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Home My WebLink About194-106STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT J-08 JBR 01/26/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 2 7/8" and 4.5" test joints used for testing. Test #2 on a low was slowly bleeding off. Bled off and purged air out of the system. Started test again and cmv #10 was found to be leaking by. Started test again using cmv #7 in place of cmv#10 for a pass. CMV#10 was serviced and tested in test #3. CMV #11 failed. Service valve and retest for a pass on test #3. Test #10 a test fitting started leaking on the high. Tightened fitting and went back to the high for a pass. Test Results TEST DATA Rig Rep:C. Pace/J. WerlingerOperator:Hilcorp Alaska, LLC Operator Rep:S. Heim/R. Gallen Rig Owner/Rig No.:Hilcorp ASR 1 PTD#:1941060 DATE:12/14/2023 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopGDC231212225903 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6 MASP: 1037 Sundry No: 323-617 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 0 NA Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 11" 5000 P #1 Rams 1 2 7/8" x 5" V P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16" 5000 P HCR Valves 1 2 1/16" 5000 P Kill Line Valves 3 2 1/16" 5000 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3050 Pressure After Closure P1700 200 PSI Attained P15 Full Pressure Attained P62 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2312 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P13 #1 Rams P7 #2 Rams P7 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill NA0 9 9 9 9 9999 9 9 FP cmv #10 was found to be leaking CMV #11 failed. Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. Iqq - i0 File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy~incent Nathan Lowell Date: [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is/ ON OR BEFORE C:LOR,Ik.,N~ILM.DO C PLUGG .~_,~G & LOC_%TION CL E~_R~_~CE REPORT =.. T_Sfl 3, .~ev-lew ~he well fi!-~, an~-commen: c= plugging, well head s=anus, = !oca=i=n c!~~ce - p~~ loc. clear. ./ Code STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Plugged Backfor Sidetrack WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 194-106 399-200 3. Address 8. APl Number P.O. Box 196612, AnChorage, Alaska 99519-6612 50-029-22497-00 4. Location of well at surface _?T,,:;~'.¥'7,----~ 9. Unit or Lease Name ~ ......... ~: ~,t..,~ ~ ~ Milne Point Unit 2574' NSL, 3343' WEL, Sec. 28, T13N, R10E, UM At top of productive interval~~, 10. Well Number 4437' NSL, 4565' WEL, Sec. 28, T13N, R10E, UM MPJ-08 At total depth 11. Field and Pool 2654' NSL, 4655' WEL, Sec. 2~, T13N, R1 0E, UM ~"~5.' Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Milne Point Unit / Schrader Bluff KBE - 64'I ADL 315848 12. Date Spudded8/10/94 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if °fish°re 16' N°' °f C°mpleti°nsS/20/94 11/4/99 N/A MSL Zero 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)19. Directional Survey ~20. Depth where SSSV set121. Thickness of Permafrost 8593 4075 FT 8593 4075 FT [] Yes [] No! N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run LWD, GR, RES .2.3. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 54.5# K-55 32' 112' 24" 250 SX Arctic Set (Approx.) 9-5/8" 40# L-80 33' 2516' 12-1/4" 504 sx PF 'E', 250 sx Class 'G' 7" 26# L-80 29' 6131' 8-1/2" 220 sx Class'G' ~" L~) 4-3/4" 9.2# L-80 5896' 8593' 6" Uncemented Pre-Packed Gravel Pack Screen~ I \ J U I I ~ ~'~ L 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None None MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4890' Set Cement Retainer 4887' P&A with 23 Bbls of Class 'G', Sqzd to 1100 psi 4885' Set Whipstock '~7. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Not on Production I N/A Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATE OIL-DEL GAS-MCF WATER-BEE OIL GRAWTY-API (CORR) Press. D 24-HOUR 28. RATE CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, GOR, and time of each phase. Subsea Top of Zone A 5025' 3824' Top of Zone B 5080' 3837' Top of Zone C 5183' 3862' 31. List of Attachments Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terr,eUubb,e "'~,~~ ~0J~-/~--. Title TechnicalAssistantlll Date MPJ-08 194-106 399-200 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 RECEIVED Nlla Oil & Gas Cons. Commillion MILNE POINT, ALASKA TO: J. Bixby FROM: M. O'Malley WELL# IMPJ- 08 Main Category: ISLICKLINE Sub Category: I Ri~ Prep Operation Date: 110-08-99 AFE # 337167 HES = 274 X 5 = $1370 HB&R = 230 x 3 = $ 690 110/08/99 9335-07O-78O Drlg / Prep / W/L Add hr = $ 220 Diesel = 26 Bbls x 42 -- $1092 HB&R RU to tubing ,Held pre job safety meeting Start down tubing .7 bpm at 2600 psi. displaced 26 Bbls tbg. volume. RDHB&R Prep for slickline run. SLICKLINE Objective: Tag for perforation, Punch 2 holes in tbg., dummy glm, set bpv. Operation: MIRU.TGSM RIH w/2.3 gauge ring to 4400' wlm,pooh RIH w/2.25 A perforator to 4398' wlm, punch hole, pooh RIH w/same to 4397' wlm, punch hole, pooh RIH w/2.5 ok-1 kot w/1.25 jdc to 140' wlm, latch, pooh RIH w/same w/1" dummy glv to 140' wIm, Set valve, pooh, good set RD Set BPV RDMO Conclusion: Punch 2 holes in tbg. @ 4398' & 4397' wlm, Dummy off glm @ 140' wlm, set BPV, RDMO SIWHP= 380# IA= 380# Diesel Used I NONE OA= 90# Methanol Used [ NONE RECEIVED ,, .;3 '16 ~000 Na~ka 0ii & Gas C0~s. ~mi~!0n Facility Date/Time 02 Nov 99 03 Nov 99 04 Nov 99 i M Pt J Pad 12:00-16:30 12:00-16:30 16:30 16:30-22:00 16:30-18:00 Duration 4-1/2 hr 4-1/2 hr 5-1/2 hr 1-1/2 hr 18:00 18:00-22:00 4hr 22:00 22:00-23:30 22:00-23:30 23:30 23:30-02:00 23:30-02:00 02:00 02:00-05:00 02:00-05:00 1-1/2 hr 1-1/2 hr 2-1/2 hr 2-1/2 hr 3hr 3hr 05:00 05:00-06:00 05:00-06:00 06:00 06:00-08:30 06:00-08:30 08:30 08:30-03:00 08:30-03:00 lhr lhr 2-1/2 hr 2-1/2 hr 18-I/2 hr 18-1/2 hr 03:00 03:00-04:00 03:00-04:00 04:00 04:00-06:00 04:00-06:00 06:00 06:00-16:30 06:00-08:00 08:00 lhr lhr 2hr 2hr 10-1/2 hr 2hr Progress .Report Well MPJ-08 Rig Nabors 4ES Page Date 1 15 May 00 Activity Derrick management Rigged up High pressure lines Rig lines to tiger tank & tree & take on sea h20 Equipment work completed :. Well control Circulated closed in well at 4397.0 ft Test lines to tree to 2000 psi. & atiempt to circ. & kill well dn tbg. Unable to circ. iat a rate sufficient to remove influx from v~ell bore. (Problem not know as of now will investigate w~en pulling out tbg. Pressure changed from 0.0 psi to 2000.0 psi in 2.00 hr - String blocke .: Bullhead well ' bull head annulus with two volumes & bleed influx off until well killes & lubricate tb~ volume until well stable & monitor same. Hole displaced with Seawater - 200.0{~ % displaced Wellhead work , Removed Xmas tree Equipment work completed - Nipple up BOP stack Rigged up BOP stack I~A¥ ] 5 ~.00( Equipment work completed Test well control equipment Tested BOP stack ~iit~ktil 0ii Test BOP stack as per. program ( Test Waived by Chuck Shove with AOGC) Pressure test completed successfully -',:3500.000 psi Wellhead work Removed Hanger plug Rig lubricator & prep to remove twc. Stopped: To hold safety meeting Wellhead work (cont..) Removed Hanger plug remove hanger plug with small amount of difficulty, Equipment work completed Electric wireline work Conducted electric cable operations rig sws & run 6.01 gr/jb to 5000' (¢'lm) & run #2 baker 7" cement retainer & log int~ position & set @ 4890' (wlm) pooh & rig dn same. i Completed run with Cement retainer fr~.m 0.0 ft to 4890.0 ft Wellhead work Installed Bell nipple remove lubricator & install bell nil~ple Equipment work completed 2-7/8in. Cement stinger workstring run Pulled Tubing in stands to 1900.0 fl rih with baker stinger to set plug bdow retainer. ; Stopped' To hold safety meeting 2-7/8in. Cement stinger workstring run (cont,.i) Ran Tubing in stands to 4890.0 ft At Top of packer: 4890.0 fl D Facility Date/Time 05 Nov 99 M Pt J Pad 08:00-09:00 09:00 09:00-10:30 10:30 10:30-11:30 11:30 1I:30-14:00 14:00 14:00-15:00 15:00 I5:00-16:30 16:30 16:30-17:00 I6:30-17:00 17:00 17:00-23:00 17:00-23:00 23:00 23:00-00:00 23:00-00:00 00:00 00:00-01:00 00:00-01:00 01:00 01:00-02:00 01:00-02:00 02:00 02:00-06:00 02:00-03:00 03:00 Progress Report Well 1VIP J-08 Rig Nabors 4ES Duration lhr 1-1/2 hr 1 hr 2-1/2 hr 1 hr 1-1/2 hr 1/2 hr I/2 hr 6111' 6hr lhr lhr 1 hr lhr lhr lhr 4hr lhr Page Date 2 15 May 00 Activity Injectivity test - 30.000 bbl injected at 700.0 psi sting in to retainer & perform inj. itest. Completed injectivity test Batch mixed slurry - 23.000 bbl rig dowell & pump 5-h20 test lin~s & pump 15-bbl, h20 & 23 bbl. I5.8 ppg. cmt. & d~place with 28-bbl. h20 max sqz psi. =1100 p!i. @ 3.23 bpmjob complete. ( witness of plug waive~l by Chuck Sheve with aogc. ' Completed operations Reverse circulated at 4890.0 ft Unsfing from cmt. retainer & revbrse circ. & monitor for cmt. returns did not identify no returns. Obtained clean returns - 200,00 % hole volume Laid down 2890.0 ft of Tubing Stopped: To circulate Circulated at 2000.0 ft freeze protect well with 80-bbI, diesel, Hole displaced with Diesel - 100.00 % displaced Laid down 2000.0 ft of Tubing Completed operations Perform integrity test Tested Cement retainer - Via string Pressure test completed successfully -! 