/18/94 (9) TD: 9304 PB: 9145 09/19/94 (10) TD: 9304 PB: 9145 09/20/94 (11) TD: 8583 PB: 8583 WAIT ON ATLAS WIRE LINE MW: 8.5 Seawater R/U FIELD SERVICE AND PULL BPV W/LUBRICATOR ON TREE. R/U LINES CIRC DOWN ANNULUS AND RECOVER DIESEL F/TBG. CHANGE LINES PUMP DOWN ANNULUS AND RECOVER DIESEL F/4.5" TBG, TOTAL OF 137 BBL'S. INSTALL 2 WAY CHECK. N/D TREE REMOVE ADAPTER FLANGE. CHECK LDS AND HANGER THREADS. TBG SPOOL, ADAPTER FLANGE AND TBG HANGER WILL BE REPLACED. N/U BOP'S, RESTACK RECONDITION BOP RAMS, ADD EXTENSION ON CHOKE LINE & RISER, DO LOCK OUT TEST ON RECONDITIONED RAMS, RAM SHAFE SEAL LEAK ON SINGEL GATE, CHANGE SHAFE SEAL AND RETEST O.K. TEST BOP'S TO 250-5000 PSI. FIELD SERVICE PULLED 2 WAY CHECK W/BOP LUBRICATOR. BACK OUT LDS, PULL ON 4.5" 12.6# L-80 MOD-BTS TBG TO 80% OF 288,000# PULLED 230,000# TO SHEAR OUT TIW SBR, PINED TO SHEAR @ 85,000# OVER STRING WEIGHT, PULLED 145,000# OVER P/U WT. NO SHEAR, WAIT ON ATLAS WIRE LINE. P/U DP RIH W/OVERSHOT FISH MW: 8.5 Seawater WAIT ON ATLAS WIRE LINE. R/U ATLAS AND RUN 4.5" CHEMICAL TBG CUTTER, CUT TBG @ 8103' TBG MD IN THE MIDDLE OF JT #1. PULL TBG TO FLOOR. R/U TO CIRC, R/D ATLAS. CBU R/U OTHIS TO RECOVER CONTROL LINE. PULL & L/D 4.5" TBG RECOVERED 26 CONTROL LINE RUBBER PROTECTORS AND 6 STEEL BANDS. R/D OTIS. CONTINUE TO PULL AND L/D 4.5" 12.6# L-80 MOD-BTS TBG TOTAL OF 200 JTS, 5 GLM'S, 1 SLIDING SLEEVE, SSSV AND TBG HGR. R/D TBG TOOLS. MILL 9 5/8" TIW PKR @ 8132' MW: 8.5 Seawater RIH TO 6200' W/FISHING BHA#1, P/U HALLIBURTON 9 5/8" STORM PACKER & SET # 51' BELOW ROTARY. N/D BOP'S REMOVE OLD STYLE CAMERON TBG HEAD, CUT 9 5/8" CSG STUB TO FIT NEW 13 5/8" X 5M TBG SPOOL, N/U TBG SPOOL & BOP'S. TEST BOP'S 250-5000 PSI, ANNULAR TO 3000 PSI, STATE MAN WITNESSED BY LOU, INSTALL WEAR BUSHING. STAB INTO STORM PKR @ 51' TEST 9 5/8" CSG TO 3500 PSI 30 MIN O.K. PULL AND L/D SAME. CONTINUE TO P/U 5" DP AND RIH TO 8073' P/U KELLY AND WORK OVER FISH @ 8073' DP MD. RELEASE TIW LATCH @ 9 5/8" PKR W/RIGHT HAND 10 TURNS. POOH L/D 20' CUT OFF, TIW SBR & LATCH. P/U TRI-STATE FISHING BHA #2 AND RIH TO 8132' STAB-IN PKR CHECK PRT, WORKING. MILL ON PKR. MILLING 9-5/8" SECTION MW: 9.1 Seawater MILL ON 9-5/8" PKR F/8132 T/8135. PKR CAME FREE. HOLE TOOK 76 BBLS. VOID BELOW PKR 74 BBLS. CIRC OUT GAS. POOH W/PKR & TAIL PIPE, LD PKR, 3 JTS OF 4.5" TBG, X NIPPLES W/LEG. LD TOOLS. PU BHA #3 W/9-5/8" SECTION MILL. RIH SLIP & CUT 59.5' DL. RIH T/8600'. CIRC OUT GAS & OIL F/DP. PU 5" DP & RIH T/9078 BRIDGE. CHANGE SEAWATER T/9.1 PPG BIOZAN MILLING FLUID. POOH T/8558. RECEIVED NOV -4 1994 Anchon. ~ WELL : J-01A OPERATION: RIG : DOYON 14 PAGE: 3 09/21/94 (12) TD: 58'( 0) 09/22/94 (13) TD: 8563' (8505) 09/23/94 (14) TD: 8802' ( 239) 09/24/94 (15) TD: 9052' ( 250) 09/25/94 (16) TD: 9254' ( 202) 09/26/94 (17) TD: 9557' ( 303) 09/27/94 (18) TD: 9900' ( 343) PU BHA #1 MW: 9.2 VlS:100 CON'T MILLING 9-5/8" SECTION F/8583 T/8618. CUT 60' SECTION. CBU. POOH LD SECTION MILL W/50% WEAR. PIH OE W/5" DP T/8550. CIRC PIPE VOL. RIH PU DP OFF RACK 9074' HIT BRIDGE. CIRC & BATCH MIX CMT. PUMP 20 BBLS WATER. TEST LINES T/3000. FOLLOW W/365 SX OF CLASS G CMT. FOLLOWED BY 7 BBLS OF WATER. DISPLACE W/126 BBLS MUD. CIP @ 23:30 HRS ON 9/20. PULL 11 STNDS EST. TOP CMT @8300'. CIRC @600 GPM T/CLEAN DP. POOH LD 58 JTS DP. PU DELLY & JET TOOL. WASH OUT BOP'S. PU DRLG BHA #1 & RIH. COND MUD F/KO MW: 8.9 VIS: 56 RIH T/8036. CIRC. & WOC. TIH & TAG CMT @8400. DRILL CMT F/8400 T/8423. PULL UP T/8345 & WAIT ON CMT. APPLY 300# PRESS ON CMT & HOLD. DRLG FIRM CMT F/8423 T/8563. CIRC HOLE CLEAN. POOH LD 40 JTS 5" DP & BHA. MU NEW 6.75 BHA & TEST. RIN PU 3.5" DP. CIRC. & COND MUD F/KO. POOH F/NEW BHA MW: 9.0 VIS: 63 CIRC/COND MUD F/KO. RU ATLAS WL & RUN GYRO ORIENTATION. START KO OUT OF 9-5/8" WINDOW @8563 & DRLG T/8802. CIRC HOLE CLEAN F/TRIP. POOH F/BHA & NEW BIT. DRLG & SVYS @ 9052 MW: 9.2 VIS: 71 POH F/NEW BHA & BIT. CHANGE BHA & BIT ORIENT MOTOR. RIH. CUT DRLG LINE. LAY DOWN 6 JTS DP. MAD PASS F/8583 TO 8802. DRLG & SVYS F/8802-9052' (BUILDING ANGLE). DRLG & SVYS MW: 9.1 VIS: 73 DRLG & SVYS F/9052-9185'. CIRC. HOLE CLEAN. POH F/N MOTOR. (MOTOR FAILURE). CHANGE OUT BHA & MOTOR. RIH-BENCH MARK SVY @ 8798. DRLG & SVYS F/9185-9254' DRLG & SVYS MW: 9.2 VIS: 87 DRLG & SVY F/9254-9316'. CIRC. HOLE CLEAN. POH F/BHA. CHANGE BHA & PICK UP RLL TOOL. RIH & MAD PASS F/9140-9316'. DRLG & SVYS F/9316-9557' CLEAN OUT W/HOLE OPENER MW: 9.4 VIS: 80 DRLG & SURV. F/9557 T/9567. CIRC F/GEO SAMPLES. DRLG T/9900 TD. CIRC HOLE CLEAN. POOH LD 30 JTS OF 5" PIPE F/HOLE OPENER RUN. CHANGE OUT BHA'S. RIH T/SHOE. CUT DL. RIH T/BRIDGE @8861. CIRC DOWN & REAM BRIDGES F/8861 T/9000. NOV -'4 i994 Gas Cons. Commission Anchon ~ WELL : J-01A OPERATION: RIG : DOYON 14 PAGE: 4 09/28/94 (19) TD: 9900' ( 0) 09/29/94 (20) TD: 9900' ( 0) 09/30/94 (21) TD: 9900 PB: 9817 RU & RUN 5.5" LINER MW: 9.3 VIS: 76 REAM W/HOLE OPENER F/9006 T/9900/ CIRC HOLE CLEAN. WIPER TRIP T/SHOE. HOLE IN GOOD COND. CIRC HOLE CLEAN. POOH T/SHOE. DISPLACE HOLE T/SEAWATER @ SHOE. POOH & LD 5" HWDP. & 3.5" BHA. RU T/RUN 5.5" LINER. RIH W/5.5" CASG MW: 8.5 VIS: 27 RU & RUN 45 JTS OF 5.5" 17# L-80 SLT LINER W/BAKER INSERT FLT EQUIP & TIW 9-5/8 X 5.5" CASG HNGR, LINER TOP PKR & TIE BACK SLEEVE. SHOE @9900. PLUG CATCHER @9817 & LINER TOP @8089. CIRC LINER VOL. RU 35 JTS OF 5" DP OUT OF DERRICK & FILL EVERY 10 STNDS. CIRC PIPE VOL. @8500. MU CMT HEAD ON JT. RU 5.5 LINER THRU OPEN HOLE T/TD @9900. NO PROB. CIRC. W/SEAWATER, REMOVE FLOPRO MUD. BATCH MIX TAIL CMT. TEST LINES T/4000. PUMP 20 BBLS MCSA NON WEIGHTED, 70 BBLS MCS4 WEIGHTED T/10.3 PPG, FOLLOW W/25 BBLS (50SX) WT @ 10-13.2 PPG, 53 BBLS) (265 SX) TAIL CMT. KO DART W/5 BBLS WATE & DISPLACED W/175 BBLS SEAWATER. 