3500.000 psi Slick]ine wireline work Conducted slickline operations on Slicldi~te equipment - Tool run 6 0'" Rig SWS wireline & dh with , i GR/JB to 4042' tool stopped. Run #2 with 3.625" ~wedge & bailer to 4500' stopped (No Recovery) Rrna,' #3 2,72" roller assy to 4795' & stopped & seen nd debri or signs of cmt. to stop tool, pooh & rig dn. Completed run with Cleaning / Investigation tools from 0.0 ft to 4795 Wellhead work Installed Tubing hanger Equipment work completed Nipple down BOP stack Removed BOP stack Equipment work completed RECE'! VE Wellhead work Installed Xmas tree Equipment work completed Mf~¥ '] ~ 200 Wellhead work Installed Hanger plug Equipment work completed Oft Facility M Pt J Pad Progress Report Well MPJ-08A Page 1 Rig Nordic3 Date 06 January 00 Date/Time 16 Dec 99 17 Dec 99 12:01-15:30 12:01-14:00 14:00 14:00-15:30 15:30 15:30-17:00 15:30-16:00 16:00 16:00-16:30 16:30 16:30-17:00 17:00 17:00-18:30 17:00-18:30 18:30 18:30-20:30 18:30-20:00 20:00 20:00-20:30 20:30 20:30-23:00 20:30-23:00 23:00 23:00-00:00 23:00-00:00 00:00 00:00-06:00 00:00-01:00 01:00 01:00-03:30 03:30 03:30-04:00 04:00 04:00-05:00 05:00 05:00-06:00 06:00-13:00 Duration 3-1/4 hr 1-3/4 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 2 hr 1-1/2 hr 1/2 hr 2-1/2 hr 2-1/2 hr lhr 1 hr 6hr 1 hr 2-1/2 hr 1/2 hr 1 hr 1 hr 7 hr Activity Move rig Rig moved 100.00 % Move onto MP J-08A. Rig accepted @ 1400 hrs on 12/16/99. At well location - Cellar Installed Drillfloor / Derrick Berm up pit liner. Set tanks & buildings. Thaw cellar ro access annulus valves. Equipment work completed Wellhead work Removed Hanger plug Pull BPV. Equipment work completed Installed Hanger plug Set TWC. Eqpt. work completed, running tool retrieved Removed Xmas tree ND tree & adapter. Equipment work completed Nipple up BOP stack Rigged up BOP stack NU & function test rams. Work completed - BOP stack in position Wellhead work Removed Tubing hanger PU landing jt. Screw into hanger. Check for pressure. BOLDS. Pull hanger & LD. Equipment work completed Installed BOP test plug assembly Set test plug. Prep to test stack. Eqpt. work completed, running tool retrieved Test well control equipment Tested BOP stack Test BOPE to 250 / 2000 psi-OK. Witnessing waived by John Crisp-AOGCC Field Inspector. Pressure test completed successfully - 2000.000 psi Wellhead work Installed Wear bushing Pull test plug. Set wear ring. Eqpt. work completed, running tool retrieved BHA run no. 1 Rigged up Drillstring handling equipment Work completed - Drillstring handling equipment in position Made up BHA no. 1 MU mill assembly f/dummy run. PU 12-4.75" DC & 36-3.5" HWDP. BHA no. 1 made up R.I.H. to 2200.0 ft Stopped: To circulate Circulated at 2200.0 ft Circ out freeze protect diesel w/120 deg seawater. Hole displaced with Seawater - 150.00 % displaced R.I.H. to 3900.0 ft BHA run no. 1 (cont...) RECEIVED ,amkaOa&OasOons. Oomm Facility M Pt J Pad Progress Report Well MPJ-08A Page 2 Rig Nordic3 Date 06 January 00 Date/Time 06:00-06:30 06:30 06:30-07:00 07:00 07:00-07:15 07:15 07:15-08:15 08:15 08:15-08:30 08:30 08:30-08:45 08:45 08:45-09:30 09:30 09:30-11:00 11:00 11:00-13:00 13:00 13:00-06:00 13:00-14:00 14:00 14:00-14:30 14:30 14:30-18:00 18:00 18:00-18:30 18:30 18:30-19:00 19:00 19:00-20:30 20:30 20:30-23:30 23:30 23:30-00:00 Duration 1/2 hr 1/2 hr 1/4 hr lhr 1/4 hr 1/4 hr 3/4 hr 1-1/2 hr 2hr 17hr 1 hr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 3 hr 1/2 hr Activity Serviced Top drive Service rig & top drive. Equipment work completed R.I.H. to 4783.0 ft Observed loss of 4000.00 klb string weight Circulated at 4783.0 ft Start circ to wash through tight spot. Had seawater spill outside. Stop circ & all personnel respond outside. Stopped ' Flowline plugged Held safety meeting Respond to spill. Thaw cuttings chute. Attempt to clean-uo spill. Everything frozen. Held safety meeting to discuss incident. LCIR #10587. Completed operations Reamed to 4785.0 ft Wash & ream past tight spot several times-OK. No further resistance R.I.H. to 4887.0 ft Washed 2' to top of retainer. On bottom Circulated at 4887.0 ft Circ sweep. Pump dry job. Blow down. Hole swept with slug - 120.00 % hole volume Pulled out of hole to 1520.0 ft At BHA Pulled BHA LD bumper sub & jars. BHA Stood back BHA run no. 2 Made up BHA no. 2 MU BHA. Orient. Stopped ' To hold safety meeting Held safety meeting Held pre-spud meeting with all personnel. Completed operations Made up BHA no. 2 MU whipstock. Run DC's. Test MWD. Blow down. BHA no. 2 made up Serviced Top drive pipe handler Serv pipe handler. Change elevators. Equipment work completed Held safety meeting PJSM on RIH w/whipstock. Completed operations R.I.H. to 4885.0 ft On bottom Functioned downhole tools at 4885.0 ft Break circ. Orient whipstock. Set anchor-OK. Attempt to shear off several times. Did not see bolt shear. Question as to whether whipstock is oriented. Consult with service personnel & w/Anch drilling. Equipment work completed Circulated at 4867.0 ft RECEIVED Al aC &GasCo s. i Facility M Pt J Pad Progress Report Well MPJ-08A Page 3 Rig Nordic3 Date 06 January 00 Date/Time 18 Dec 99 00:00 00:00-04:30 04:30 04:30-06:00 06:00 06:00-10:00 06:00-06:30 06:30 06:30-08:30 08:30 08:30-10:00 10:00 10:00-06:00 10:00-13:00 13:00 13:00-16:00 16:00 16:00-17:00 17:00 17:00-17:30 17:30 17:30-06:00 19 Dec 99 06:00-06:00 06:00-07:30 07:30 07:30-11:00 11:00 11:00-12:00 12:00 12:00-12:30 12:30 12:30-14:00 14:00 14:00-19:30 Duration 4-1/2 hr 1-1/2 hr 4hr 1/2 hr 2hr 1-1/2 hr 20 hr 3 hr 3hr 1 hr 1/2 hr 12-1/2 hr 24 hr 1-1/2 hr 3-1/2 hr 1 hr 1/2 hr 1-1/2 hr 5-1/2 hr Activity Hole displaced with Water based mud - 100.00 % displaced Milled Casing at 4892.0 ft Milled window f/4866'-80', as per procedure. Completed operations Circulated at 4892.0 ft Circ sweeps while working mills through window. Cleaned up good. Window appears smooth. Obtained clean returns - 200.00 % hole volume BHA run no. 2 (cont...) Circulated at 4892.0 ft Pump dry job. Blow down. Heavy slug spotted downhole Pulled out of hole to 1548.0 ft At BHA Pulled BHA LD milling assembly. All mills in guage. BHA Laid out BHA run no. 3 Made up BHA no. 3 MU drlg BHA. Orient. Load MWD. PU NMDC's. Test motor & MWD. BHA no. 3 made up R.I.H. to 4850.0 ft Stopped: To service drilling equipment Serviced Top drive Change out saver sub. Service top drive, swivel & blocks. Equipment work completed Circulated at 4892.0 ft Break circ. Orient 10-L. Slide through window. Tag bottom. Broke circulation Drilled to 5415.0 ft Extrapolating surveys back, it appears that the whipstock was most likely set at the correct orientation ( 30L of Hi ). BHA run no. 3 (cont...) Circulated at 5415.0 ft Circ sweeps. Rotate & reciprocate 30'off bottom. Abandon rig drill; OS-l: 15 min. Hole swept with slug - 150.00 % hole volume Drilled to 5609.0 ft Stopped: To take survey Took MWD survey at 5609.0 ft Do IFR calculations. Acceptable survey obtained at 5545.0 ft Drilled to 5675.0 ft Began precautionary measures Circulated at 5675.0 ft Circ HiVis / HiFiber weighted sweeps. Rotate & reciprocate 20' off bottom. Hole swept with slug - 150.00 % hole volume Drilled to 5996.0 ft RECEIVI D STATE OF ALASKA ALASK~ ,.)IL AND GAS CONSERVATION CO~MISSION APPLICATION FOR SUNDRY APPROVAL 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 2574' NSL, 3343' WEL, Sec. 28, T13N, R10E, UM At top of productive interval 4437' NSL, 4565' WEL, Sec. 28, T13N, R10E, UM At effective depth 2654' NSL, 4655' WEL, Sec. 28, T13N, R10E, UM At total depth 2654' NSL, 4655' WEL, Sec. 28, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KB) KBE: 64' 7. Unit or Property Name Milne Point Unit Well Number MPJ-08 Permit Number 94-106 APl Number 50-029-22497 Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 8593 feet true vertical 4075 feet Effective depth: measured 8593 feet true vertical 4075 feet Plugs (measured) Junk (measured) , 9. 10. 1. .,. ;-~ . ~-~ ~'.: !.J"-'} Casing Length Size Cemer~-t~'8"' ~f~6~0¥897:' MD TVD Structural Conductor 80' 13-3/8" 250 sx Arctic Set I (approx) 112' 112' Surface 2483' 9-5/8" 504 sx PF 'E', 250 sx Class 'G' 2516' 2446' Intermediate Production 6102' 7" 220 sx Class 'G' 6131' 4054' Liner Gravel Pack Screen 4-3/4" Uncemented (Pre-packed) Liner 5896' - 8593' 4029' - 4075' Perforation depth: measured true vertical 5076'-5136', 5174'-5216', 5806'-5871' 3901'-3916', 3925'-3934', 4018'-4026' ORI IN^L Tubing (size, grade, and measured depth) 2 7/8", 6.5#, L-80 to 4450'; 4" Baker Slim-Pack Screen Assembly from 5007' to 5909' Packers and SSSV (type and measured depth) HES 7" VTL packer at 5007'; HES 7" BWD packer at 5230'; HES 7" PGP packer at 5749'; Baker 7" F-2 packer at 5909' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation October 8, 1999 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Robert Laule, 564-5195 15. Status of well classifications as: [~ Oil I--I Gas [~] Suspended Service Date approved Michael Triolo, 564-5774 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Robert Laule Title Operations Drilling Engineer Commission Use Only ri~K~',Approval: Notify Commissio, o,o,o~ so representative witness Plug integrity "~ BOP Test ~V Location clearance__ .__ Mechanical Integrity Test __ Date I Approval No..~¢¢.. ~¢)~ Subsequent form required 10- ~.I~ ~1~ order of the Commission Form 10-403 Rev. 06/15/88 ORIGINAL SIGNED. BY Robert N. ChC, stenson Commissioner Date / 0 '-/o'~ ~ Submit In Triplicate , eared rvices rilling To: Blair Wondzell - AOGCC From: Michael Triolo Subject: MPJ-08 Application for sundry permit - P&A for Sidetrack Operations Date: 4 October 1999 Reference: API #50-029-20497 J-08 was drilled as a horizontal well in the OA Sand. 7" casing was set at top of the OA Sand. The 2,460 ft of OA Sand that was drilled was left open and a prepacked liner was run across the OA. Production started in May '94. A RWO for the ESP pump failure was done in Nov '95. The N sands were frac packed with screens and tied into the top of the prepacked liner. There is a check valve on top of the liner w~hich prevents pumping into the OA. The well is currently producing 100 bopd. The MPJ-08 plug and abandonment is currently scheduled for Nabors 4ES in mid October pending Sundry approval. The plug and abandonment work for MPJ-08 will precede the actual sidetracking of the well by Nordic 3. Pre-Rig work: 1) Amarada Survey 2) Injectivity test 3) Punch tubing and set BPV RWO Scope of work: 1) Pull BPV with lubricator, take on fluids. 2) Circulate and kill well 3) Set TWC 4) ND tree, NU BOP test to 3,500 psi 5) Pull TWC with lubricator 6) Pull and LD tubing hanger on Rig floor 7) Pull tubing and stand back in the derrick. 8) RIH with retainer on wireline with CCL. Set retainer @+4,921' depending on collar location. 9) RIH with tubing sting into retainer and establish inj rate and press, depending on inj. rates, remain stung in or sting out. 10) Batch mix cement, pump cement down tubing to top of retainer, sting in (if low inj rate) and squeeze to perf's. 11) Sting out reverse circulate right on top of retainer to clean out tubing and top of retainer. 12) POH to 2,000', freeze preotect, continue POH. 13) ND BOP, NU tree and test to 5,000 psi. 14) Pull TWC and set BPV 15) Release Rig Wellhead: WKM 11" 5M w/11' MPU J-08 (Current) x 2 7/8" 8rd EUE tbg. hng., KB = 65.20' (Nabors 22E) 2.5 .... H" BPV profile GL -- 35.7' Tree: Cameron 2-9/16" - 5M Actuator: Baker CAC · ~,ODF to T/7" hng. = 28.65' (N22E) 13 3/8" L-80, 64 ppf csg. Ilo3' I Camco2 7/8"x 1" 137' md I pocket KBMM GLM KOP = 1550' Max hole angle = 94 deg. from 8400' to TD. Raychem Heat Trace w/cable gaurd ;Horizontal section: 6400' - TD to a depth of approx. 2330' md. BLS of 4 to 7 deg./100' from 5090' to 5500' i Centrilift No. 2 ESP Power Cable ! ii 9 5/8" 40 ppi, L-80, Btrc. 12516'md I~ i!~ii 7", 26 ppf, L-80 Btrc. production csg !i, Centrilift GC -1200 ESP Minimum tbg. ID is 2.37" in GLM at 137'L~; '';~] GPMARC 146 Stg. Minimum gravel pack ID is 3.0" in seal bore ~-~ Seal Section GSTGDBHL I 4424' md I below screens (5749' and 5230' md) ~"~ B Centrilift Motor, 115 hp, 2030 I 4437' md Stimulation Summary: Volt, 33 Amps, KME 1 NB/NC Sands - 12/06/95, 14,200 lbs. Centrilift PHD I 4450' md 16 - 20 Carboite frac pack to screenout NF Sands - 12/04/95, 5100 lbs. HES 7" 'VTL' pkr. 16-20 Carbolite frac pack to screenout ~ ~ HES closing sleeve 5007' md Perforation Summarv:.i ~?:i!!!i~i??:ii?~:'~?'i~:i:~:;:i;;;~::';i:'~:'""~::~i:i~!iiiil ]i~?::'?: :::'~ - 4", 9.5 ppf blank pipe 5016' md -Ref. Loq: A~¥S GR/CCL - 11/29/95 ~!?!::!~:;!!??:.~i~i~i I I ':i~::i~:::..ii~i:i- ! Baker 4" Slimpack pre- 5037' md Size ;PF Interval (TVD) ' ~ ~ packed screen (0.012" ga.) 5069' md HES 7" 'BWD' Pkr. 5230' md 4.5" 12 ,'.076'-5136' (,1 901'-3916') 1 4", 9.5 ppf tbg. space out 4.5" 12 ,' 174'-5216' (,'. 925'-3934') 4.5" 12 ,' 806'-5871' (, 018' -4026') ~ ~ HES 7" 'PGP' pkr. 5749' md Baker Inteq PerfForm 22.7 gr. charges, -4", 9.5 ppf blank pipe 5772' md , 1~5 / 45 de~ phasing, El-ID = 0.50", 'Baker 4" Slimpack pre- 5803' md 'FI'P = 5.@~" packed screen (0.012" ~a.) 5~0~' wire Open Holo Summary: I~ Baker 7" F-2 Sz 85-40 ~kr. 5~11' md HES 3.5" 'XN' Npl. (2.63" ng) Open hole from 7" csg. shoe at 6131' 41 -- ~ ~/HES standing valve ~ L6131, md to TD (8593'). 3.5" x 4.75" prepacked~ 7" Csg. Shoe (16-30 Baker Bond) screen (0.20 gage) i 4.75" x 3.5" prepacked liner I ' from 6091'to 8573' i~i.~ 6091 md -- ~.._~-- Two flapper valve assys. 8585' md. TD of 6" open hole = 8593' md ,- "V" Set Shoe 8593' md DATE REV. BY COMMENTS MILNE POINT UNIT 08/94 ML Initial ESP Completion Well MP J-08 12/08/95 JBF £ omplete N B/C/F Sands and RunESP APl NO: 50-029-20497 BP EXPLORATION (AK) Wellhead: WKM 11" 5M w/11' x 2 7/8" 8rd EUE tbg. hng., 2.5 .... H" BPV profile Tree: Cameron 2-9/16"- 5M Actuator: Baker CAC 13 3/8" L-80, 64 ppf csg. 9 5/8" 40 ppf, L-80, Btrc. 103' M P U J-08 (Proposed) , ! KB = 65.20' (Nabors 22E) [GL = 35.7' I~ODF to ¥/7" hng. = 28.65' (N22E) KOP = 1550' Max hole angle = 94 deg. from 8400' to TD. Horizontal section: 6400' - TD DLS of 4 to 7 deg./100' from 5090' to 5500' ~516' md IJ 7", 26 ppf, L-80 Btrc. production csg Minimum gravel pack ID is 3.0" in seal bore below screens (5749' and 5230' md) Stimulation Summary: NB/NC Sands - 12/06 / 95, 14,200 lbs. 16 - 20 Carboite frac pack to screenout NF Sands - 12 / 04/95, 5100 lbs. 16-20 Carbolite frac pack to screenout Perforation Summary: Ref. Loc AWS GR/CCL - 11/29/95 ,, Size SPF Interval (TVD) 4.5" 12 5076'-5136' (3901'-3916') 4.5" 12 5174'-5216' (3925'-3934') 4.5" 12 5806'-5871' (4018'-4026') Baker Inteq PerfForm 22.7 gr. charges, 135 / 45 deg phasing, EHD = 0.59", TTP = 5.96" Open Hole Summary: Open hole from 7" csg. shoe at 6131' to TD (8593'). 3.5" x 4.75" prepacked (16-30 Baker Bond) screen (0.20 gage) from 6091' to 8573' Cement Cement Retainer :¢~¢!~'~"' ........ .'.::~;~ii "'VTL' pkr. HES closing sleeve 4", 9.5 ppf blank pipe Baker 4" Slimpack pre- packed screen (0.012" ga.) HES 7" 'BWD' Pkr. 4", 9.5 ppf tbg. space out HES 7" 'PGP' pkr. 'HES flow sub (sliding slv.) 9.5 ppf blank pipe 4" Slimpack pre- packed screen (0.012" ga.) Baker 7" F-2 Sz 85-40 Pkr. HES 3.5" 'XN' Npl. (2.63" rig) HES standing valve~ 7" Csg. Shoe ~ 4.75" x 3.5" prepacked liner ~4,921' 5007' md 5016' md 5037' md 5069' md 5230' md 5749' md 5756' md 5772' md 5803' md 5906' wlm 5911' md 6131' md I 6091' md TD of 6" open hole = 8593' md Two flapper valve assys. "V" Set Shoe 8585' md. 8593' md DATE O8/94 12/O8/95 9/27/99 REV. BY ML COMMENTS Initial ESP Completion JBF Complete N B/C/F Sands and RunESP MTT Proposed decompletion 4ES MILNE POINT UNIT Well MP J-08 APl NO: 50-029-20497 BP EXPLORATION (AK) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [~PuII Tubing I-~Alter Casing [~ Repair Well []Other ESP Changeout 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2574' NSL, 3343' WEL, Sec. 28, T13N, R10E, UM At top of productive interval 4437' NSL, 4565' WEL, Sec. 28, T13N, R10E, UM At effective depth 2654' NSL, 4655' WEL, Sec. 28, T13N, R10E, UM At total depth 2654' NSL, 4655' WEL, Sec. 28, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KBE) KBE: 64' 7. Unit or Property Name Milne Point Unit 8. Well Number MPJ-08 9. Permit Number / Approval No. 94-106 10. APl Number 50- 029-22497 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 8593' feet true vertical 4075' feet Effective depth: measured 8593' feet true vertical 4075' feet Casing Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) Length Size Cemented 80' 13 3/8" 250 sx Arctic Set I (approx) 2483' 9 5/8" 504 sx PF 'E' 250 sx 'G' 6102' 7" 220 sx Class 'G' MD TVD 112' 112' 2516' 2446' 6131' 4054' Perforation depth: measured 5076'-5136', 5174'-5216', 5806'-5871' true vertical 3901'-3916',3925'-3934',4018'-4026' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 5909' Packers and SSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure APR "1,5 1998 Gas Oo~s. Comm~m 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipAIvord ~~ ~ Title Form 10-404 Rev. 06/15/88 Engineering Supervisor Date ~/2--~i.9~ Prepared By Name/Number: Mary Youngers 564-5242 SubmitlnDup~ ~ SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING- BPX/ARCO Well Name: MPJ-08 Rig Name: N-4ES AFE# 330061 Accept Date: 11/25/95 Spud Date: . Release Date: 12/09/95 NOVEMBER 25, 1995 ACCEPTED RIG @0100 HRS. SCOPE DOWN, BRIDAL UP & LOWER DERRIK, PREPARE SUBSTRUCTURE TO MOVE. PU LOCATION. MOVE RIG FROM L161 TO J PAD, SET HERCULITE SPOT SUB ON J-08, SET PIPE SHED PITS & CAMP. RAISE DERRICK, DRIDAL DOWN, SCOPE UP. TAKE ON 8.4 PPG SOURCE WATER, HEAT IN PITS, SET TIGER TANKS & RU HARD LINES TO WELL, TEST HARD LINES TO 2000 PSI. NOVEMBER 26, 1995 PULL BPV, TBG 1040 PSI, ANN 1040 PSI, BLEED TBG THRU CHOCKE TO TIGER TANK, CONT. KILLING WELL @ 5.5 BPM & VENTING TO TIGER TANK. WHILE VENTING GAS, FLOWING GAS CREATED A STATIC CHARGE CLOSE TO THE HATCH, THIS RESULTED IN AN IGINITION OF FLAMMABLE VAPORS WITHIN THE EXPLOSIVE RANGE CAUSING A BRIEF FIRE. NO DAMAGE OR INJURIES - SWI. NOTIFIED MPU PE'S, PROD DEPT & SAFETY DEPT. MEET W/PROD & SAFETY DEPT. AND A NEW PROCEDURE FOR VENTING THE REMAINING GAS THRU THE FLOW LINE WAS DISCUSSED. RU HARD LINES TO FLOW LINE & TEST TO 750 PSI INITIAL FLOW LINE PRESS = 250 PSI. TBG PRESS = 0 PSI. 7" ANN. 750 PSI. BLEED GAS TO PRODUCTION FLOW LINE. KEEP TBG FULL W/CHARGE PUMP. PRESS DN TO 250 PSI CONT. BLEED GAS TO TT TO 0 PSI. CIRC W/ HEATED FILITERED SOURCE WATER THRU CHOKE, GAS RETURNS W/FLUID LOSS OF 60 BPH. SWI & MONITOR FOR ½ HOUR. 0 PRESS ON TBG & ANN. MIX & PUMP 40 BBLS XANVIS + LITHIUM HYP. SPOT PILL & MONITOR WELL. SET TWC. NS XMAS TREE & NU BOP. NOVEMBER 27, 1995 SERVICE RIG, NU BOPE, INSTALL 2 7/8" RAMS. TEST BOPE, PULL TWC & INSTALL LJ WITNESSING WAIVED BY MR. D. AMOS AOGCC. MIX & SPOT 40 BBLS XANVIS PILL W/LITHIUM H. BREAKER. BOLDS, PULL & LD HANGER, TEST HEAT TRACE & ESP LINE. POH W/2 7/8 TUBING & ESP COMPLETE. ASSEMBLY., DRIFTING & REPLACING SEAL RINGS. SLM. INSTALL TEST PLUG, CHANGE RAMS & TEST TO 5000 PSI. MU BHA #1. NOVEMBER 28, 1995 SERVICE RIG. STRAP & MU BHA. PU & PIH W/BHA #1 & 3.5" L-80 NSCT. TBG. SLIP DRILLING LINE. CONTINUE RIH W/3.5" TBG TO 5799. BRK CIRC., DROP 7/8 BALL TO BASKET, CIRC THRU BASKET F/5799 TO LINER TOP @ 5902'. MIX & SPOT XANVIS PILL W/BREAKER MONITOR WELL. POH W/3.5" TBG (CLEAN OUT J. BASKET- RECOVER 4 METAL BANDS & 1 6' FLAT GUARD). MU J. BASKET & RIH TO 5800'. BRK CIRC. DROP 7/8" BALL, CIRC. THRU REV CIRC. J BASKET TO Page 1 of 4 SUMMARY OF DALLY OPERATIONS LINER TOP @ 5902'. POH W/3.5 TBG. CLEAN OUT J BASKET (RECOVER 4 METAL BANDS). MU J. BASKET & RIH. NOVEMBER 29, 1995 SERVICE RIG. CON'T RIH REC. CIRC. BASKET TO 5890'. DROP 7/8 BALL & WORK BASKET F/5890 TOP 5902' (LINER TOP). POH W/3.5 TBG. LD REV. CIRC. BASKET & JARS. MU "G" PLUG. DID NOT RECOVER ANY BANDS OR JUNK. RIH W/BHA TO 310'. CUT & SLIP DRILLING LINE. CON'T RIH W/"G" PLUG & EQUALIZER TO LINER TOP @ 5902'. SET "G" PLUG ON PACKER & UN "J" "G" PLUG. POH. MU (2) & SCRAPERS & RIH. NOVEMBER 30, 1995 PICKLE WORK STRING W/RECOMMENDED SOLUTION & RATE, REV OUT SAME. REV CIRC CSG WASH AT A MAXIMUM RATE. REV CIRC/FILTER SOURCE WATER W/RIG. TEST CSG. 800 PSI/15 MIN BLEED, CHECK SURFACE EQUIPMENT RETEST SAME LOSS RATE. PULL PLUG, BREAK CIRC, RESET SAME LOSS RATE. PULL PLUG, MONITOR FLUID LOSS @ 25 BPH. SPOT XANVIS PILL W/BREAKER. POOH W/PLUG. NIPPLE UP SHOOTING FLANGE ON BOP'S. R/U ATLAS. TEST LUBRICATOR T/500 PSI. PUMP DOWN CASED HOLE GR/CCL TO PACKER @ 5906' ELM, LOG UP TO 4000' ELM. R/D ATLAS. ND SHOOTING FLANGE, NU FLOWLINE. DECEMBER 01, 1995 LUB RIG. M/U BAKER SEAL ASSY & RTTS & TIH. ENGAGE PKR @ 5903' (4ES KB) TEST 7" CASING TO 3400 PSI LOOSING 100 PSI PER MINUTE F/10 MIN. 9 5/8" X 7" PSI UP TO 350 PSI (DID SEVERAL CK W/NO TEST GOOD (DISCOVER THAT VARIABLE PIPE RAMS LEAKING. CHANGE PIPE RAMS, TEST PIPE RAMS TO 3400 PSI. TEST 7" CASING TO 3400 PSI LOOSING 500 PSI PER MINUTE 9 5/8" X 7" UP TO 150 TEST PACK OFF W/WKM REP (NO TEST). POOH. CHG. 7" PACK OFF TEST TO 5000 PSI (PACK OFF WAS DAMAGED FROM USE. P/U 84BJTS. OF 2 1/16" CS & BAKER SNAPLATCH & RIH TO 8556' & ENGAGE P/U CIRC. & CK. TEMPERATURE ON FLUID. PUMPING LINER TREATMENT. DECEMBER 02, 1995 CONT. LINER TREATMENT, NO PRESSURE LOSS WHILE BULL HEADING MONITOR WELL. TOH W/3 ~" TBG, LD BAKER SNAP LATCH ASSY. P/U QUADCO STANDING VALVE & RIH TO XN NIPPLE @ 5925' (4ES KB). TEST STANDING VALVE TO 4000 PSI. F/10 MIN (LOST 400 PSI) RE-REST LOST 400 PSI IN 10 F MIN OK. POOH W/3 Y:~" TBG. (WET DUE TO STANDING VALVE SETTING TOOL NOT ALLOWING GOOD TRANSFER OF FLUID. RIH W/3 Y:~" TBG. RIG UP & DISPLACE 8.4 PPG. W/8.7 PPG. DECEMBER 03, 1995 DISP. WELL W/8.7 PG FLUID. TOH, MU BAKER TCP ASSY & RIH TO PKR TOP @ 5906'. SPACE OUT SET PKR FIRE GUNS PERF 12 SPF, 5806'-5871' REVERSE Page 2 of 4 SUMMARY OF DALLY OPERATIONS CIRC. INFLUX LOSSES UP TO 60 BBLS PER HR. CIRC. & CUT WT. TO 8.4 PPG. SLOW LOSSES TO 11-12 BPH WHILE STATIC POH & LD PERF GUNS. MU HOWCO FRAC-PAC TOOLS & RIH W/SAME. DECEMBER 04, 1995 CUT DRILLING LINE, CONT TIH W/FRAC PAC ASSY, TAG PKR 5902'. SPACE OUT & DROP BALL & SET PKR TEST SAME. REV OUT BALL RIG BJ TEST LINES TO 5500 PSI. HOLE SAFETY & OPERATIONAL MEETING PERFORM FRAC PAC AS PROGRAM SCREENED OUT W/AN ESTIMATED 1600 LBS BEHIND PIPE BEFORE IT SCREENED OUT TO SURFACE PRESSURED UP TO 4500 PSI ATTEMPTED TO REDO FRAC BY REPRESSURING TO 4500 PSI REV CIRC OUT SAND TO PITS & REPAIR BJ BLENDER. RE PACK SCREEN IN THREE STAGES & ESTIMATED SAND BEHIND PIPE AFTER 3 STAGES IS 3500 + 1600= 5100 LBS. REV CIRC & COND HOLE W/25 BBL XANVIS SWEEP. DECEMBER 05, 1995 SERVICE RIG, TOH & LD FRAC PAC TOOL. M/U HOWCO "BWD" ISOLATION PKR & RIH W/SAME. TAG PKR @ 5749' & SPACE OUT & DROP BALL & SET ISOLATION PKR @ 5230' BALL SHEARED @ 2000 PSI SET TO SHEAR @ 3500 PSI UNABLE TO TEST PKR SHEAR OUT 55K OVER. POH & LAY DOWN SETTING TOOL. M/U HOWCO SEAL ASSY & RIH W/SAME SET SEALS IN PKR @ 5230' TEST PKR TO 3000' PSI OK. TOH W/SEAL ASSY. M/U BAKER TCP GUNS & RIH W/SAME. DECEMBER 06, 1995 CONTINUE TIH W/BAKER TCP GUNS. SET & TEST PLUG IN ISOLATION PKR SET TCP PACKER ATTEMPT TO FIRE GUN W/PRIMARY SOURCE UNABLE W/3200 PSI WENT TO SECONDARY FIRING SYSTEM AND FIRED GUNS W/3500 PSI & BLEED PSI AND WAIT 8 MINS GUN FIRED. 