9 BPM BUMPED PLUG W/3500PSI. SET HANGR & BLEED OFF. SET PKR. CIP @ 21:45 HRS. REV. CIRC OUT 23 BBLS CMT & 70 BBLS SPACER, 20 BBLS PREFLUSH. REV OUT 'TIL CLEAN. TEST CASG & LINER TOP PKR T/3500. OK. POOH & BRK DOWN CMT HEAD. PU 4.75" ECONO NILL, 5.5" CSG SCRAPER, 12 3-1/18" DC'S, 45 2-7/8" 8.7# DSS TBG, X/O T/4.5" IF, TOTAL 1810' RIH W/5" DP. RIH W/RTTS T/CHK LINER MW: 0.0 Seawater CON'T RIH W/4.7" MILL, 5.5" SCRAPER, 12) 3-1/8" DC'S. 45 JTS 2-7/8" TBG ON 5" DP. TAG CMT @9803. RETEST CASG T/3000. BLEED OFF 500 IN 5 MIN. FAILED. C/O CMT F/9803 T/9815 LNDG COLLAR DPM. CBU. POOH & STND BACK 5" & TBG LD MILL & SCRAPER. PU 9-5/8" RTTS TOOL & TIW 7.5 X 6 SEAL ASSY & RIH T/4000. TEST CASG T/3000. OK. CON'T T/ RIH T/5.5" LINER TOP @8087' DPM. STAB INTO TIE BACK SLEEVE W/TIW SEAL ASSY @8087. PUMP DOWN DP PRESS UP T/2500. PRESS LOSS T/1000. BLEW UP -5.5" PARTED. BLEED OFF PRESS T/ANNUL. PRESS UP T/3000. HELD 10 MIN. W/NO PRESS LOSS. GOOD TEST. LINER TOP PKR HOLDING. PU & SET RTTS @8060. PUMP DOWN DP PRESS. UP T/3000. 600 PSI LOSS IN 3 MIN. 1200/5MIN. RESET SEAL ASSY IN TIE-BACK. PRESS UP INJECTING @ 1200PSI. HOLE IN 5.5 LINER. PU. CBU CHK F/GAS.POOH LD 9-5/8" RTTS & TIW SEAL ASSY. PU 5.5 RTTS TOOL & 1200 OF 2-7/8". RIH T/FIND HOLE IN 5.5" LINER. RECEIVED NOV Oil & Gas Con,~o Commission Anchor; WELL : J-01A OPERATION: RIG : DOYON 14 PAGE: 5 10/01/94 (22) TD: 9900 PB: 9815 10/02/94 (23) TD: 9900 PB: 9815 10/03/94 (24) TD: 9900 PB: 9815 L/D 7 JTS 2 7/8" & 12 3/8 DC'S MW: 8.5 Seawater CONTINUE TO RIH W/HOWCO 5.5" RTTS TOOL ON 1172' OF 2 7/8" BHA TO 8000'. SLIP AND CUT DRLG 59.5' DRLG LINE. CONTINUE RIH TO 9170' SET RTTS. TEST CSG DOWN ANNULUS TO 3000 PSI 30 MIN TEST OK. POOH (SLM) O.K. NO CORRECTION L/D RTTS. P/U 4.75" MILL AND 5.5" CSG SCRAPER ON 2 7/8" BHA RIH TAG PLUG CATCHER @ 9815' CPM, DID NOT SEE LINER TOP. REVERSE CIRC AND DISPLACE HOLE W/CLEAN FILTERED SEAWATER. POOH L/D 7 JT'S 2 7/8" DSS AND 12 3 1/8" DC'S MILL & SCRAPER. L/D PERF GUNS MW: 8.5 Seawater CONTINUE TO L/D 3 1/8" DC'S CLEAR FLOOR. R/U TO P/U ATLAS 3 3/8" SPECTRA JET TCP GUN'S @ 4 SPF 60/120 DEGREES PHASING. HELD 15 MIN SAFETY MEETING ON TCP GUNS. P/U SAME. RIH W/5" DP TO 6379'. ATTEMPT TO CLOSE HOWCO FAST FILL VALVE PRESSURE UP TO 1500 PSI WOULD NOT CLOSE. POOH TO HOWCO FAST FILL VALVE, CHANGE OUT SAME RERUN TO 6097' CLOSE FAST FILL OK RIW/3435' DRY PIPE FOR 100 PSI DIFFERENTIAL DRAW DOWN. TAG UP @ 9815' P/U AND SPACE GUNS TO PERF 9214-9380' 9420-9630' 9660-9810'_ R/U HOWCO TEST MANIFOLD AND TEST HEAD, TEST EQUIP TO 3000 PSI OK SHOT FLUID LEVEL 3460' PRESSURE UP ANNULUS TO 2000 PSI FIRE GUNS @ 1841 HRS. BUBBLES IN BUCKET 2 MIN. STRONG VLOW OPEN TO TEST TANK, SHOT FLUID LEVEL @ 1910 HRS 30 MIN FLUID LEVEL @ 1760' 30 BBL INFLUX OPEN BYPASS @ 1927' REVERSE CIRC 29 BBL'S FLUID TO SURFACE CIRC ONE PIPE VOLUME TO TEST TANK, AND ONE TO SLOP TANK TILL FLUID CLEAN. CHANGE TO PUMP LONG WAY. UNSEAT PACKER CIRC COMPLETE HOLE VOLUME FLUID LOSS 25 BPH WHILE CIRC. POOH L/D DRILL PIPE. BREAK KELLY. L/D HOWCO 9 5/8" RTTS, 2 7/8" TBG @ ATLAS 3 1/8" FIRED GUNS NOW FLUID LOSS WHILE LAYING DOWN 360 BBL'S AVERAGE 40 BPH. CIRC & PUMP CORREXIT AROUND MW: 8.5 Seawater CONTINUE TO L/D ATLAS 3 1/8" PERF GUNS. ALL GUNS FIRED R/D & CLEAR FLOOR. R/U TO RUN 4.5" PRODUCTION TBG. LOAD PIPE HOUSE W/JEWELRY. HOLD SAFETY MEETING. RUN 198 JTS 4.5" 12.6% L-80 MOD-BTRS TBG (USED). 9 5/8" TIW HBBP PKR, SET @ 8019', "XN" 8017', "X" NIPPLE'S @ 8054' & 7954', BLM'S @ 7885' ~7779' 6821' & 4191' AND SSSV @ 2101' (TORQUE BTRS , TBG TO 3600 FT/LB AVG.). M/U TBG HGR AND CONTROL LINES TEST TO 5000 PSI O.K., LAND TBG TORQUE LDS TO 450 FT/LB. N/D BOP'S, BREAK AND TURN BOSS SPOOL SET BOP'S BACK. M/U ADAPTER FLANGE & NEW 4" CAMERON TREE TEST TO 5000 PSI CONTROL LINES AND TREE ALL O.K. R/U RIELD SERVICE LUBRICATOR AND PULL 2 WAY CHECK. REVERSE INCORREXIT CORROSION INHIBITER. WELL : J-01A OPERATION: RIG : DOYON 14 PAGE: 6 10/04/94 (25) TD: 9900 PB: 9815 SIGNATURE: CONTINUE PUMPING CORREXIT MW: 8.5 Seawater CONTINUE PUMPING CORREXIT AND DROP BALL. R/U LINES PRESSURE UP ON TBG TO 3500 PSI SET TIW 9 5/8" HBBP PKR HOLD FOR 30 MIN O.K. BLEED PRESSURE TO 1300 PSI. CHANGE LINES AND TEST 9 5/8" X 4.5" CSG ANNULUS TO 3500 PSI HOLD 30 MIN. OK.K BLEED TBG PRESSURE AND "RP" VALVE OPENED @ 2900 PSI. R/U LITTLE RED HOT OIL UNIT PUMP 150 BBL'S DIESEL DOWN ANNULUS TAKING RETURNS F/TBG. USED 6300 GL'S FOR FREEZE PROTECTION. HOOK UP AND "U" TUBE DIESEL TO BALANCE. TBG PRESSURE WOULD NOT GET BELOW 150 PSI. FOR 2100' FREEZE PROTECTION. LOOKS LIKE A GOOD WELL. CALL FIELD SERVICE TO LUBRICATE BPV. PUMP OUT TANKS. R/U FIELD SERVICE AND LUBRICATE IN AND SET BPV. DATE: (drill~ng~supe~ntendent) SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 SHARED SERVICE DRILLING PBU/J-01A 500292002001 NORTH SLOPE COMPUTATION DATE: 9/28/94 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN 8555 8554.10 8480.10 8662 8660.69 8586.69 8724 8720.97 8646.97 8756 8751.42 8677.42 8789 8783.55 8709.55 DATE OF SURVEY: 092694 MWD SURVEY JOB NUMBER: AK-MW-40079 KELLY BUSHING ELEV. = 74.00 FT. OPERATOR: BP EXPLORATION COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 2 7 S 41.00 W .00 9 18 N .00 E 10.27 17 19 N 4.64 W 13.04 18 32 N 7.29 W 4.61 18 14 N 5.94 W 1.56 63.30S 53.20W -37.97 56.13S 54.50W -30.85 41.89S 55.25W -17.42 32.10S 56.28W -7.98 21.48S 57.51W 2.29 8822 8813.75 8739.75 8851 8840.74 8766.74 8883 8868.06 8794.06 8914 8893.52 8819.52 8945 8917.29 8843.29 21 45 N 10.54 W 11.99 26 44 N 14.41 W 17.65 32 59 N 16.22 W 20.03 38 6 N 15.98 W 16.36 42 57 N 20.63 W 18.24 10.62S 59.12W 12.94 1.24N 61.79W 24.91 16.36N 65.95W 40.47 33.84N 71.00W 58.55 53.11N 77.41W 78.80 8974 8937.31 8863.31 9005 8956.62 8882.62 9036 8974.06 8900.06 9068 8989.97 8915.97 9099 9003.71 8929.71 48 49 N 21.74 W 20.58 54 57 N 21.86 W 19.63 57 2 N 21.70 W 6.68 61 37 N 22.09 W 14.72 66 45 N 25.73 W 19.32 72.36N 84.89W 99.44 95.21N 94.03W 124.05 119.22N 103.62W 149.91 144.12N 113.63W 176.73 170.06N 125.15W 205.11 9130 9014.22 8940.22 9146 9018.75 8944.75 9175 9026.35 8952.35 9207 9032.61 8958.61 9238 9035.75 8961.75 72 44 N 27.27 W 20.24 74 20 N 27.36 W 10.02 76 7 N 27.14 W 6.05 81 5 N 27.79 W 15.80 87 10 N 28.67 W 19.94 195.57N 137.88W 233.55 209.19N 144.91W 248.83 234.81N 158.11W 277.56 262.40N 172.45W 308.54 289.38N 186.94W 339.01 9271 9036.85 8962.85 9292 9037.03 8963.03 9327 9036.80 8962.80 9356 9036.18 8962.18 9386 9035.62 8961.62 89 4 N 29.05 W 5.79 89 54 N 29.26 W 4.08 90 51 N 28.77 W 3.13 91 33 N 29.04 W 2.55 90 34 N 31.44 W 8.61 318.65N 203.07W 372.24 336.96N 213.28W 393.08 366.86N 229.87W 427.05 392.64N 244.10W 456.33 418.64N 259.26W 486.15 9419 9035.72 8961.72 9450 9036.03 8962.03 9480 9036.37 8962.37 9510 9037.25 8963.25 9544 9039.02 8965.02 89 3 N 29.86 W 6.67 89 49 N 30.55 W 3.30 88 51 N 30.98 W 3.54 87 49 N 31.02 W 3.45 86 13 N 30.14 W 5.34 447.01N 276.07W 518.80 474.08N 291.83W 549.86 499.60N 307.02W 579.25 525.43N 322.54W 609.07 554.81N 339.90W 642.86 9576 9041.10 8967.10 9606 9043.02 8969.02 9637 9044.67 8970.67 9668 9046.58 8972.58 9699 9048.74 8974.74 86 7 N 30.46 W 1.07 86 44 N 30.10 W 2.29 87 3 N 30.48 W 1.61 85 56 N 30.82 W 3.69 85 52 N 31.52 W 2.31 581.59N 355.55W 673.60 608.23N 371.10W 704.18 634.49N 386.45W 734.32 661.32N 402.34W 765.19 687.30N 418.06W 795.22 MICROFILMEi RIGiNAL RECEIVED hi~si;~ i~il & 6a$ Con~. Corr~r~ission Anc.~or: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICE DRILLING PBU/J-01A 500292002001 NORTH SLOPE COMPUTATION DATE: 9/28/94 DATE OF SURVEY: 092694 MWD SURVEY JOB NUMBER: AK-MW-40079 KELLY BUSHING ELEV. = 74.00 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 9729 9050.74 8976.74 86 39 N 30.29 W 4.72 9761 9052.35 8978.35 87 26 N 31.36 W 4.27 9791 9053.54 8979.54 88 5 N 30.68 W 3.08 9822 9054.49 8980.49 88 22 N 32.32 W 5.35 9855 9055.19 8981.19 89 11 N 32.42 W 2.55 713.59N 433.79W 825.54 740.38N 449.78W 856.42 766.56N 465.52W 886.64 793.02N 481.74W 917.31 820.66N 499.26W 949.56 9899 9055.80 8981.80 89 11 N 32.40 W .05 857.46N 522.63W 992.52 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1004.18 FEET AT NORTH 31 DEG. 21 MIN. WEST AT MD = 9899 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 337.38 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICE DRILLING PBU/J-01A 500292002001 NORTH SLOPE COMPUTATION DATE: 9/28/94 DATE OF SURVEY: 092694 JOB NUMBER: AK-MW-40079 KELLY BUSHING ELEV. = 74.00 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 8555 8554.10 8480.10 9555 9039.68 8965.68 9899 9055.80 8981.80 63.30 S 53.20 W .90 563.48 N 344.93 W 515.32 514.42 857.46 N 522.63 W 843.20 327.89 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICE DRILLING PBU/J-01A 500292002001 NORTH SLOPE COMPUTATION DATE: 9/28/94 DATE OF SURVEY: 092694 JOB NUMBER: AK-MW-40079 KELLY BUSHING ELEV. = 74.00 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 8555 8554.10 8480.10 8574 8574.00 8500.00 8675 8674.00 8600.00 8779 8774.00 8700.00 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 63.30 S 53.20 W .90 63.51 S 53.64 W .91 .01 53.73 S 54.54 W 1.53 .62 24.61 S 57.19 W 5.81 4.28 8890 8874.00 8800.00 9036 8974.00 8900.00 9899 9055.80 8981.80 20.27 N 67.09 W 16.33 10.53 119.21 N 103.62 W 62.93 46.60 857.47 N 522.63 W 843.20 780.27 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS Petrotechntcal Data 8P Exploma~ton (Alas. 900 East Benson Boulevard ~cnorage, ~as~ 99908 Received Date ..... ' LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: '~ 23 September 1994 Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 CCL/TUBCUTR.FINAL BL 1 CCL/TUBCUTR RF SEPIA ECC No. Run # 1 1590.02 Run # 1 Run # 1 5812.03 Run # 1 Run # 1 5953.05 Run # 1 Run # 1 6047.01 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 6075.05 6162.03 Run # 1 6271.00 Run # 1 Run # 1 6273.00 Run # 1 R CEi¥[D OC1- 0 5 1994 Please sign and return to: Atlas Wireline S~ ~~ Alaska Oil & Gas Cons. CommissionAnchorage Anch~ge ,. AK,~99518 ~~~~. Paulson MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Blair Wondzell, ~ P. I. Supervisor FROM: Lou Grimaldi, ~- SUBJECT: Petroleum Inspector DATE: September 18, 1994 FILE NO: AIGJIRBD.DOC BOP Test Doyon rig #14 BPX well # J-1 Prudhoe Bay field PTD # 94-127 ~ ~ ~-""'~ I Sunday, September 18, 1994: I traveled to Doyon rig #14 to witness the weekly BOP test on their rig which is presently drilling BPX well # J-1 in the Prudhoe Bay Field. The rig was changing the casing head when I arrived. The test once staded went very well with all components functioning properly and holding its pressure test. There were two leaks, one on the upper pipe rams door and one on the 90 degree block in the choke line, they were tightened and retested "OK". As both these connections had been broke before the test I did not consider these failures. The test lasted 2.5 hours with no failures observed. I found the rig to be in very good condition. Summary: I witnessed the weekly BOP test on Doyon rig #14. Test time 2.5 hours. No failures. Attachment: AIGJIRBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: DOYON Rig No. 14 PTD # BPX Rep.: J-1 Rig Rep.: Set @ Location: Sec. Weekly X Other 94-217 DATE: 9/18/94 Rig Ph.# 659 - 4510 DON WESTER MO R T HEA VIRLA ND g T. 11N R. 13E Meridian U TeSt , ,~:i MlSC, INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure P/F Location Gen.: OK Well Sign OK Upper Kelly/IBOP I 1250/5000 P Housekeeping: OK (Gen) Drl. Rig OK Lower Kelly /IBOP 1 1250/5000 P Reserve Pit N /A Ball Type I 1250/5000 P Inside BOP 1 1250/5000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F Test 1 500/3000 P Pressure 250 / 5000 1 250/5000 P 1 250/5000 P I 250/5000 P 3 250/5000 F 2 250/5000 P 3 250/500O P N~ N~ MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Gas Detectors OK OK CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes P/F P 36 250/5000 P I P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: 4 (~ 2100 3,000 J P 1,700 P minutes 26 sec. minutes 46 sec. YES Remote: YES Psig. · : : Number of Failures: 0 ,Test Time: 2.5 Hours. Number of valves tested 26 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: GOOD TEST, Leak in choke line argO deg. block. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c -Inspector FI-021L (Rev. 7/19) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: AIGJIRBD.XLS Louis R Grimaldi ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 25 August 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: #/ DESCRIPTION 1-29 M-25 ~~.. 