12 SPC 5076-5136-5174-5216'. REV CIRC @ 3 BPM 300 PSI MON WELL UNSEAT PKR & CIRC BOTTOMS UP NO FLUID LOSS. TOG & LD GUNS ALL SHOTS FIRED. TIH W/HOWCO PLUG RETRIEVING TOOL REV CIRC OVER PLUG & PULL SAME CIRC BOTTOMS UP MONITOR WELL TOH W/PLUG & LD SAME & DC. RIG UP FLOOR & MAKE UP FRAC PAC ASSY. TIH W/FRAC PAC ASSY. ENGAGE PKR @ 5230" ANP OUT TO VERIFY & SPACE PUPS BELOW 1-JT TBG DROP BALL & RIG BJ EQUIPMENT. DECEMBER 07, 1995 SET & TEST PKR TO 2500 PSI SHEAR OUT F/PKR & REV OUT BALL @ 4 BPM @ 500 PSI TOP OF PKR 5006' RIG BJ TEST LINES & PREFORM DATA. FRAC W/22000# SAND OF WHICH 14200# ENDED UP BEHIND PIPE SCREENED OUT TO 4500 PSI RE-STRESSED TO 2000 PSI TWICE. REVERSED OUT EXCESS SD & ATTEMPT TO POSITION TOOL TO RE-STRESS PACK @ 3 BPM PSI = 300 PSI. RIG BJ & WORK ON BLENDER & ATTEMPT TO RE-STRESS & PACK SCREEN RATE & PSI PROVED SCREEN TO BE PACKED PRESSURED UP SEVERAL TIMES TO 2000 PSI OK. RIG DOWN BJ & BEGIN POH LD 3 ~" TUBING. Page 3 of 4 SUMMARY OF DALLY OPERATIONS DECEMBER 08, 1995 SERVICE RIG TOH LD 3 Y2 TBG CHG RAMS IN BOP & TEST SAME TIH W/13 STDS OF27/8"TBG &LDSAME RIG UP TO RUN ESPCOMP PICK UP PUMP, MTR& CHECK OUT RIH W/ESP COMP RIG UP RAYCHEM HEAT TRACE TAPE RIH W/ESP COMP HYDRAULIC LINE ON CENTRILIFT BROKE & LOST 3 HAL OF HYDRAULIC OIL RIH W/ESP COMP. DECEMBER 09, 1995 TIH W/ESP COMPLETION INSTALLING HEAT TRACE TAPE, SPACE OUT FOR HEAT TRACE & INSTALL HANGER & PENETRATORS. SPLICE ESP CABLE LAND HANGER RILDS - LD LANDING JT SET TWC. NIPPLE BOP'S & NU TREE ESP & HEAT TRACE & TEST TREE TO 5000# PULL TWC & SET BPV FREEZE PROTECT ANNULUS & TBG 12-BBLS & ANNULUS 63 BBLS DISCONNECT LINES FROM TREE & SECURE WELL. RIG DOWN & MOVING RIG TO C-22. RIG RELEASED @ 0400 HRS. Page 4 of 4 --- AOGCC ;~ind'i'viduat Wet ~ ~ ,3 e o i o 8 ~' c a i ~4 a t e r' ~' a 'i s .it. n v e,~ ,'. o r" y P E F~: i,'II T DATA T DATA._P L U S 94-.'-'106 ~/6311 T 251'?--6098 OH/CDR/'ADN 94--~106 ~;.337 T 6131...859-3 RLL/'GRC/E\,,/R 9a..--106 ~2 T LUD/CDR/ADN 9a.~I06 ~ R COb~P DATEa 08/28/9a. 9/~'-~ 106 ~C,P ~ 08/1 ~-08/'26/"9~, 9a--.- 106 ~VEY R 112---8593 9a-'i06 ~ L ~800.-~5600 9a.--.. I06 ~DN L SEPIA 9a~-106 ~N--~TVD L SEPIA _ 9a .... 106 ~~ L 2500 .... 6100 9a .... 106 ~R L SEPIA 9a---'106 ~~-TVD L SEPZA 9a.'-~106 ~/'DGR L 5890'~-8595 9a.-~ 106 ~WR~,/DGR L. }}993~a. 0i0 TVD~ r'e q u ~' r'e d ? y e s ~r'e c e 'i' v e d 'i' y e s ,/es ~-~~'i's &. d¢,.~,'"'",'p*~' .... ; o R r" ~i~ <c e 'i' v e dj "? I'1 0 y ~ :E; r'~ O GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 100g0 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 3/26/96 Field: Greater Point Mclntyre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27)] Floppy Well Job # Log Description Date BL RF Sepia Disk N PRUDHOE BAY ST #3 IBP SETTING RECORD 9 51 1 1 I I 1 , , , LISBURNE L4-32 TUBING PATCH RECORD 9 51 1 2 2 I 1 ,, .. SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: i'/tAr 2 'J i996 Oil & Gas Cons. Commission Anchora,,;e LARRY GRANT Attn. ALASKA OIL + GAS cONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP MPJ-08 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 GR/CCL FINAL BL+RF Date: RE: 5 December 1995 Transmittal of Data ECC #: 6260.01 Sent by: HAND CARRY Data: GR/CCL Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or F~ to (907) 563-7803 Received by~~/~/~~~~---/_ DEC 1995 4nchorage WELL LOG TRANSMITTAL To~ ARCO Alaska Inc. December 8, 1994 Attn: Larry Grant, AOGCC P.O. Box 100360 Anchorage, Alaska 99510-0360 ~ ~,~ [ 0 (t9 MWD Formation Evaluation Logs - MPJ-08 f The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2"x 5" MD Resistivity and Gamma Ray Logs: 2" x 5" TVD Resistivity and Gamma Ray Logs: 1 Magnetic Tape w/LDWG Listings ~' 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia ' 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification ol Service Well OIL [] GAS [] SUSPEND~ [] ABANDONED I-I SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration (Alaska)/nc. 94-106 3. Address ~,. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 s0- 029-22497 4. Location of well at surlace ~~.~ ;9. Unit or Lease Name 2574' NSL, 3343' WEL, SEC. 28, T13N, R10E ! :: ........~ '~ Mi/ne Point Unit ~~,/~. 10. Well Number, l MPJ-08 At Top Producing Interval 2 7' NSL, WE , SEC. T 3N, R OE At Total Depth 2654' NSL, 4655' WEL, SEC. 21, T13N, RIOE ! ~d__ ..... ~' Milne Point Unit - Schrader Bluff Pool 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 64' ! ADL 315848 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, il offshore 116. No. of Completions 8/10/94 8/20/94 8/28/94I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey IO. Depth where SSSY set ~1. Th,ckness of Permafrost 8593' MD/4075' TVD 8593' MD/4075' TVD '~s [] ~:> [] None ~eet MD 1800' (Approx.) 22. Type Electric or Other Logs Run L WD - ~/~£S 23. CASING, LINER AND CEMENTING RECORD SE'I-FING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 54.5# K-55 32' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 33' 2516' 12-1/4" 504 sx PF 'E'/250 sx "G' 7" 26# L-80 29' 6131' 8-1/2" 220 sx Class "G" 4-3/4" 9.2# L-80 5896' 8593' 6" Uncemented pre-packed graveI pack screen 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 (MDI Pre;?,acked gravel pack screen 2-7/8", EUE 8RD 6091' 5896' 6131-8593' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 0P, IGI L DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 9/3/94 I ESP Date of Test Hours Tested PRODUCTION FOR OIL-BBL ~AS-MCF WATER-BBL CHOKE SITF JGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brie! description of lithology, porosity, fractures, apparent dips, and presence o! oil, gas or water. Submit core chips. ~sk~ ~l & Gas G0ns. c0mmmm0~'' AnchorE~.~o Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGK:; MARKERS FuRMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEP'n=I TRUE VERT. DEPTH GOR, and time of each phase. Subsea Top Zone A 5025' 3824' Top Zone B 5080' 3837' Top Zone C 5183' 3862' 31. LIST OF ATTACHMENTS 32. I hereby certify/~hat the foregoing is true and correct to the best of my knowledge Signed Title Drillina Erl~_inecr Su.~ervisgr Date . INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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. R E C E IV E D Item 28: If no cores taken, indicate "none". Form 10~407 OCT 2 8 1994 ~sk~ Oil & Gas Cons. Colr~mission Anchora.~ MP J-08 08/10/94 194' MOVE RIG FROM MP J-09 TO MP J-08. NU DIVERTER, MIX SPUD MUD, BERM RIG, HOOK UP ELECTRICAL, WATER, AIR AND STEAM LINES. SERVICE TOP DRIVE. FUNCTION TEST DIVERTER. PU BHA #1 AND STAND BACK IN DERRICK. SPUD AND DRILL F/112-194'. ACCEPT RIG @2100 HRS ON 08/09/94. 08/11/94 2,530' DRILLING F/194-291'. MU BHA. DRILLING AND MWD SURVEY F/291-2530'. PUMP SWEEP. DROP EMS, PUMP SLUG. POH TO JARS. RETRIEVE EMS. RIH TO TD. NO PROBLEMS ON SHORT TRIP. CIRC AND CONDITION MUD. SPOT THERMOTHIN FOR GELATION CONTROL. POH. LD BHA. 08/12/94 2,530' FINISH LD BHA. RU TO RUN 9 5/8" CSG. RIH W/62 JTS 9 5/8" 40# L-80 BTC CSG. NO MUD LOSS. MU HANGER AND LAND CSG @2515'. CIRCULATE AND CONDITION MUD. PUMP 10 BBLS H20. TEST LINES. LEAK IN GREASE FI-I-i-lNG ON MANIFOLD. CIRC UNTIL REPLACEMENT MANIFOLD ARRIVED. REPLACE MANIFOLD. ND DIVERTER. PERFORM TOP JOB. RD EQUIPMENT. CLEAN CELLAR. INSTALL SPEED HEAD. NU BOPE. INSTALL WKM TEST PLUG. TEST BOPE. MU BHA. LOAD SOURCE IN LWD. 08/13/94 4,611' HAD PROBLEMS INSTALLING SOURCE IN PROPER POSITION IN LWD TOOL. FINISH MU BHA. SURFACE TEST MWD. RIH. TEST CSG. DRILL FLOAT EQUIP, CEMENT AND NEW FORMATION TO 2540'. PERFORM FIT TO 12.5 PPG W/8.6 MUD + 500 PSI @2497' TVD. DRLG 8 1/2" HOLE AND MWD SURVEY W/LWD F/2540-3569'. SHORT TRIP TO SHOE. NO PROBLEMS. DRLG 8 1/2" HOLE AND MWD SURVEY W/LLWD F/3569-4611'. CIRC SWEEP AROUND. DROP EMS, PUMP SLUG. POH TO SHOE. RETRIEVE EMS. RIH. 08/14/94 5,650' FINISH RIH. DRLG 8 1/2" HOLE ANS MWD SURVEY W/LWD F/4611-5034'. POH W/STDS TO 4800'. REAM AND LOG F/4800-4875'. SIDE TRACKED. DRLG 8 1/2" HOLE AND MWD SURVEY W/LWD F/4875-5650'. BACK REAM AND LOG 8 1/2" HOLE FROM 5648-5030'. 08/15/94 6,145' RECEIVED OCT 2 8 1994 ,~iaska ~Jll & Gas Cons. Commission Anchora,,? FINISH LWD LOG UP TO 4900'. PUMP PILL. POH TO SHOE. NO PROBLEMS. SERVICE TOP DRIVE. RIH, NO PROBLEMS. REAM LAST STAND TO BO'I-FOM. NO FILL. DRLG 8 1/2" HOLE AND MWD SURVEY W/ LWD F/5650-6145'. PUMP LO/HI VIS SWEEPS. SHORT TRIP TO 3300'. NO PROBLEMS. PUMP LO/HI VIS SWEEP. SPOT PILL FOR RUNNING CSG. POH.. SLM.. NO CORRECTION. CHANGE RAMS TO 7". STAND BACK HWDP. LD BHA. COWN LOAD LWD. LD BHA. PULL WEAR BUSHING. SET TEST PLUG. TEST BONNETS. RU AND RIH W/7" CSG. 08/16/94 6,145' RIH W/CSG TO 2508'. CBU. RIH W/7" CSG. MU HANGER AND LAND CSG AT 6132'. CIRC AT 12 BPM WHILE RECIPROCATING CSG. TEST LINES. DID NOT BUMP PLUG. LD LJ. CLEAR FLOOR. INSTALL 7" PACKOFF. WILL NOT TEST. PULL PACK OFF AND INSPECT SAME. RERUN PACKOFF. CHECK MEASUREMENTS. NO TEST. REPLACE PACKOFF. ND WELL HEAD. REMOVED SMALL PIECE OF ALLUMINUM ALLOY METAL THAT WAS WEDGED ON TOP OF HANGER. INSTALL PACKOFF AND TEST. NU WELL HEAD. CHANGE OVER TOP DRIVE TO 3 1/2" SET TEST PLUG. ANNULAR PREVENTER FAILED TO TEST. ND FLOW LINE AND RISER. REPLACE ANNULAR ELEMENT. RU TEST EQUIP. TEST ANNULAR AND RAMS. MU BHA. 08/17/94 6,318' MU BHA. LOAD NEUTRON SOURCES, TEST TOOLS. RIH WHILE PU 3.5" DP AND TAG CMT @5928'. TEST 7" CSG. DRILL HARD CEMENT, FE, AND 10' OF NEW FM TO 6156'. CBU AND DISPLACE 9.9 PPG LSND MUD WITH 9.9 PPG NEW FLO-PRO FLUID. DRLG F/6156-6222'. CBU - ZERO LOSSES, PULL INTO 7" SHOE, SHUT DOWN PUMP AND MONITOR FLUID LEVEL IN WELL. SLACK OFF INTO HOLO TO 6222' W/NO PUMPS. NO INDICATIONS OF HOLE INSTABILITY OR FILL. POH FOR FAILED ANADRIL SLIMHOLE GR/DIR. DOWNLOAD SPERRY GR/RES. ANADRIL PULSAR PLUGGED WITH SCALE FLAKES. CHANGE OUT PULSAR. SERVICE WEAR RING. RIH TO 6222'. OPEN HOLE IN GOOD SHAPE. DRLG F/6222-6311' 08/18/94 6,921' DRLG F! 6311-6756'. MWD TOOL NOT WORKING. AI-I'EMPT TO RESTART W/ NO SUCCESS. POH. REPLACE MDC'S W/M HWT. SERVICE WEAR BUSHING. RIH. REAM F/6641-6756'. DRLG F/6756-6921' 08/19/94 7,793' DRLG F/6921-7462'. MWD TOOL NOT WORKING. ATTEMPT TO RESTART W/ NO SUCCESS. CBU, PUMP PILL. POH. CHANGE BITS. SERVICE WEAR BUSHING AND TOP DRIVE. SET UP NEW ANADRILL TOOL. RIH. CHECK BENCHMARK, REAM AND LOG F/6907-7462'. DRLG F/7462-7793'. RECEIVED OCT 2 8 199~ 0il & Gas Cor~s. Commission Anchora ~, 08/20/94 8,593' DRILLING F/7793-8192'. CBU. PUMP PILL. POH TO DC'S. PU ADDITIONAL 12 DC'S. RIH. NO PROBLEMS. DRLG F/8192-8379'. RELOG FROM 8310- 8360'. DRILLING F/8360-8593'. 08/21/94 8,593' CBU. SHORT TRIP TO SHOE. NO PROBLEMS. CBU. R AND R PIPE WHILE CIRC. POH. LD MWD. NO CORRECTION. NU SPERRY SUN COLLAR. RIH. MU CSG SCRAPER. SERVICE TOP DRIVE. RIH. REAM F/6131-6500'. NO PROBLEMS. REAM AT MAX 450'/HR FOR LOGS F/6500-8593'. CBU. SPOT XANVIS PILL ACROSS OH. POH TO SHOE. CLEAN PITS AND PREP F/ BRINE DISPLACEMENT. 