1~~ PDK LDWG TAPE+LISTER ECC No. Run # 1 3235.03 Run ~ 1 3987.02 Run # 1 4731.01 Run # 1 5764.04 Run # 1 5765.03 Run # 1 5808.03 Run # 1 6069.01 Run # 1 6238.03 Please sign and return to: Atlas Wireline Services 5600 B Street AS~oer2a~el, AK 99518 % '~' At~~ey D. P aulson~-~ ~~ Ip Re ce ived ~_~/~_/~~/////~~. D at e .'~%~.~%~,~~. %~ lease s i~n ~d ~~ ~o: , 'Petrotechnical Da~a Cen%e~ BP Exploration (Alaska) Ine 900 East Benson Boulevard Anchorage, Alaska 99908 Received by 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 August 24, 1994 Adrian Clark Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit J-01A BP Exploration (Alaska), Inc. Permit No. 94-111 Sur. Loc. 750'SNL, 1245'WEL, Sec. 9, TllN, R13E, UM Btmnhole Loc. 107'NSL, 1600'WEL, Sec. 4, TllN, R13E, UM Dear Mr. Clark: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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) ~ust be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrill EIIlb. Type of well. ~'x'ploratoryr-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenCII Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 77.25' feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. 0. Box 196612. Anchorac~e. Alaska 99519-6612 ADL 28281 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 750' SNL, 1245' WEL, SEC. 9, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 515' SNL, 1411' WEL, SEC. 9, T11N, R13E J-OIA (34-4-11-13) 2S100302630-277 At total depth 9. Approximate spud date Amount 107' NSL, 1600' WEL, SEC. 4, Tl lN, R13E 9/1/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property 15. Proposed depth (MD and TVD) property line ADL 28282-3680' feet No close approach feet 2560 10118' MD/9051' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.o35 (e)(2)) Kickoff depth 85z5' feet Maximum hole angle89.~ o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD MD TVD (include stage data) 6-3/4" 5-1/2" 17# L-80 S TL 1868' 8425' 8425' 9861' 9861' 170 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~, l,.~, ~ ' Present well condition summary Total depth: measured 11871 feet Plugs (measured) ~0Co '~ c~ true vertical 11869 feet Effective depth' measured 9085' feet Junk (measured) ~i\~SV.~. 0~'~ & G~s COOS. true vertical 9083' feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 83' 20" 280 sx PF 100' 100' S u rface 933' 20" 1800 sx Fondu 950' 950' I nte rm e d i at e 4241' 13-3/8" 1600 sx "G" 4258' 4258' Production L i n e r 928 7' 9-5/8" 2155 sx "G" 9304' 9302' Perforation depth: measured 9019'-9056'(open) 8878'-9056' (squeezed interva/s) true vertical 9018'-9055' (open) 8877'-9055' (squeezed intervals) 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid prog?~n [] Time vs deptl~ plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certi~/~_~t,h'b~.t~,~/%/?/'U~cfe'reg°in///~, ~is true and correct to the best of my knowledge -~/'_ /' Signed *~' // / / ~-''/':'*' '~.'~ Date ~/// ;-' v k ~ '.,~.-~C-~' -~' '~- Title Drilling Engineer Supervisor ~ ~ '- Commission Use Only Permit Number IAPI number IApproval_date ., . ISee cover letter ?¢_is o- 0 ~ ¢ - ~ 0 o 2..0 - c~ ? I ~:?~ "- c~)'~-''x~7'¢1f°r other requirements Conditions of approval Samples required [] Yes ,[~ No Mud log required []Yes J~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~ Yes [] No Required working pressure for DOPE [] 2M; 1-13M; J~5M; 1-110M; I-I15M; Other: Original Signed By by order of Approved by David W. Johnston Commissioner zne commmsion~,Date.. .~//'z'~f'"c~f.. ,, Form 10-401 Rev. 12-1-85 Submit in triplicate IWell Name: I J-O1A Redrill Plan Summary Type of Redrill (producer or in~ector): PRODUCER Surface 749.42 FNL 1 244.94 FEL S09 T11N R13E UM Location: Target Location: 514.55 FNL 1410.80 FEL S09 T11N R13E UM Bottom Hole 1 06.58 FSL 1600.46 FEL S04 T11N R13E UM Location: AFE 4P0613 Number: JRig: J DOYON RIG #1 4 Estimated Start Date: 01SEP94 Operating days to complete: 19 I'rvD: 19,os~' I Well Design (conventional, slimhole, etc.): HORIZONTAL SIDETRACK I.Objective I SADLEROCHIT A 9.5 - 10.00 ppc~ Mud Program: Biozan polymer/KCI water based mud will be used. Special design A NON-DAMAGING XANVIS POLYMER MUD AT 8.6-9.0 PPG considerations WILL BE USED TO DRILL THE 6-3/4" HOLE INTERVAL. ALSO, UPON FURTHER REVIEW OF THE DRILLING HISTORY A WATERBASED SYSTEM MAY BE SUBSTITUTED FOR THE BIOZAN POLYMER. Depth Density PV YP INT IOMIN FL OIL I SOLIDSI (TVD) (PPG) (CP) (#/FT) GEL GEL cc30/min KOP' 9.5 1 0 1 5 5 10 5 0 5 to to to to to to to to to TD' 10.0 18 25 15 Z0 6 0 8 Directional: I KOP: 18,S7S' MD/8,574' TVD I M~ximum Hole 89.1 ° Angle: Close Approach NONE Well: The above listed wells will be secured during the close approach. RiC, EiVED Gas Cons. Commission Anchorage Casin i/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 6-3/4" 5-1/2" 17# L-80 STL 1868' 8425'/8425' 9861 '/9861' TUBING 4-1/2" 12.6# L-80 TDS OR 9,000' SURFACE 8870'/8863' BTC-MOD Cement Calculations: Basis: Liner 5-1 / 2" Size: 50% open hole excess, 80' shoe joint, 150' liner lap and 150' excess above liner with DP. Total Cement Volume: 1701 sxs of Class G Blend 1.1 7. ft3/sx Liner Size: Basis: above liner with DP. Total Cement I I Volume: 50% open hole excess, 80' shoe joint, 1 50' liner lap and 1 50' excess sxs of Class G Blend 1.1 7. ft3/sx Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. /~UG q 9 1994 Alas~,a, {Jii & Gas Cons. Commission Anchora.~-: SUMMARY PROCEDURE: , . 3. 4. 5. 6. 7. . . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. Pre-rig work. Cut the 4-1/Z". 12.6#. L-80. BTC-MOD tubing near 8104' MD. Displace well to seawater. Freeze protect tubing and annulus to 2200' md and set a BPV. Move in drilling rig. Pull BP¥. Circulate diesel freeze protection cap from well and recover for future use. Install a BPV and tree test plug. Remove the production tree. Install BOP's and test to 5000 psi. Remove the test plug and BPV. Pull and lay down the 4-1/2" tubing. Displace well to milling fluid. Cut a 50' section in the 9-5/8" casing starting from about +8575'MD. Spot a balanced cement kick-off plug through open-ended drillpipe from PBTD to 200' above the top of the section (this will serve both as an abandonment plug as well as the kickoff plug). Run in with an 4-3/4" steerable drilling assembly and a 6-3/4" bit with gamma ray/directional MWD and dress the cement to 5' below the section top. Kickoff and displace well to FLO-PRO system. Continue to directionally drill to TD at _+9862' md which should yield +1000' of horizontal section (see attached directional plan). Make a conditioning trip with a 6-3/4" hole-opener for the open hole section and with a 9- 5/8" casing scraper spaced to clean the casing. Install a 5-1/'2", 17". L-80 . STL SOLID liner with 5-1/2" X 9-5/8" packer/hanger. Space packer / hanger to be set within about 150' of the 7-5/8" liner shoe. Cement the liner in place with the total cement volume based upon 50 % open-hole enlargement plus the 80' shoe volume, 150' lap volume and 150' excess on top of the liner with drillpipe in the hole. Re-test BOP's as needed. PU 3-1/8" BHA. RIH and cleanout liner. Displace well to seawater. POOH and LDDP. RIH with drillpipe conveyed perforating assembly and perforate the well. Run the 4-1/2" L-80 completion string assembly re-using as much of the 4-1/2" tubing and jewelry that was pulled from the well. Space out and circulate with corrosion inhibitor. Install a BPV and test plug. Remove BOP's. Install and test the production tree to 5000 psi. Pull tree test plug and BPV. Set packer. Test the tubing x casing annulus to 3500 psi for 30 minutes. Shear RP valve in the upper GLM and freeze protect the well. Set a BPV. Release rig. Complete appropriate documentation and hand-over to Production. ,! Pr, udl.qoe Bay D", il. Ii n g Pr, uolhoe o,7' Unit ..J-PA'D J-O'l A Wp7 ~TIE~L ~ ~F- ~L~D ~r[C~ ~CT~ ~. ~L~AD 8424 8451 -- 8516 CLRI'HC. AL [-~]N'1' L~ATA fEZ LCU T_V TJ'~ T..~ TJ~ ~ RiVE~ SHJT~)K ~ 4/4B ? tNIF.qP~A'I~D 8'.03~IE03 Z~ 4A I × END I]F ~£ &7,SRT Ed:' 18,4~f1C0 ft ZEI~ FR~SEN~ ~qc ZD~ ~ / lB END ~- CL~VE ~3 ].St° 2~,11° 69~3 41 S 40 W 71~ ~97° 240.24° 71~ 44 S 44 W 7[49 O~ R40.~ 7149 44 g 44 ~ 74~ O~ 818.34° 74~ 47 g 47 ~ 7643 ~ ~.4~° 7~43 ~ S 4B ~ ~ t.~~ ~1,11° 7~ ~$ ~ 8i33 0.~ 1~.55° 81~ ~ S 5~ ~ ~65 0.~ I~4-~~ 55 ~ S 51 ~ ~4 1 .~ I ~ 84~4 ~ S 51 ~ ~61 t.~ i~L~ 8461 61 S ~ W ~40 ~.070 ~tSO~ ~40 63 S 53 W ~ ~.~t° 2~ ~74 C~ S ~ W ~3 3.~° ~.8~ ~ ~ g ~ W ~71 8.~ ~) 8769 49 S 67 W 8774 8.~° '~. l~ 8772 49 S 67 ~ ~ 4g~ 3407~ ~ 48N l~ ~70 63.~ 34[.6~ ~4 l~ N 12~ ~ ~18 ~.~ 34~.~ ~37 8~ N L~ ~ 9K'0 147 I t I 0 IE~) 200 vtR'rlO:q_ SECTiI]Xl Pt~X~: _-'.'37.35~ WELLPLAN FEASIBILITY STUD'/ ; This plan is for f~.asibility purposes only, ' it h~s not yet ~e~ c~rd~, i i I I-O;~Kl~froL VIE~r CIR._ ~-RIHi, 103 f-L / DLVIS,1EN SL~vEY I~: ~ILkEA1) j H~N_LIBL~TEN 1~,/9/g4 ~SP em 103 1003 gOO 800 703 4/X) 500 4[0 ~ ~ ICO o tOd EO0 ~SB ~ 'TVD g047.61 ~D g861.76 r,b'S EI~ 357.45 Dote F~ot~ed STATE OF ALASKA ALAS, .., OIL AND GAS CONSERVATION COMMISSIL.., APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend __ Operation Shutdown__ Re-enter suspended well~ Alter casing , Repair well__ Plugging X Time extension__ Stimulate ~ Change approved program __ Pull tubing ~ Vadance __ Perforate __ Other X ~ Plugback for redrlll 2. Name of Operator - BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 750' SNL, 1245' WEL, SEC. 9, T11N, R13E At top of productive interval 822'SNL, 1310' WEL, SEC. 9, T11N, R13E At effective depth 828' SNL, 1322' WEL, SEC. 9, T11N, R13E At total depth 833'SNL, 1329' WEL, SEC. 9, T11N, R13E 5. Type of Well: Development X Exploratory __ Stratigraphic ~ Service DUPLICATE 6. Datum elevation (DF or KB) KBE = 55.43 7. Unit or Property name Prudhoe Bay Unit 8. Well number J-01 (31-09-11-13) 9. Permit number 69-40 10. APl number 50- 029-20020 11. Field/Pool Prudhoe Bay Field/Oil Pool feet 12. Present well condition summary Total depth: measured true vertical .Effective depth: measured true vertical 11871 feet Plugs (measured) 11869 feet 908,5. feet Junk (measured) 9083 feet fill @ 9085' WLM (3/90) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 83' 933' 4241' 9287' Size Cemented Measured depth 30" 280 sx Permafrost 20" 1800 sx Fondu 13-3/8" 1600 sx Class "G" 100' 950' 4258' 9-5/8" 2155 sx Class "G" measured 9019'-9056' (Open) 8878'-9056' (10 squeezed intervals) true vertiCal 9018'-9055' (Open) 8877'-9055' (10 squeeze intervals) 9304' Tubing (size, grade, and measured depth) 4-1/2", L-80 to 8144' w/4-1/2" tailpipe to 8247' MD Packers and SSSV (type and measured depth) 9-5/8" TIWpacker@ 8144'MD; 4-1/2" SSSV@ 2162'MD True vertical depth 100' 950' 4258' 9302' RECEIVE AUG 1 2__ 199,t AlaSka. bll & Gas Cons. C0r Anchorage 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: 8/16/94 16. ff proposal was verbally approved Oil x Gas __ Name of approver Date approved Service 17. I hereby c~th~e and correct to the best of my knowledge. Signed _'~~~' Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Suspended~ Conditions of approval: Notify Commission so representative may witness Plug integrity ,..~'"' BOP Test~ Location clearance~ Mechanical Integrity Test Subsequent form required 10- ;yo ~ ,,-.~ ~-.~. w~ /-~,,~ ~,~,-,,¢.A ~.,,,:. Original Signed By Approved by order of the Commission David W. d0hnstrm Form 10-403 Rev 06/15/88 Approved Copy Returned Commissioner SUBMIT IN TRIPLICATE ~missi0[~ WELL PERMIT CHECKLIST F~E~,D ~ POOL d; '7, c,./5 ~ WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev [] redrll~ aery [] //~o o~oFF s~o~ ADMINISTRATION 1. Permit fee attached ................... 2. Lease number appropriate ............... 3. Unique well name and number .............. Y 4. Well located in a defined pool ............. Y Y 5. Well located proper distance from drlg unit boundary... 6. Well located proper distance from other wells ..... '7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. I.Y 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ........ ~ ENGINEERING APPR~ D~/~ 14. Conductor string provided ................ Y N~ 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg.. Y N 17. CMT vol adequate to tie-in long string to surf csg . . . Y N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ N 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate .?~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~O~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. Y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/. 31. Data presented on potential overpressure zones ..... y ~v ~ i ......... ~/~ /<Y,~ ' 34. Contact name/phone for weekly progress reports .... [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: 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. PRUDHOE BAY Run 1' 06 - August - 1994 CN/GR Cased Hole 1386 }064 lilt. STERN ATLAS Atlas Wireline Services Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT 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: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING J - 01 (09-11-13) 500292002000 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 12-AUG-94 3987.02 L. KOENN J. MELVAN 9 liN 13E 750 1245 56.40 55.40 38.40 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) .0 .00 .0 .00 9.625 9304.0 47.00 4.500 8247.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BHCS GR 2 1 14-MAY-69 SWS BASELINE DEPTH 8394.5 8416.0 8445.5 8460.0 8461.0 8467.0 8474.0 8481.5 8496.0 8501.0 8512.5 8516.5 8541.0 GRCH 8397.5 8418.5 8449.5 8463.5 8465.0 8469.5 8478.0 8485.5 8500.0 8505.0 8516.0 8520.5 8544.0 - EQUIVALENT UNSHIFTED DEPTH 8560.5 8572.0 8588.0 8617.0 8624.0 8663.0 8696.0 8700.5 8862.0 8901.0 8923.5 9014.5 9019.5 9038.5 9045.0 $ REMARKS: 8564.0 8575.5 8591.5 8620.5 8627.0 8667.0 8699.0 8704.0 8865.0 8903.5 8926.0 9017.0 9021.5 9041.0 9047.5 CN/GR Cased Hole. LOG TIED TO CNL LOG PASS #3 DATED 22-DEC-81. GAS IN WELLBORE LOCATED AT 8992'. LOADED WITH SEAWATER TO COMPLETE LOGGING. PRODUCTION DATA (05-JUL-94): GROSS FLUID = 1.51 MBPD NET OIL = 1.45 MBOPD NET WATER = 0.06 MBWPD FORM. GAS = 21.51 MMSCFD GOR = 14831 LIFT GAS = 0.00 CASING PRES.= 0.00 TGOR = 14831 TGLR = 14201 CHOKE = 21.7 MAN. PRES. = 1308 PSIG MAN. TEMP. = 129 DEGF WATER CUT = 4.2% NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTION = 10.625", CHISM FILTERING OFF, CASING CORRECTIONS OFF, SALINITY = 0 PPM. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS NEUTRON DEPTH MATCHED TO "SHIFTED" FIRST PASS G~ RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT NEUTRON PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS NEUTRON. / ? ?MATCH1A. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH NPHI 8416.0 8418.5 8445.5 8448.5 8461.0 8465.0 8467.0 8469.5 8471.5 8475.0 8474.5 8477.0 8481.5 8484.5 8484.0 8486.5 8496.0 8499.5 8501.0 8505.0 8508.0 8510.0 8510.0 8513.0 8516.5 8520.5 8541.0 8544.0 8560.5 8564.0 8572.0 8575.5 8587.5 8590.0 8617.0 8620.5 8624.5 8627.0 8663.0 8665.0 8696.0 8699.0 8701.0 8704.0 8862.5 8864.0 8866.5 8868.5 8901.0 8903.0 8923.5 8924.5 9005.5 9008.5 9011.5 9014.0 9014.5 9017.0 9020.5 9022.0 9030.0 9032.0 9038.5 9041.0 9045.0 9047.5 $ START DEPTH STOP DEPTH 8388.0 9056.0 8400.0 9064.0 REMARKS: (MEASURED DEPTH) PASS 1. FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. EQUIVALENT UNSHIFTED DEPTH CN WN FN COUN STAT / ? ?MATCH1B . OUT $ : BP EXPLORATION : J - 01 (09-11-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 4 2 NPHI 2418 68 1 PU-S 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 5 TENS 2418 68 1 LB 4 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 33 Tape File Start Depth = 9075.000000 Tape File End Depth = 8385.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 8287 datums Tape Subfile: 2 215 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8386.0 9056.0 8398.0 9064.0 BASELINE DEPTH GRCH 8389.5 8391.5 8409.0 8411.5 8409.5 8412.5 8421.5 8424.5 8427.5 8425.0 8428.5 8425.5 8429.0 8439.0 8443.5 8445.0 8450.0 8454.5 8451.0 8455.0 8460.0 8463.5 8461.5 8467.0 8469.5 8474.0 8479.0 8476.5 8480.5 8485.0 8492.5 8496.0 8508.0 8516.5 8521.0 8517.5 8521.5 8532.0 8536.0 8535.5 8539.0 8541.0 8545.5 8549.0 8555.0 8559.0 8560.0 8572.5 8587.0 8591.0 8587.5 8617.0 8620.0 8621.0 8624.5 8623.0 8626.5 8624.0 8657.0 8658.5 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH NPHI 8424.5 8448.5 8464.5 8480.0 8496.0 8500.5 8510.0 8520.5 8544.5 8564.0 8576.0 8590.5 8627.0 8658.5 8660.0 8663.0 8665.5 8690.5 8701.0 8701.5 8704.0 8705.0 8705.5 8712.5 8713.5 8715.5 8725.0 8725.5 8726.5 8735.0 8749.0 8753.5 8760.0 8763.5 8770.0 8771.0 8775.5 8787.5 8823.0 8824.5 8848.5 8852.5 8853.0 8854.0 8854.5 8855.0 8856.5 8862.5 8869.5 8871.0 8895.0 8897.5 8918.5 8920.0 8921.5 8924.0 8928.0 8955.5 8970.5 8974.0 8979.0 8982.0 8983.5 8984.5 8987.5 8990.5 9001.0 9006.0 9012.0 9018.5 9019.5 9020.5 9021.0 9024.0 9025.5 8667.5 8693.5 8704.5 8705.5 8708.0 8708.5 8859.5 8921.5 8924.0 8930.5 8985.0 8986.5 8987.0 9021.0 9021.5 9022.5 9023.5 8668.5 8708.0 8709.0 8716.0 8716.5 8718.5 8728.5 8729.0 8729.5 8738.0 8751.5 8756.0 8763.5 8767.0 8773.0 8773.5 8778.0 8790.5 8823.5 8825.0 8850.5 8854.5 8855.5 8856.5 8857.5 8858.0 8864.0 8871.5 8873.0 8898.0 8900.0 8921.0 8925.0 8957.0 8975.0 8979.0 8982.0 8986.0 8990.5 8993.0 9004.5 9010.5 9014.5 9023.5 9026.5 9027.0 9027.0 9033.0 9035.5 9036.0 9037.0 9044.5 9047.0 9049.0 $ REMARKS: 9029.5 9036.0 9036.5 9039.0 9039.5 9047.0 9049.5 9051.0 9051.0 PASS 2. FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. CN WN FN COUN STAT /??MATCH2A.OUT / ? ?MATCH2B. OUT $ : BP EXPLORATION : J - 01 (09-11-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 4 2 NPHI 2418 68 1 PU-S 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 5 TENS 2418 68 1 LB 4 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 33 Tape File Start Depth = 9075.000000 Tape File End Depth = 8385.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 8287 datums Tape Subfile: 3 Minimum record length: Maximum record length: 172 records... 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8386.0 9056.0 8398.0 9064.