08/22/94 8,593' CLEAN PITS. PUMP SPACER. PUMP 50 BBLS XANVIS/BRINE SPACER. DISPLACE WELL W/9.8 BRINE. CIRC AND FILTER BRINE UNTIL CLEAN. POH. DOWNLOAD SPERRY SUN TOOL. CLEAR FLOOR. SERVICE WEAR RING. RU PREPACK LINER EQUIP. RIH W/BAKER 4 3/4" PREPACK SCREENS. 08/23/94 8,593' FINISH MU 4 3/4" PREPACK LINER. RIH AND SPACE OUT 2 1/16" WASH PIPE. MU HOOK UP NIPPLE. RIH TO 5981'. BREAK CIRC. ROTATE LINER. RIH W/LINER SLOW. TAG BOTTOM @8593'. NO HOLE PROBLEMS. SPACE OUT W/PUPS FOR LOW CONNECTIONS. RU ATLAS WL. RIH AND CONFIRM POSITION OF RA SUB. NO CORRECTIONS. RU TO DISPLACE WELL. BREAK CIRC. PUMP 150 BBLS XANVIS/BRINE/HYPOCHLORITE PILL. DISPLACE TO JUNK TANK W/FILTERED SOURCE WATER. CIRC AND FILTER SOURCE WATER. 08/24/94 8,593' CIRC AND FILTER SOURCE WATER. DROP 1 3/4" BALL. PRESS DP TO RELEASE LINER. VERIFY LINER RELEASE BY UP AND DOWN WT. REVERSE OUT BALL. PUMP 250 BBLS 180 SOURCE WATER. HEAT SOURCE WATER IN PITS TO 180 DEGREES. UNSTING FROM FLAPPER VALVE. CIRC 180 SOURCE WATER. MONITOR WELL. WELL IS STATIC. RECEIVED OCT 2 8 199~ ~iaska. iJJi & Gas Cons. Commission Anchors. ,,2 08/25/94 8,593' RU AND HEAT SOURCE WATER. PUMP BALL AND SHEAR OUT OF LINER. MONITOR WELL- NO LOSSES. POH TO 6048'. MIX AND PUMP 30 BBL XANVIS PILL. DISPLACE WITH SOURCE WATER AND FILTER UNTIL CLEAN. POH W/3 1/2" DP AND LD 2 1/16" WASH PIPE. RU FLOOR TO RUN PACKER ASSEMBLY. MU F-2 PACKER AND SEAL ASSEMBLY. RIH W/ PACKER AND SEAL ASSEMBLY ON 3 1/2" DP. 08/26/94 8,593' STING INTO HOOK UP NIPPLE. DROP BALL. PRESSURE UP AND SET F-2 PACKER @5895'. RELEASE PRESS. PULL 30K OVER AND TEST ANNULUS. INCREASE PSI AND RELEASE PACKER. PULL 10' AND BLOW OUT BALL. POH, LD 3 1/2" DP. FREEZE PROTECT TOP 2000' WITH DIESEL. FINISH POH. PULL WEAR RING AND CHANGE OUT TOP RAMS TO 2 7/8" AND TEST DOORS. RU FLOOR TO RUN TUBING AND PU 72 JTS 2 7/8" TUBING AND RIH. DISPLACE DIESEL WITH SOURCE WATER. POH. STANDING BACK THE AMOUNT OF TUBING TO BE RUN WITH HEAT TRACE. RU TO TUN ESP. MU ESP MOTOR, SEAL, AND PUMP. TEST AND FILL WITH OIL. HOOK UP CABLE. RUNNING ESP AND 2 7/8" TUBING. 08/27/94 8,593' RUNNING ESP, TUBING AND HEAT TRACE. 08/28/94 8,593' MU GAS LIFT MANDREL WITH HEAT TRACE AND ESP CABLE. TALKED WITH PRODUCTION SUPERVISOR AND DECIDED TO RUN FLAT CABLE TO SURFACE. RU CAMCO AND HI-POT TEST. SPLICE CABLE. FINISH RUNNING TUBING, ESP CABLE, AND HEAT TRACE TO SURFACE. SPACE OUT AND MU HANGER. SPLICE ESP PIG TAIL. LAND HANGER. RUN IN LOCK DOWN SCREWS AND LD LANDING JT. CHANGE TOP DRIVE TO 5" AND CHANGE TOP RAMS TO 5". NSTALL ADAPTOR FLANGE AND TEST SAME. TEST ESP CABLE. NU TREE AND TEST. PULL CHECK VALVE AND PUMP 51 BBLS DIESEL DOWN ANNULUS AND ALLOW TO U-TUBE TO FREEZE PROTECT 9 5/8" X 7" CASING. SET BPV. RELEASE RIG @0400 HRS ON 08/28/94. Gas Cons. Oommissior~ Anchora ,~ RECEIVED OCT 2 8 1~g4 Alaska Oil & Gas Cons. Coramission Anchor~, :'~ O+C)fi :' '-'". r",, F::". . . o "..:, ~'..; .., . ~- -.. C;, f;-:) :, ,-,,"--_-c. "--.'8,7'~ ,'... r:,:: _..... n. i -': :' ':' ~':' '>"' 0,2::-' 0:6,2: "' ~'"' 8-.;'.34 ..... i007.~Q !!01,!2 i !75, ~:: i477,67 1571,55 1668,79 176~,72 r:. r. 17Ai g9 1,54 .~-: z-,- ' "" = :" .... 81 -""~ ' - ,-.~ +,.v ~J+// .~,~..= 2,, Z,t: ,~ 0,14 ..... =: z-c, ~ ~ A,~,7 6,';'7 80.34 i,i<' S,W 34~09 _ · ....i. ';.7 7,51%_. .' ,~d ..',, ,c~ ,.. ~ :z. 0>,~... ii,36 2,45 7,,:13 8,0g 71'., ~,~. z ...... · i., iS 0,62 24~27 4,2i ,S133 ?,.37 5,00 r.,., ,o.._"-: )3'?.0~ 5,02 ~:,.~u v,:,: -.c.. ~_Y ., ,,.-... r ~ ~-, '"- ~ ."~:t "- , '.-" t 5' ~ :'J.t ' :,,_,v i -- =' ~' 6,75 ..... ,0,! 0,37 ..... ', ~.r, ' ..... 6.32 ' "- 5.4! ...,:.. 27. _, -'.,, :: ........ _~v,' .... ,c,~ ,.,,.:~.,; "~. 4,25 7,61 ."',,~. , ""; :, 0,21 6,.5i !,i3 ',P.'.-'7,: ~ A.k,; .... 7,15. ,-Z,.'c ;' ~'' 4 ~ ~ ...' ""-- --" 'd, :.' '7 .-..._ -~,~='. 2 w 0'-" ~ 6:45 0,60 6,47 z,~::¢ ',,43 12137 4,a7 ......... -.q. C~ 1.3,67 ~a,,,,;,.: ~ '- _. ,:-'"0 + 1£ i6+ 6," ..... · .... - L 9¢ ,gC~ 7;24 32.5,70 9!,57 -r,,~ 23 "~ - ..... :,t -, =.-. :::%.A~ 10,2:..4 .q27 .-'a -:s ,:,~. _ix,:o '-7:7 35_.' '--:.'-:,i.1:-':.,34 ...... +=.=_ -~-.,:.l....,i. -.' **~ · -. -'.. , 96,3 !948,50 94,4 2~)5~72 15,54 3i9,97 67,79 ~&+[~ ..... ~-~ -27.63 _% ,93 33:.]. ,'.;7 3,2~ -42,06 79J'? .:,':,,:., L,;~ -60. !':,' i05:75 325, -80.41 137,76 ':14,30 ::: ~..3 i0-2,76 !72, &? -:'-?, 5.':. 2,25' -: .t 2, 2~93.i2 24r,:,.78 267:3~73 2755,~5 -12A,75 .... '",7~ .... LLO.. 2i2 S? "'= "- >:'~ "'" -238,56 38,S .~,2J' 30i5.76 342.~1. .. 25',6~- --.:o"~,17,',,- R45_.. ,72 c~ ..... -- 42g,!2 31,iZ 324,72 :-. £5. 475.92 S?.5 32,5J~ 3,ii 3675,5'8 3769.85 RECEIVED OCT 28 1994. Aiaska Oil & Gas Cons. Commission Anchor:., .? ~6~i --. % '-':'"': 3658,92 45';,:7,, '.:.' ~:- 1479+68 7i,84 3~0,96 1477~02 !558,78 72157 332,o5 155e,oi 500i~80 i Ai,": - !9 v= ,: .7.:: i, <,-A i .'&.':-7 + ~-~,~ .~.. ...... .' ..2 +~. £ ........ , :--, ,:, 6<,74.-.7,5 ':'--"-: ~'< 1803,$7-' 75,'?.7 :~7,5_-;i i i87,92 '~$ :?.. 34i.v~ ',, ,;, ...'~,. 7~ 76,40 .'_:~3,74 i972 93, i ".:..-5,,2.'-- 3967148 ,:..-'7,3 398-'3,.*:,5 9417 3'790,33 ..... 4000,4? 7£+~ ....... 77~53 80,68 ~4+97 2i52.9i 83+77 ' ..... 35~,.. - i ?13178 2417,2:...:- .:12;.-,, 48 -i276,75 ':-503,11 '.32'; · ' J-c.:, +7z .,- -128i .65 "= .... :,J-:..., o,*' -1282,i7 Z~-7i,211 '.13i - IZS:_';+Z¥ /_; _:- o + v'! 5. 7,2':; 5 ,~,'? (.' 5'?45,19 6'C-37 ~ %'.-: g"f7 :.:'-.:k..: / ~ '.d: 4023~08 4034+27 !~+~- . ..... 29,! ~047,53 82,74 ~58,59 2~7,3i -12,~,58 1836.77 -i?g5,qA ~21,01 ?:' cA ..... ~: · ;_: _. ! ,£5 i,37 i ,03 i,i4 815'.;' , 21) $'.-218+20 A2%, :_=-a ,..--~ .T:C L :Y, £U 8401,. 511':: :"--- * 4060:2:1 ~-. ,. .~.,....,-. ,.- C',.:+ t; 91:3:4076+06 ~=~,// 359,93 3C, i?,3~~ 31,82,61 86,70 35_,8.~3 3079.24 3!73,80 8?.~0 358,00 3i70,42 l 2 2,74 .54'.'.-:'2,20 C,C/ ! ,53 I, 0.'5 O. 5<' L';' 77. ': r: 7017, 7i::-.2,30 727'~ ..- 50 89,5 4075,95 92+0 4079,32 A~'~ 71.8 92,5 4078,27 37?0,94 88,7,3 759+~:; 2974,04 90+70 E+go 40AA+45_. 90,40 i ,.~ ~ %9-:+A0 -130,.'.,5.°, '""'" ~7 ....... 3'7 i 7 ,...-. ,,. =-- 37~7+52 -130~.4i ~:,,:17,15 54'-'.:,,'?4 i,?,} :,.:<7.,-,. <,,~ -I307,6,9 ..'.c.~,?'-;, zi 34i ,-37 2,c'~ cw.- :_,,,- .. a. ,..- , .' -' ....... '- .. ..:~1,c,' ?:~%', + K'-. -1304.;.,' 40A.:: r..z-i.%C',62 42.%,!5 .... v,.. .,,~,c, 2_, i ._,.' f,: f .t -12'}5,~0 4437,[3 - 15:';"7', ~ I q_:L,'r~",. - !289,'7','- 4,50'? , 44 ?4:3,75 . ~.~.: ,~.~ .... *OZ' 5L'.-: · ~--~ ,. ; ,": f.ff t £,/£ 2,62 / ~ -.2:-Z,,: r, < 4 / 82i2,50 830(:" ~ 95 84?:7(': 85!9,70 aa ~. 4-092.. gO :.'-:,_¥" .i. O' d ?-~, ~v _. ~ a.-.-; ~.-..-: ~t.~ _.~.-.-,-: ,.. ,.v--, · -- ----~; · ......... =-'-'=~' ': -~Sq:,,k~. o== or, =,2=,4,7~ -l;:Ov "" ~,4~4 '.CZ 34A,03 92, f q-'-.~.l ,._':.1 _:--.-_,~, + is .... ._._.-., +¢,_. ....... ,;c, _ ...... sc~,..,,..:-, z.--':"..',"";--., ..i.4 =,..:.;.q , r?..., ,.. , ., . ,,._. %,60 357 ,.¢,'::r' 52i:5.44 -1308.,78 544A,23.. '3,'::.*. .., 10 F'RFJTECTEi:TO TT_:, -:-s,~,.S ~:;7~,,64 5363,i4 :f3:,~.,o ~<~/.,>o b.::--'..-',/~ -i~ti.,.'.'.-,'7 5=i7..:75 E4,'5..,'--5 2,5:3 ,), 8:-' O. '04 TO: 500 W. International Airpod Road Anchorage, Alaska 99518-1199 October 24, 1994 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-661 The following data of the LWD DEPTH CORRECTED CDR ~,/~,DN for well MPJ-08, Job # 94289 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 State of AI~-'~' Alas~& Gas Conservation Comm. Att~. Larry Grant 3004,_Porcupine Drive Anch~99501 1 OH LIS Tape 3 Bluelines 1 Film Returning CDR, ADN, CDR & ADN - TVD 1 Blueline %, ) 1 RFolded Sepi?~_a ~ OXY USA, Inc Attn: Erma Galindo P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline I RFolded Sepia Sent Certified Mail P 676 541 348 PLEASE ACKNO CEIPT-~BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA)INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 Schlumberger Courier: SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE. ALASKA 995184 199 / / Received By: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 29 August 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ECC No. ~_~~MPJ-06 1 PFC/PERF FINAL BL Run # 1 6259.01 1 PFC/PERF RF SEPIA Run ~ 1 /-06 1 GR/CCL FINL.RF SEPIA Run # 1 6259.00 1 GR/CCL FINAL BL Run # 1 1 GR/CCL FINAL BL 1 GR/CCL RF SEPIA Run # 1 6260.00 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 RECEIVED Anchorage, AK 99518 ~/ ~~ney D. Paulson. SIP 0 1 ]994 Received b~. //~~/// //~.~ ,~__ Dat...~- Alaska Oil & Gas Cons. Commission Please s~gn and return to: Petrotechnical Data Center BP Exploration (Alaska) 900 East Benson Boulevard Anchorage, Alaska 99508 Received by MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission David Johns~, Chairma0~7 Blair Wondzell, .~~- P. I. Supervisor FROM' Bobby Foste~--~'- SUBJECT: Petroleum Inspector DATE: August 12, 1994 FILE NO: AWOIHLBD.doc BOPE Test - Nabors 22E BPX - MPU - J-08 PTD # 94-0106 Scharder Bluff Pool Friday, August 12, 1994: I traveled this date to BPX's MPU well J-08 being drilled by Nabors rig 22E and witnessed the BOPE test. As the attached AOGCC BOPE Test Report shows there were no failures. The rig was clean and all equipment seemed to be in good working order. The equipment on the location was all stored properly and there was good access to the rig. Summary: I witnessed the BOPE test on Nabors rig 22E - test time 2.5 hours - no failures. Attachment: AWOIHLBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: NABORS Rig No. 22E PTD # 9400106 Operator: BPX Rep.: Well Name: J-08 Rig Rep.: Casing Size: 9.625" Set ~_, 2515' Location: Sec. ~ Test: Initial X Weekly Other DATE: 8/12/g4 Rig Ph.# 659-6475/76 DONNIE LUTRICK LENORD SCHILLER 28 T. 13N R. IOE Meridian U MISC. INSPECTIONS: Location Gen.: OK Well Sign OK Housekeeping: OK (Gen) Dri. Rig OK Reserve Pit N/A BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams 1 c,h,d Rams 1 Choke Ln. Valves 1 HCR Valves Kill Line Valves Check Valve Test Pressure P/F 300/3,000 P 500/5,000 500/5,000 500/5,000 500/5,000 FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP CHOKE MANIFOLD: P No. Valves 17 P No. Flanges P Manual Chokes P Hydraulic Chokes 1 Test Quan. Pressure P/F 1 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P Test Pressure P/F 500/5,000 P 42 500/5, 000 P 1 P Functioned Functioned 2 500/5,000 P 1 500/5,000 P ACCUMULATOR SYSTEM: N/A System Pressure 3,100 P Pressure After Closure 1,350 P MUDSYSTEM: Visual Alarm 200 psi Attained After Closure 0 minutes 34 Tdp Tank OK YES System Pressure Attained 3 minutes 22 Pit Level Indicators OK YES Blind Switch Covers: Master: YES Remote: Flow Indicator OK YES Nitgn. Btl's: 4@ 2000 4@ 1800 Meth Gas Detector NOTE NOTE Psig. H2S Gas Detector OK YES sec. sec. YES Number of Failures: 0 ,Test Time: 2.5 Hours. Number of valves tested 23 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: Methane gas dectectors not working - parts on order to repair. Distribution: odg-Well File c- Oper.tRig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER F1-021L (Rev. 7t19) AWOIHLBD.XLS ALASKA OIL AND GAS CONSERVATION COMMISSION August 5, 1994 Adrian Clark Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re: Milne Point Unit MPJ-08 BP Exploration Permit No: 94-106 Sur. Loc. 2574'NSL, 3343'WEL, Sec. 28, T13N, RiOE, UM Btmhole Loc. 2120'NSL, 4600'WEL,. Sec. 21, T13N, R10E, UM Dear Mr. Clark: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill dOes not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field 59-3607. · David~. Johnston ~ ~ Chair~~ ~ BY ORDER OF T SSION 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 20 AAC 25.005 la. Type of work Drill [] RedrillF'lllb. Type of well. Exploratoryl-I Stratigraphic TestFl Development OilE1 Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 15. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 64' feet Milne Point Unit - Schrader 3. Address 6. Property Designation BluffPool P. 0. Box 196612. Anchoraae. Alaska 99519-6612 ADL 315848 4. Location of well at surface 7. Unit or property Name 11. Type Bond(se, 20 Mc 25.025) 2574' NSL, 3343' WEL, SEC. 28, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 4800' NSL, 4600' WEL, SEC. 28, T13N, RIOE MPJ-08 2S100302630-277 At total depth 9. Approximate spud date Amount 2120' NSL, 4600' WEL, SEC. 21, T13N, RIOE 8/8/94 $200,000.00 12. DJ'stance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) prop~/~L line 025906-2120' feet No close approach feet: 2560 8140' MD/4046' TVD feet !16. To be completed for deviated wells 17. Anticipated pressure Kickoff depth ~6oo feet Maximum hole angle 9o o Maximum surface 3330 psig At total depth (TVD) 8800'/4590 psi~ 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole . _Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data). 24" 13-3/8" 54.5# K-55 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 B TRC 2469' 31' 31; 2500' 24 77' 504 sx PF "E"/250 sx "G"/250 sx "C' 8-1/2" 7" 26# L-80 BTRC 5570' 30' 30' 5600' 4044' 150 sx Class "G" 6" 4-3/4" 9.2# L-80 NSCT 2700' 5440' 4022' 8140' 4124' Uncemented 19.To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth' measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface RECEIVED Intermediate Production ~,~Jg Liner Perforation depth. measured Ai~ska. 0ii & Gas Cons. Commission true vertiCal Anch0ra¢ 120. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drillin~ fluid progra/~ [] Time vs depth plot [] Refraction analysis r-1 Seabed reportF1 20 AAC 25.050 requirements[] 21.1 hereby ce~i,,f~t~t ,,th)e/~regoin~ is true and correct to the best of my knowledge Signed,//~,~/'~j,~,~/~. Title Drillin~7 En~tineer Supervisor Date t Commission Use Only Permit Number IAPI number IAppr~l date ISee cover letter .IS0-o.~_~-~~¢'~, ~-,~--~'~ Ifor other requirements Conditions of approval Samples required [] Yes [] No Mud log required []Yes ~ No Hydrogen sulfide measures [] Yes ~1~ No Directional survey required ~ Yes [] No Required working pressure for BOPE [] 2M; I-]3M; ~].5M' I-]10M' I--115M; Other: Original Signed By -~.. by order of Approved by ,*.,~4d W. Johnston Commissioner tne commission Date Form 10-401 Rev. 1'2' -85 Submit in 'iplicate [ Well Name: [ MPJ-08 Well Plan Summary [' Type of Well (producer or injector): ! Producer Surface Location: Target LOcation: Bottom Hole Location: 2574' NSL 3343' WEL Sec 28 T13N R10E UM., AK. 4800' NSL 4600' WEL Sec 28 T13N R10E UM., AK. '2120' NSL 4600' WEL Sec 21 T13N R10E UM., AK. [' AFE Number: ! 330061 [Estimated Start Date: [August1994 8, [MD: [ 8140' ! I TVD: [ Well Design (conventional, slimhole, etc.): [ Rig: I Nabors 22E IOperating days to complete: 14046' bkb I IKBE: I64' I [ Milne Point Ultra Slimhole 7LS x 4-1/2" Prepack ] Formation -Markers: Formation Tops MD TVD (bkb) base permafrost 1815' 1814' MA 4048' 3550' Ugnu Sands NA 4731' 3874' Top of Schrader Bluff (West Sak) Sands Target Top OA Sand 5540' 4044' Land 7" Casint~ at 87.1 del~rees Base of OA Sand 4074' Total Depth 8140' 4046' TD the Horizontal Hole Section Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD ,, 24" 13 3/8" 54.5# K-55 Weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 2469 31/31 2500/2477 8 1/2" 7" 26# L-80 btrc 5570 30/30 5600/4044 6" 4-3/4", 9.2# L-80 nsct 2700 5440/4022 8140/4124 Prepack Internal yield pressure of the 7" 26g casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 4124 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 1775 psi is 1560 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: R E~E[V E D [ Open Hole Logs: Surface Intermediate Final [Cased Hole Logs: None Al IR - LWD Triple Combo (DIR/GR/RES/NEU/DENS) ......... LWD GR Real Time/RES Memory Alaska 0il & Gas Cons. C0mmis[si0n GR/CCL will be run during N Sand Completion. CBL run onl~dltor~,ggssary.] A gamma ray log will be obtained from surface to TD. Mud Logging is not required. Mud Program: ISpecial design considerations I Surface and Intermediate: Spud Mud and LSND, respectively. I Horizontal Hole Section: Flo-Pro Xanvis Fluid. Surface Mud Properties: SPUD MUD ] Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 tO tO tO tO tO tO tO 9.6 90 35 15 30 10 15 Intermediate Mud Properties: LSND [ Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 12 5 7 9 4 tO tO tO tO tO tO tO 10.4 50 20 10 12 10 6 Production Mud Properties: Flo-Pro Xanvis i _DensitL __ _Brookefield Yield .... 10 sec , 10 min pH Fluid (P P G ) Viscometer Point gel gel Loss 9.8 +60,000 30 12 18 9 4 to LSRV to to to to to 10.0 35 15 20 10 10 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: IKOP: 11600' I [Maximum Hole Angle: I 90 degrees [ Close Approach Well: [ (No Shut Ins) Disposal: Cuttings Handling: CC2A iC. EIVED -- 5 1994 Alaska 0il & Gas Cons. Commission Anch0ra.~ Fluid Handling: All ddlling and completion fluids can be annular injected. Otherwise, Haul to CC2A. Annular Injection: The MPJ-0$ annulus is permitted for drilling & completion fluid injection. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED VOL (BBLS) (BBLS) Milne Point MPJ-08 0 35,000 5/3/94 thru 2/20/9 MIIne Point MPJ-06 2000 35,000 5/3/94 thru 2/20/9 ! Milne Point! MPJ-09 ! 2000 ! 35,000 15~3~9,~ thru FREEZE PROTECTION' Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annunlus was injected into to avoid freezing. 2/20/9 R'ECEIVED AUG -5 1994 Alaska 0il & Gas Cons. Commission Anchor%a MPJ-08 Proposed Summary of Operations 1. Drill and Set 13-3/8" Conductor. Weld a starting head on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. NU and test 20" Diverter system. Build Spud Mud. 5. Drill a 12-1/4" sudace hole, run and cement 9-5/8" casing. Run only Dir MWD (No LWD required). 6. ND 20" Diverter, NU and Test 13-5/8" BOPE. 7. RIH w/ 8.5" Insert bit on Low Speed/High Torque Motor, and Directional/Gamma Ray, Resistivity/Neutron/Density (Triple Combo) MWD/LWD. Test 9-5/8" casing to 3000 psig, Drill out float equipment and 10 feet of new formation, Perform a LOT. 8. Drill ahead in the intermediate hole section and land the horizontal hole section into the ........ topof theOA-Sand-at 88° as per directional program. Begin weight up to 9.8 ppg at the MA Sand top. POOH, LD the Insert Bit and Motor while laying down the 5" drill pipe. 9. Run & cement 7" intermediate casing. Install and Test Pack-off. 10. MU Insert bit on Iow speed high torque 4-3/4" motor, Dir/GR real time as close to bit as possible, and GR/RES memory. Finish RIH while PU 3-1/2" drill pipe. 11. Test 7" casing, drill out Float Equipment and 10' of new formation. 12. Displace the LSND drilling fluid with 9.8 ppg New FIo-Pro Xanvis. 13. Drill 6" horizontal hole section -- trip for bit as necessary. Wiper trip to shoe at TD. 14. POOH and lay down 6" BHA and make 6" hole opener run. Spot clean Xanvis drilling fluid system across the openhole. POOH and displace top 3000 feet of hole with clean brine. 15. MU 3-1/2" x 4-3/4" Prepack Liner and wash pipe. RIH with liner on 3-1/2" drill pipe. 16. Displace Xanvis out of the hole with 150 bbl 3 ppb Xanvis/Brine/4 bbp Lithium Hypochlorite Pill followed with 1.5 hole volumes of source water. Pump 200 bbls of heated Lithium Hypochiorite and spot first 100 bbls across open hole. Alternate high pump (5 bpm) and soak (30 minute) treatments at 25 bbl increments. . 17. Release from liner. Unsting wash pipe and circulate heated 8.5 ppg source water inside liner for 6 to 8 hours at 4-6 bpm. Displace inside of liner and spot 25 bbls of Lithium Hypochlorite inside liner. POOH and space washpipe on top of liner. Circulate out top of liner. POOH with liner running tool. Run sump packer and perform perforation and gravel pack operations on the N Sands. 18. 19. 20. 21. ND BOPE, NU and Test the Frac Tree. Set BPV in 7" x 11" tubing hanger. RDMO Nabors 22E drilling rig to drill MPJ-10. ESP production system will be run with Coil Tubing Unit. RECEIVED AUG -5 1994 Alaska Oil & Gas Cons. Commission Anch0r~.~a MPJ-08 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" SPACER: 75 bbls fresh water. CIRC. TEMP 50 deg F at 2500' TVDSS. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 504 THICKENING TIME: Greater than 4 hrs at 50° F. Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk TAIL CEMENT TYPE: ADDITIVES: 2.0% CaCI2 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS: 100-150 cc Premium G YIELD:1.15 ft3/sx MIX WATER' 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE: Permafrost C ADDITIVES: Retarder WEIGHT: 15.6 ppg YIELD: 0.96 cu ft/sk. MIX WATER: 3.7 gal/sk APPROX NO SACKS: 250 CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 10 joints of casing (10 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS' Pedorm lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 623' md above the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' rnd with 30% excess and from 1500' md to sudace with 100% excess. 3. 80'rnd 9-5/8", 40# capadty for float joints. R E 6 E iV E D 4. Top Job Cement Volume is 250 sacks. AUG - 5 1994 Alaska 0il & Gas Cons. Commission Anchorajc MPJ-08 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON PRIMARY CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: SPACER' 140°F BHST 170degFat 7040' TVDSS. 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE' Premium G ADDITIVES' 0.2% CFR-3, 0.2% Halad 344, 2.0% CaCI2 W_EIGHT_: l_5.Sppg ........ YI_ELD: 1_. 15 cu ft/s.k APPROX # SACKS: 150 FLUID LOSS: 100-150 cc MIX WATER: 5.0 gal/sk THICKENING TIME: 4 hours @ 50 FREE WATER' 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- two per joint on the bottom 29 joints of 7" Casing (58 total). This will cover 300' above the NA Sand Top. 2. Run one 7"x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 3. Total 7"x 8-1/4"Straight Blade Rigid Centralizers needed is 59. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME' 1. Cement volume is calculated to cover from the OA Sand Top to 500' above the NA Top with 30% excess. Gas Cons. 6omrnis¢on Anchor~.