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 8389.5 8390.5 8399.0 8400.5 8407.5 8410.0 8416.5 8419.0 8417.0 8420.0 8419.0 8422.0 8420.0 8422.5 8420.5 8422.5 8424.0 8426.5 8439.0 8443.0 8440.5 8443.0 8449.0 8451.5 8449.5 8452.5 8450.0 8453.0 8451.5 8455.5 8459.5 8463.0 8462.5 8466.0 8467.0 8470.5 8473.0 8475.5 8475.5 8479.5 8476.5 8479.5 8490.5 8493.0 8491.0 8494.0 8491.5 8495.0 8504.0 8507.0 8508.5 8510.0 8512.5 8517.0 8516.5 8519.5 8520.0 8518.0 8522.0 8519.0 8522.5 8526.0 8529.5 8527.0 8530.0 8531.0 8534.5 8531.5 8535.5 8534.5 8532.0 8536.0 8534.0 8538.0 8534.5 8538.5 EQUIVALENT UNSHIFTED DEPTH NPHI 8535.5 8547.0 8553.5 8558.5 8566.5 8567.0 8569.5 8578.0 8579.0 8580.0 8585.5 8619.5 8627.0 8629.0 8648.5 8654.0 8656.0 8656.5 8667.0 8690.5 8694.0 8701.0 8703.0 8704.0 8705.0 8705.5 8706.5 8709.0 8712.0 8712.5 8716.5 8723.5 8763.0 8764.0 8774.0 8824.0 8824.5 8837.0 8840.5 8859.5 8863.5 8867.5 8885.5 8891.5 8895.0 8896.0 8904.0 8905.0 8921.5 8923.5 8959.5 8965.0 8970.5 8974.5 8977.5 8978.0 8979.0 8983.0 8990.0 9001.0 8538.5 8550.0 8558.0 8570.0 8589.0 8622.5 8630.0 8657.5 8659.5 8660.5 8671.0 8693.5 8697.0 8706.5 8709.0 8862.5 8898.0 8898.5 8539.0 8562.0 8569.5 8570.0 8573.0 8581.5 8582.0 8582.5 8631.5 8650.0 8657.5 8704.0 8707.0 8707.5 8709.0 8711.0 8714.0 8715.0 8719.0 8726.5 8766.0 8766.5 8776.5 8825.0 8825.5 8837.0 8840.5 8865.5 8869.5 8888.0 8894.0 8906.0 8907.0 8922.5 8924.5 8961.5 8967.0 8973.5 8977.5 8980.0 8980.5 8981.0 8985.0 8992.0 9005.0 9006 9011 9016 9017 9018 9019 9020 9021 9023 9024 9026 9026 9027 9033 9034 9039 9042 9044 9045 9046 9050 9057 $ REMARKS: .0 .5 .0 .0 .5 .5 .0 .5 .0 .0 .0 .5 .5 .5 .5 .5 .5 .5 .5 .0 .0 .5 PASS FUCT, 9010.0 9014.0 9018.5 9019.0 9020.5 9021.0 9022.0 9023.0 9024.5 9025.0 9028.0 9029.0 9028.5 9036.0 9035.0 9036.5 9041.5 9044.5 9046.0 9046.5 9048.0 9052.0 9059.0 e NUCT, & TENS WERE SHIFTED WITH NPHI. CN WN FN COUN STAT /??MATCH3A. OUT /??MATCH3B.OUT $ : BP EXPLORATION : J - 01 (09-11-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GRCH 2418 68 1 GAPI 2 NPHI 2418 68 1 PU-S 3 FUCT 2418 68 1 CPS 4 NUCT 2418 68 1 CPS 5 TENS 2418 68 1 LB Size API API API API Log Crv Crv Length Typ Typ Cls Mod 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 33 Tape File Start Depth = 9075.000000 Tape File End Depth = 8385.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 16574 datums Tape Subfile: 4 186 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: .5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS GRCH 2418 $ REMARKS: CN WN FN COUN STAT 1, 2, 3 1, 2, 3 AVERAGED PASS. GRCH, NPHI, FUCT, & NUCT WERE AVERAGED FOR ALL 3 PASSES. $ : BP EXPLORATION : J - 01 (09-11-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH CNAV 68 1 GAPI 4 2 NPHI CNAV 68 1 PU-S 4 3 FUCT CNAV 68 1 CPS 4 4 NUCT CNAV 68 1 CPS 4 4 35 725 65 1 4 35 725 65 1 4 35 725 65 1 4 35 725 65 1 16 * DATA RECORD (TYPE~ 0) 1006 BYTES * Total Data Records: 28 Tape File Start Depth = 9075.000000 Tape File End Depth = 8385.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 15193 datums Tape Subfile: 5 51 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8387.5 2418 8395.5 $ LOG HEADER DATA STOP DEPTH 9057.0 9065.5 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 PCM PULSE CODE MODULATOR GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S 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): 06-AUG-94 FSYS REV. J001 VER. 1.1 1819 06-AUG-94 9027.0 9067.0 8400.0 9066.0 1500.0 YES TOOL NUMBER 3507XA 1310XA 2418XA 2323XA .OO0 9304.0 .0 SEAWATER .00 .0 .0 0 .0 .000 .000 .000 .0 THERMAL SANDSTONE .00 10.625 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): .0 REMARKS: PASS 1. $ CN WN FN COUN STAT : BP EXPLORATION : J - 01 (09-11-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 4 2 CNC 2418 68 1 PU-S 4 3 CN 2418 68 1 PU-L 4 4 LSN 2418 68 1 CPS 4 5 SSN 2418 68 1 CPS 4 6 CCL 2418 68 1 4 7 SPD 2418 68 1 F/MN 4 8 TTEN 2418 68 1 LB 4 9 TEN 2418 68 1 LB 4 4 19 991 67 5 4 86 720 65 6 4 31 149 96 6 4 27 466 87 5 4 28 122 23 5 4 79 150 21 1 4 65 866 87 0 4 31 402 87 0 4 31 402 87 0 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 111 Tape File Start Depth = 9073.000000 Tape File End Depth = 8385.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 44105 datums Tape Subfile: 6 Minimum record length: Maximum record length: 186 records... 62 bytes 1006 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8386.0 2418 8394.0 $ 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): STOP DEPTH 9057.0 9065.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MODULATOR GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S 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): 06-AUG-94 FSYS REV. J001 VER. 1.1 1856 06-AUG-94 9027.0 9067.0 8400.0 9066.0 1500.0 YES TOOL NUMBER 3507XA 1310XA 2418XA 2323XA .O0O 9304.0 .0 SEAWATER .00 .0 .0 0 .0 .000 .000 .000 .0 THERMAL SANDSTONE .00 10.625 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN) : .0 REMARKS: PASS 2. $ CN WN FN COUN STAT : BP EXPLORATION : J - 01 (09-11-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TTEN 2418 68 1 LB 9 TEN 2418 68 1 LB 4 4 19 991 67 5 4 4 86 720 65 6 4 4 31 149 96 6 4 4 27 466 87 5 4 4 28 122 23 5 4 4 79 150 21 1 4 4 65 866 87 0 4 4 31 402 87 0 4 4 31 402 87 0 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 111 Tape File Start Depth = 9074.000000 Tape File End Depth = 8386.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 42724 datums Tape Subfile: 7 Minimum record length: Maximum record length: 186 records... 62 bytes 1006 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8385.5 2418 8394.0 $ 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): STOP DEPTH 9057.0 9065.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MODULATOR GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S 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): 06-AUG-94 FSYS REV. J001 VER. 1.1 1932 06-AUG-94 9027.0 9067.0 8400.0 9066.0 1500.0 YES TOOL NUMBER 3507XA 1310XA 2418XA 2323XA .O0O 9304.0 .0 SEAWATER .00 .0 .0 0 .0 .000 .000 .000 .0 THERMAL SANDSTONE .00 10.625 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): .0 REMARKS: PASS 3. $ CN WN FN COUN STAT : BP EXPLORATION : J - 01 (09-11-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 4 2 CNC 2418 68 1 PU-S 4 3 CN 2418 68 1 PU-L 4 4 LSN 2418 68 1 CPS 4 5 SSN 2418 68 1 CPS 4 6 CCL 2418 68 1 4 7 SPD 2418 68 1 F/MN 4 8 TTEN 2418 68 1 LB 4 9 TEN 2418 68 1 LB 4 4 19 991 67 5 4 86 720 65 6 4 31 149 96 6 4 27 466 87 5 4 28 122 23 5 4 79 150 21 1 4 65 866 87 0 4 31 402 87 0 4 31 402 87 0 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 111 Tape File Start Depth = 9074.000000 Tape File End Depth = 8386.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 71636 datums Tape Subfile: 8 Minimum record length: Maximum record length: 186 records... 62 bytes 1006 bytes Tape Subfile 9 is type: LIS 94/ 8/11 01 **** REEL TRAILER **** 94/ 8/15 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 15 AUG 94 9:10a Elapsed execution time = 7.64 seconds. SYSTEM RETURN CODE = 0 sUbfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 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: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING MWD RUN 2 6576.00 T. MCGUIRE D. HEIM REMARKS: OPEN HOLE J-01A 500292002001 BP EXPLORATION (ALASKA) INC. SPERRY-SUN16_FEB 96 LOGIING SERVICES MWD RUN 3 MWD RUN 4 T. MCGUIRE D. HEIM 9 liN 13E 750 1245 74.00 72.48 38.40 T. MCGUIRE D. HEIM MICROFILMED CAS ING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 8618.0 6.750 9900.0 MWD - GR/EWR4. ALL DEPTHS ARE MEASURED BIT DEPTHS. WINDOW MILLED IN 9 5/8" CASING FROM 8555' - 8618'. RUN 1 WAS DIRECTIONAL ONLY. RUNS 2 AND 3 WERE DIRECTIONAL WITH GAMMA. (NGP) SERVICE. RUN 4 WAS DIRECTIONAL GAMMA SERVICE WITH RECORDED SLIM PHASE 4 AND DUAL GAMMA RAY. GAMMA RAY FROM 8541' - 8751' WAS LOGGED AFTER DRILLING DURING RUN 2. GAMMA RAY FROM 9109' - 9316' WAS LOGGED AFTER DRILLING DURING RUN 4. THE MERGED GAMMA RAY CURVE IS MADE UP FROM THE FOLLOWING TOOLS: NGP-GR --> 8531.0 - 9032.5 DGR-GR --> 9033.0 - 9822.0 NGP-GR --> 9822.5 - 9849.5 NOTE: DGR-GR IS PREFERRED IF IT IS AVAILABLE. NO DEPTH SHIFTS WERE DONE AS THIS IS THE DEPTH REFERENCE FOR THIS WELL. FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 8531.0 9850.0 9039.0 9829.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 8541.0 9187.0 3 9187.0 9316.0 4 9316.0 9900.0 MERGED MWD PASS. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : J-01A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 89 Tape File Start Depth = 9900.000000 Tape File End Depth = 8530.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 21929 datums Tape Subfile: 2 187 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 R3IW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8531.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOW-NHOLE 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: MAXI~ ANGLE: STOP DEPTH 9135.0 24-SEP-94 MWD 2.19 1.09 MEMORY 9187.0 8541.0 9187.0 0 .0 .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.750 8618.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: - MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTR3kTE AT MT: MUD CAKE AT MT: BIOZAN 9.20 71.0 9.5 30500 5.4 .000 .000 .000 .000 .0 .0 .0 .0 NEUTRON TOOL NLATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 2. CN WN FN COLIN ST~T : BP EXPLORATION (ALASKA) : J-01A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 16 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 Tape File Start Depth = 9190.000000 Tape File End Depth = 8530.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 3964 datums Tape Subfile: 3 -- Minimum record length: Maximum record length: 79 records... 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9133.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE 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: MAXIMUM ANGLE: STOP DEPTH 9266.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: - MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: MWD RUN 3. 25-SEP-94 MWD 2.19 1.09 MEMORY 9316.0 9187.0 9316.0 0 .0 .0 TOOL NUMBER 6.750 8618.0 BIOZAN 9.15 73.0 8.5 28500 4.8 .000 .000 .000 .000 .0 .0 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : J-01A : PRIIDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 5 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 Tape File Start Depth = 9320.000000 Tape File End Depth = 9130.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 23073 datums Tape Subfile: 4 -- Minimum record length: Maximum record length: 68 records... 62 bytes 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE S%RViMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGR 9033.0 9822.0 EWR4 9039.0 9829.0 NGP 9262.0 9850.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE 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: MAXIMUM ANGLE: 27-SEP-94 MWD 2.19 1.09 MEMORY 9900.0 9316.0 9900.0 0 .0 .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 NGP NATURAL GAMMA PROBE $ TOOL NUMBER P001SP4 P001SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.750 8618.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL POLYMER 9.10 68.0 8.2 38500 4.8 .100 .040 .080 .200 76.0 .0 76.0 76.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 · 'OOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 4. THE CURVE "GRD" IS THE GAMMA RAY FROM THE NGP TOOL. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : J-01A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Tip Cls Mod 1 GR MWD 68 2 RPX MWD 68 3 RPS MWD 68 4 RPM MWD 68 5 RPD MWD 68 6 ROP MWD 68 7 FET MWD 68 8 GRD MWD 68 1 AAPI 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 FPHR 4 1 HR 4 1 AAPI 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 4 90 310 01 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 63 Tape File Start Depth = 9900.000000 Tape File-End Depth = 9030.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 19634 datums Tape Subfile: 5 131 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS 96/ 2/16 01 **** REEL TRAILER **** 96/ 2/16 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 16 FEB 96 3:20p Elapsed execution time = 1.32 seconds. SYSTEM RETURN CODE = 0