~," PRUDHOE BAY DRI 1104 _LING GROUP MPJ-08 (P12) PLAN VIE CLOSURE ' 4989 feet at Azimuth 345.25 Marker Identification RS N/S A) KB 0 0 B) KOP BUILD 2.5/I00 ~600 0 C) STARI 2.5/100 CURVE 3200 4~! DJ END OF 2.5/100 CURVE 4488 ~282 E) START 5/~00 BUILD 4876 F) -- TOP DA TAR~£T -- 5540 2225 i263 G) BUILD ~.~/~o0 5540 2225 ~253 H) END OF 5/100 8U!L~ 5540 2225 1263 I) END OF ~.5/100 BUILD 5673 2359 ~263 J) TO 8~40 4825 1270 )ECLINATION.' 30.000 E ;CALE ' ~ inch : 800 feet DRAWN ' 08/02/g~ AnaUr i ] ] $ch ] umberger i ; ~ ALtO -'5 1994 ~ -, ; .... ~ _ .. : ,',, .~.~,~ Oil i, Gas Co~s. COBBi ' Anchor~- i60C t200 800--- 400- 4O0 2800 240O 2000 i600 2200 800 430 0 400 BO0 ~200 ~600 2OOC 2400 , <- WEST' EAST -> P UDHOE BAY DRILLING GROUP I /~nadri II Srf~lumberger =,,= ~, . ~, ~ MPJ-08 (P t2) VERTICAL SECIION VIEW Section at: 359.85 TVD Scale.: 1 incl} = 800 feet Dep Scale.: ~ inch = 800 feet Drawn ..... :08/02/94 Marker iden~ifica[ion MD BKB SECTN A) KB 0 -0 0 8) KOP OU[LD 2.5/t0D 1600 1C~O 0 Ct START 2,5/100 CURVE 3200 30Z3 4~2 0] END OF 2.5/100 ChiVE 4408 3795 1284 E] START 5/100 BUIL[] 4876 392t ~605 F) -- lOP OA TARGET -- 5540 4044 2228 G} BUILO ~.5/~00 5540 4044 2228 I~) Et~ OF 5/lO0 BUILD 5540 40d4 2228 ]~ ErlO OF 1.5/~00 GUILD 5673 ~()46 2362 ,~ TD 8140 K046 4028 - BO O - dOD 0 Illllllllll o - _ ]Z]--r ..... i ,tOO 1200 tGO0 .. lib 2000, 2400 2800 3200 Sect ion Departure INCLN 0.00 O.OO 40.00 71.04 7~ .04 BB.OO 8B.O0 88. O0 90. O0 90, O0 3600 4000 4,100 4~0 5200 5500 6900 6400 WELL PERMIT CHECKLIST FZ~LD ~ POOL 3~ / ~ O co~Y ~/~ PROGRAM: exp [] dev [] redrll~ serv [] ADMINISTRATION 1. Permit fee attached ................... 2. Lease number appropriate ................ 3. Unique well name and number ............... 4. Well located in a defined pool ............. 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 .............. 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 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT v°l adequate to circulate on conductor & surf csg. CMT vol adequate to tie-in long string to surf csg . . 17. CMT will cover all known productive horizons ....... 18. 19. Casing designs adequate for C, T, B & pezlnafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~~ 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to . .. 5~ psig.~ 27. Choke manifold complies w/API RP-§3 (May 84) ....... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............. GEOLOGY APPR 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y//~ 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . . J. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comm~nts/Instructions: Z 0 · '"~"heklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not Particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organiZe this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORATION WELL NAME : MPJ-08 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292249700 REFERENCE NO : 94289 I ICROFILI E-D LIS TaI~e Verification Listing Schlumberger Alaska Computing Center 11-JAN-1996 13:00 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/01/11 ORIGIN : FLIC REEL NAME : 94289 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION , MILNE POINT, MPJ-08, 50-029-22497-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/01/11 ORIGIN : FLIC TAPE NAME : 94289 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION , MILNE POINT, MPJ-08, 50-029-22497-00 TAPE HEADER MILNE POINT 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 O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD BIT RUN 1 94289 ST. AMOUR LUTRIK MPJ-08 500292249700 BP EXPLORATION SCHLUMBERGER WELL SERVICES 09-JAN-96 1ST STRING 2ND STRING BIT RUN 2 BIT RUN 3 28 13N iOE 2574 3343 65.20 65.20 35.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) PAGE: LIS Tape Verification Li~ting Schlumberger Alaska Computing Center 11-JAN-1996 13:00 3RD STRING PRODUCTION STRING REMARKS: THIS TAPE CONTAINS THE ADN AND CDR LOGGING WHILE DRILLING DATA FOR MPJ-08. !!PLEASE NOTE: THIS TAPE REPLACES LIBRARY TAPE PRIOR TO 9-JAN-96. $ **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUHBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH CDR 6144.5 2458.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH CDR 5568.0 5552.5 5524.5 5510.0 5514.0 5500.5 5477.5 5462.5 5433.0 5420.0 5395.5 5382.5 5381.5 5371.0 5376.0 5367.0 5367.0 5356.0 5278.5 5264.5 5261.0 5247.5 5212.5 5199.0 5198.5 5186.0 5177.0 5166.5 5142.0 5130.5 5075.5 5066.0 4980.5 4973.0 4964.5 4956.5 4919.5 4902.0 EQUIVALENT UNSHIFTED DEPTH .......... LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-JAN-1996 13:00 4877.5 $ MERGED DATA SOURCE LDWG TOOL CODE CDR CDR CDR $ REMARKS: 4860.0 BIT RUN NO. MERGE TOP MERGE BASE 1 5580.0 6144.5 2 4875.0 5580.0 1 2458.0 4875.0 THIS FILE CONTAINS THE MWD MAIN LOG DRILLING DATA WITH THE FOLLOWING EXCEPTION: AT BP's REQUEST THE UPLOGGED CDR DATA WAS SPLICED INTO THE MAIN LOG DRILLING DATA OVER THE INTERVAL FROM 4875' TO 5580'. PRIOR TO SPLICING, THE UPLOGGED DATA WAS DEPTH CORRECTED TO THE MAIN LOG DRILLING DATA. THE DATA HAS BEEN CLIPPED SO AS TO INCLUDE ONLY VALID READINGS. $ LIS FORMAT DATA PAGE: 3 TABLE TYPE : CONS TUNI VALU DEFI CN BP EXPLORATION Company Name FN MILNE POINT Field Name WN MPJ-08 APIN 500292249700 FL 2574' FSL & 3343' FEL SECT 28 TOWN 13N RANG IOE COUN NORTH SLOPE STAT ALASKA NATI USA LATI 70.45164844N LONG 149.57591777W WITN LUTRIK PDAT MSL EPD FT O. LMF DRILL FLOOR APD FT 65.2 EKB FT 65.2 EDF FT 65.2 EGL FT 35. TDD FT 6145. TDL FT 6145. BLI FT 6145. TLI FT 2513. DFT LSND DFD G/C3 9.800001 RMS OHMM 2.55 Well Name API Serial Number Field Location Section Township Range County State or Province Nation Latitude Longitude Witness Name Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Depth - Logger Bottom Log Interval Top Log Interval Drilling Fluid Type Drilling Fluid Density Resistivity of Mud Sample LIS T~pe Verification Lis'ting Schlumberger Alaska Computing Center 11-JAN-1996 13:00 PAGE: 4 TUNI VALU DEFI MST DEGF 70. Mud Sample Temperatur~ RMFS OHMM 1.17 Resistivity of Mud Filtrate S MFST DEGF 70. Mud Filtrate Sample Temperatu BHT DEGF 145. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth RA CDR ATTN RESISTIVITY RP CDR PHSF RESISTIVITY DER DIELECTRIC RESISITIVTY VRA QRO VERY ENHANCED AMPLITUDE RESISTIVITY VRP QRO VERY ENHANCED PHASE RESISITIVTY ROP RATE OF PENETRATION GR Gamma Ray FET TIME AFTER BIT DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE- _ 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 _~S T6pe Verification Lis;~ing Schlumberger Alaska Computing Center 11-JAN-1996 13:00 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMBSIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ~ F~ oo ooo oo o ~ ~ -"~ ..... ~ ..... ~ ....~~- ooooo oo0~ ~ ~ ~ 68 oooooooooo RA MWD OHMM RP MWD OHMM O0 000 O0 0 1 1 I 4 68 0000000000 DER MWD OHMM O0 000 O0 0 1 1 i 4 68 0000000000 VRA MWD OHMM O0 000 O0 0 1 1 I 4 68 0000000000 VRP MWD OHMM O0 000 O0 0 1 1 I 4 68 0000000000 ROP MWD FPHR O0 000 O0 0 1 1 I 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 i 4 68 0000000000 FET MWD HR O0 000 O0 0 i I I 4 68 0000000000 ** DATA ** DEPT. 6144.500 RA.MWD -999.250 RP.MWD -999.250 DER.MWD VRA.MWD -999.250 VRP.MWD -999.250 ROP.MWD 226.723 GR.MWD FET.MWD -999.250 DEPT. 6000.000 RA.MWD 4.778 RP.MWD 4.600 DER.MWD VRA.MWD 4.740 VRP.MWD 4.583 ROP.MWD 233.995 GR.MWD FET.MWD 0.436 DEPT. 5500.000 RA.MWD 4.352 RP.MWD 4.236 DER.MWD VRA.MWD 4.434 VRP.MWD 4.310 ROP.MWD 41.373 GR.MWD FET.MWD 0.147 DEPT. 5000.000 RA.MWD 4.359 RP.MWD 4.064 DER.MWD VRA.MWD 4.287 VRP.MWD 4.036 ROP.MWD 118.679 GR.MWD FET.MWD 0.343 DEPT. 4500.000 RA.MWD 3.299 RP.MWD 2.952 DER.MWD VRA.MWD 3.254 VRP.MWD 3.004 ROP.MWD 617.379 GR.MWD FET.MWD 0.337 DEPT. 4000.000 RA.MWD 6.937 RP.MWD 6.519 DER.MWD VRA.MWD 6.735 VRP.MWD 6.785 ROP.MWD 466.020 GR.MWD FET.MWD 0.326 DEPT. 3500.000 RA.MWD 6.627 RP.MWD 5.673 DER.MWD VRA.MWD 5.902 VRP.MWD 5.720 ROP.MWD 212.739 GR.MWD FET.MWD 0.317 DEPT. 3000.000 RA.MWD 6.410 RP.MWD 5.531 DER.MWD VRA.MWD 5.904 VRP.MWD 5.445 ROP.MWD 243.128 GR.MWD FET.MWD 0.410 DEPT. 2500.000 RA.MWD -999.250 RP.MWD -999.250 DER.MWD VRA.MWD -999.250 VRP.MWD -999.250 ROP.MWD -999.250 GR.MWD FET.MWD -999.250 -999.250 -999.250 4.654 106.554 4.273 74.076 4.151 73.215 3.057 42.915 6.640 71.119 5.944 95.607 5.785 89.938 -999.250 26.805 LIS T~pe Verification Listing Schlumberger Alaska Computing Center 11-JAN-1996 13:00 PAGE: DEPT. 2458.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 ROP.MWD -999.250 FET.MWD -999.250 DER.MWD GR.MWD -999.250 46.353 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/11 MAX RE¢ SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves~ all MAD runs merged using earliest passes. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH CDR 5586.0 4747.0 ADN 5630.0 4772.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH CDR ADN 5568.0 5552.5 5524.5 5510.0 5514.0 5500.5 5477.5 5462.5 5433.0 5420.0 LIS T~pe Verification Lis~ing Schlumberger Alaska Computing Center 11-JAN-1996 13:00 5395.5 5381.5 5376.0 5367.0 5278.5 5261.0 5212.5 5198.5 5177.0 5142.0 5075.5 4980.5 4964.5 4919.5 4877.5 $ HERGED DATA SOURCE LDWG TOOL CODE CDR CDR $ REMARKS: 5382.5 5371.0 5367.0 5356.0 5264.5 5247.5 5199.0 5186.0 5166.5 5130.5 5066.0 4973.0 4956.5 4902.0 4860.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE I 2 4837.0 5586.0 1 I 4747.0 4830.0 THIS FILE CONTAINS THE MAD ACQUIRED CDR AND ADN DATA. THE CDR DATA IN THIS FILE IS A MERGE OF THE UPLOGGED AND WASHDOWN CDR PASSES. THERE WAS ONLY i PASS OF ADN DATA AND IT WAS ACQUIRED AS AN UPLOG PASS. BOTH THE CDR AND ADN HAVE BEEN DEPTH CORRECTED TO THE MAIN LOG DRILLING DATA. $ LIS FORMAT DATA PAGE: 7 TABLE TYPE : CONS TUNI VALU DEFI CN ............ ~-~¢[6~5i6~ ................. ~;;~;;~-~;;;- FN MILNE POINT Field Name WN MPJ-08 APIN 500292249700 FL 2574' FSL & 3343' FEL SECT 28 TOWN 13N RANG IOE COUN NORTH SLOPE STAT ALASKA NATI USA LATI 70.45164844N LONG 149.57591777W WITN LUTRIK PDAT MSL EPD FT O. Well Name API Serial Number Field Location Section Township Range County State or Province Nation Latitude Longitude Witness Name Permanent datum Elevation of Permanent Datum ..~ Tape Verification List'ing Schlumberger Alaska Computing Center 11-JAN-1996 13:00 PAGE: 8 TUNI VALU DEFI LMF DRILL FLOOR Log Measured From FT 65.2 Above Permanent Datum APD EKB FT 65.2 EDF FT 65.2 EGL FT 35. TDD FT 6145. TDL FT 6145. BLI FT 6145. TLI FT 2513. DFT LSND DFD G/C3 9.800001 RMS OHMM 2.55 MST DEGF 70. RMFS OHMM 1.17 MFST DEGF 70. BHT DEGF 145. Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Depth - Logger Bottom Log Interval Top Log Interval Drilling Fluid Type Drilling Fluid Density Resistivity of Mud Sample Mud Sample Temperature Resistivity of Mud Filtrate S Mud Filtrate Sample Temperatu Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth RHOB Bulk Density ROBU RHOB UPPER QUAD ROBR RHOB RIGHT QUAD ROBB RHOB LOWER QUAD ROBL RHOB LEFT QUAD DPHI Density Porosity DRHO Delta RHO PEF PhotoElectric Factor CALN NUCLEAR CALIPER NPHI Thermal Neutron Porosity RA CDR ATTN RESISTIVITY RP CDR PHSF RESISTIVITY DER DIELECTRIC RESISITIVTY VRA QRO VERY ENHANCED AMPLITUDE RESISTIVITY VRP QRO VERY ENHANCED PHASE RESISITIVTY ROP RATE OF PENETRATION GR Gamma Ray _~ Tape Verification Listing Schlumberger Alaska Computing Center 11-JAN-1996 13:00 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64ED ** TYPE REPR ~66~-- VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** -- NAME SERV UNIT SERVICE AP! API API APl FILE NUMB ~--~i~--~---~6~- ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT OD O00 OD O 2 1 .... i ..... ~ ..... ~ .... ~~- RHOB MAD G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 ROBU MAD G/C3 O0 000 O0 0 2 I 1 4 68 0000000000 ROBR MAD G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 ROBB MAD G/C3 O0 000 O0 0 2 I i 4 68 0000000000 ROBL MAD G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 DPHI MAD PU O0 000 O0 0 2 I 1 4 68 0000000000 DRHO MAD G/C3 O0 000 O0 0 2 i i 4 68 0000000000 PEF MAD BN/E O0 000 O0 0 2 i 1 4 68 0000000000 CALN MAD IN O0 000 O0 0 2 1 i 4 68 0000000000 NPHI MAD PU-S O0 000 O0 0 2 1 1 4 68 0000000000 RA MAD OHMM O0 000 O0 0 2 ! 1 4 68 0000000000 RP MAD OHMH O0 000 O0 0 2 i i 4 68 0000000000 DER MAD OHMM O0 000 O0 0 2 I i 4 68 0000000000 VRA MAD OHMM O0 000 O0 0 2 i 1 4 68 0000000000 VRP MAD OHHM O0 000 O0 0 2 1 1 4 68 0000000000 ROP MAD FPHR O0 000 O0 0 2 I I 4 68 0000000000 GR MAD GAPI O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** _~ Ta)~e Verification Listing Schlumberger Alaska Computing Center DEPT. 5630.000 RHOB.MAD ROBB.MAD -999.250 ROBL.MAD PEF.MAD -999.250 CALN.MAD RP.MAD -999.250 DER.MAD ROP.MAD -999.250 GR.MAD DEPT. 5500.000 RHOB.MAD ROBB.MAD 2.245 ROBL.MAD PEF.MAD 2.906 CALN.MAD RP.MAD 4.236 DER.MAD ROP.MAD 41.373 GR.MAD DEPT. 5000.000 RHOB.MAD ROBB.MAD 2.256 ROBL.MAD PEF.MAD 3.387 CALN.MAD RP.MAD 4.064 DER.MAD ROP.MAD 118.679 GR.MAU DEPT. 4747.000 RHOB.MAD ROBB.MAD -999.250 ROBL.MAD PEF.MAD -999.250 CALN.MAD RP.MAD -999.250 DER.MAD ROP.MAD -999.250 GR.MAD 11-JAN-1996 13:00 -999.250 ROBU.MAD -999.250 DPHI.MAD -999.250 NPHI.MAD -999.250 VRA.MAD -999.250 2,225 ROBU.MAD 2.234 DPHI.MAD 9.175 NPHI.MAD 4.273 VRA.MAD 74.076 2.201 ROBU.MAD 2.244 DPHI.MAD 9.274 NPHI.MAD 4.151 VRA.MAD 73.215 -999.250 ROBU.MAD -999.250 DPHI.MAD -999.250 NPHI.MAD -999.250 VRA.MAD 77.044 -999.250 ROBR.MAD -999.250 DRHO.MAD -999.250 RA.MAD -999.250 VRP.MAD 2.245 ROBR.MAD 25.300 DRHO.MAD 43.200 RA.MAD 4.434 VRP.MAD 2.182 ROBR.MAD 28.000 DRHO.MAD 41.600 RA.MAD 4.287 VRP.MAD -999.250 ROBR.MAD -999.250 DRHO.MAD -999.250 RA.MAD -999.250 VRP.MAD PAGE: 10 -999.250 -999.250 -999.250 -999.250 2.226 0.077 4.352 4.310 2.215 0.105 4.359 4.036 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/11 MAX RE¢ SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED MAD PASSES Depth shifted and clipped curves~ for each pass of each run in separate files. ~lS Tape Verification Listing Schlumberger Alaska Computing Center 11-0AN-1996 13:00 MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH CDR 4874.5 $ STOP DEPTH 4747.0 BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH $ REMARKS: THIS FILE CONTAINS THE MAD ACQUIRED CDR DATA OF THE WASHDOWN PASS. NO DEPTH CORRECTIONS WERE APPLIED, THE DATA HAS BEEN CLIPPED OF INVALID READINGS. $ LIS FORMAT DATA PAGE: 11 TABLE TYPE : CONS TUNI VALU DEFI CN BP EXPLORATION Company Name FN MILNE POINT Field Name WN MPJ-08 APIN 500292249700 FL 2574' FSL & 3343' FEL SECT 28 I'OWN 13N RANG iOE COUN NORTH SLOPE SFAT ALASKA NATI USA LATI 70.45164844N LONG 149.57591777W WITN LUTRIK PDAT MSL EPD FT O. LMF DRILL FLOOR APD FT 65.2 EI<B FT 65.2 EDF FT 65.2 EGL FT 35. TDD FT 6145. TDL FT 6145. BLI FT 6145. TLI FT 2513. DFT LSND Well Name API Serial Number Field Location Section Township Range County State or Province Nation Latitude Longitude Witness Name Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Depth - Logger Bottom Log Interval Top Log Interval Drilling Fluid Type LIS Tape Verification Listing Schlumoerger Alaska Computing Center 11-JAN-1996 13:00 PAGE: 12 TUNI VALU DEFI DFD G/C3 9.800001 ..... ~iiii~-~]~'~it~ -- - RMS OHMM 2.55 Resistivity of Mud Sample MST DEGF 70. Mud Sample Temperature RHFS OHMM 1.17 Resistivity of Mud Filtrate S MFST DEGF 70. Mud Filtrate Sample Temperatu BHT DEGF 145. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth GR Gamma Ray ROPE RATE OF PENETRATION DER DIELECTRIC RESISITIVTY ATR CDR ATTN RESISTIVITY PSR CDR PHSF RESISTIVITY ATVR QRO VERY ENHANCED AMPLITUDE RESISTIVITY PSVR QRO VERY ENHANCED PHASE RESISITIVTY ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JAN-1996 13:00 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM DEPT FT O0 000 O0 0 3 1 1 4 GR MD1 GAPI O0 000 O0 0 3 1 1 4 ROPE MD1 F/HR O0 000 O0 0 3 1 1 4 DER MD1 OHMH O0 000 O0 0 3 1 1 4 ATR MD1 OHMM O0 000 O0 0 3 1 I 4 PSR MD1 OHMM O0 000 O0 0 3 I I 4 ATVR MD1 OHMM O0 000 O0 0 3 1 i 4 PSVR MD1 OHMM O0 000 O0 0 3 I i 4 REPR PROCESS CODE (HEX) 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 13 ** DATA ** DEPT. 4874.500 GR.MD1 -999.250 ROPE.MD1 72.289 DER.MD1 ATR.MD1 -999.250 PSR.MD1 -999.250 ATVR.MD1 -999.250 PSVR.MD1 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED MAD PASSES Depth shifted and clipped curves; for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 LIS ~ape Verification List'ing Schlumberger Alaska Computing Center 11-JAN-1996 13:00 # FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH CDR ADN 5568.0 5552.5 5524.5 5510.0 5514.0 5500.5 5477.5 5462.5 5433.0 5420.0 5395.5 5382.5 5381.5 5371.0 5376.0 5367.0 5367.0 5356.0 5278.5 5264.5 5261.0 5247.5 5212.5 5199.0 5198.5 5186.0 5177.0 5166.5 5142.0 5130.5 5075.5 5066.0 4980.5 4973.0 4964.5 4956.5 4919.5 4902.0 4877.5 4860.0 $ REMARKS: THIS FILE CONTAINS THE MAD ACQUIRED CDR AND ADN DATA OF THE UPLOG PASS. THIS DATA HAS BEEN PLACED ON DEPTH WITH THE MAIN LOG DRILLING PASS. $ LIS FORMAT DATA PAGE: 14 TABLE TYPE : CONS TUNI VALU DEFI CN BP EXPLORATION Company Name FN MILNE POINT Field Name WN MPJ-08 Well Name APIN 500292249700 API Serial Number FL 2574' FSL & 3343' FEL Field Location SECT 28 Section TOWN 13N Township RANG IOE Range LIS Tape Verification Lis~ing Schlumoerger Alaska Computing Center 11-JAN-1996 13:00 PAGE: 15 TUNI VALU DEFI COUN NORTH SLOPE County ALASKA State or Province STAT NATI USA LATI 70.45164844N LONG 149.57591777W WITN LUTRIK PDAT MSL EPD FT O. LMF DRILL FLOOR APD FT 65.2 EKB FT 65.2 EDF FT 65.2 EGL FT 35. TDD FT 6145. TDL FT 6145. BLI FT 6145. TLI FT 2513. DFT LSND DFD G/C3 9.800001 RMS OHMH 2.55 MST DEGF 70. RMFS OHMM 1.17 MFST DEGF 70. BHT DEGF 145. Nation Latitude Longitude Witness Name Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Depth Logger Bottom Log Interval Top Log Interval Drilling Fluid Type Drilling Fluid Density Resistivity of Mud Sample Mud Sample Temperature Resistivity of Mud Filtrate S Mud Filtrate Sample Temperatu Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth GR Gamma Ray ROPE RATE OF PENETRATION DER DIELECTRIC RESISITIVTY ATR CDR ATTN RESISTIVITY PSR CDR PHSF RESISTIVITY ATVR QRO VERY ENHANCED AMPLITUDE RESISTIVITY PSVR QRO VERY ENHANCED PHASE RESISITIVTY RHOB Bulk Density ROBU RHOB UPPER QUAD ROBR RHOB RIGHT QUAD ROBB RHOB LOWER QUAD ROBL RHOB LEFT QUAD DPHI Density Porosity DRHO Delta RHO PEF PhotoElectric Factor CALN NUCLEAR CALIPER NPHI Thermal Neutron Porosity LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JAN-1996 13:00 PAGE: 16 ** DATA FORHAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 4 I 1 4 68 0000000000 GR MD2 GAPI O0 000 O0 0 4 1 i 4 68 0000000000 ROPE MD2 F/HR O0 000 O0 0 4 i 1 4 68 0000000000 DER MD2 OHMM O0 000 O0 0 4 i i 4 68 0000000000 ATR MD2 OHMM O0 000 O0 0 4 i I 4 68 0000000000 PSR MD2 OHHH O0 000 O0 0 4 1 i 4 68 0000000000 ATVR MD2 OHMM O0 000 O0 0 4 1 i 4 68 0000000000 PSVR MD2 OHMM O0 000 O0 0 4 I i 4 68 0000000000 RHOB MD2 G/¢3 O0 000 O0 0 4 I 1 4 68 0000000000 ROBU MD2 G/C3 O0 000 O0 0 4 I i 4 68 0000000000 ROBR MD2 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 ROBB MD2 G/C3 O0 000 O0 0 4 I 1 4 68 0000000000 ROBL MD2 G/C3 O0 000 O0 0 4 i i 4 68 0000000000 DPHI MD2 PU O0 000 O0 0 4 1 1 4 68 0000000000 DRHO MD2 G/C3 O0 000 O0 0 4 1 i 4 68 0000000000 PEF MD2 BN/E O0 000 O0 0 4 i 1 4 68 0000000000 CALN MD2 IN O0 000 O0 0 4 i 1 4 68 0000000000 NPHI MD2 PU O0 000 O0 0 4 i 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-JAN-1996 13:00 PAGE: 17 DEPT. 5630.000 GR.MD2 ATR.MD2 -999.250 PSR.MD2 RHOB.MD2 -999.250 ROBU.MD2 ROBL.MD2 -999.250 DPHI.MD2 CALN.MD2 -999.250 NPHI.MD2 DEPT. 5500.000 GR.MD2 ATR.MD2 4.352 PSR.MD2 RHOB.MD2 2.225 ROBU.MD2 ROBL.MD2 2.234 DPHI.HD2 CALN.MD2 9.175 NPHI.MD2 DEPT. 5000.000 GR.MD2 ATR.MD2 4.359 PSR.MD2 RHOB.MD2 2.201 ROBU.HD2 ROBL.MD2 2.244 DPHI.MD2 CALN.MD2 9.274 NPHI.MD2 DEPT. 4771.500 GR.MD2 ATR.MD2 -999.250 PSR.MD2 RHOB.MD2 -999.250 ROBU.HD2 ROBL.MD2 -999.250 DPHI.MD2 CALN.MD2 -999.250 NPHI.MD2 ** END OF DATA ** -999.250 ROPE.MD2 -999.250 ATVR.MD2 -999.250 ROBR.MD2 -999.250 DRHO.MD2 -999.250 74.076 ROPE.MD2 4.236 ATVR.MD2 2.245 ROBR.MD2 25.300 DRHO.MD2 43.200 73.215 ROPE.MD2 4.064 ATVR.MD2 2.182 ROBR.MD2 28.000 DRHO.MD2 41.600 -999.250 ROPE.MD2 -999.250 ATVR.MD2 -999.250 ROBR.MD2 -999.250 DRHO.MD2 -999.250 -999.250 -999.250 -999.250 -999.250 41.373 4.434 2.226 0.077 118.679 4.287 2.215 0.105 -999.250 -999.250 -999.250 -999.250 DER.MD2 PSVR.MD2 ROBB.MD2 PEF.MD2 DER.MD2 PSVR.MD2 ROBB.MD2 PEF.MD2 DER.MD2 PSVR.MD2 ROBB.MD2 PEF.MD2 DER.MD2 PSVR.MD2 ROBB.MD2 PEF.MD2 -999.250 -999.250 -999.250 -999.250 4.273 4.310 2.245 2.906 4.151 4.036 2.256 3.387 -999.250 -999.250 -999.250 -999.250 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER RAW MWD LIS Tape Verification List'ing Schlumberger Alaska Computing Center 11-JAN-1996 13:00 PAGE: 18 Curves and log header data for each bit run in separate files. BIT RUN NUMBER: i DEPTH INCREMENT: 0.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH CDR 5028.5 $ 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 (FTC: BIT ROTATING SPEEQ (RpM} HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISTIVITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN):. DRILLERS CASING DEPTH (FTC: BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L~/~): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM} AT TEMPERATUQE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF EWR FREQUENCY STOP DEPTH 4820.5 15-AUG-94 LOGOS 20.4 FAST 2.5 MEMORY 6145.0 2513.0 6145.0 84.5 TOOL NUMBER RGS022 8.500 2513.0 LSND 9.80 2.550 70.0 1.170 70.0 20000 LIS Tape Verification List~ing Schlumberger Alaska Computing Center 11-JAN-1996 13:00 REMARKS: ************ RUN 1 ************* ADN RP TO BIT: 102.51 FT DENSITY TO BIT: 106.09 FT NEUTRON TO BIT: 110.43 FT DRILLED INTERVAL: 2513 TO 6145 FT CDR RP TO BIT: 47.89 FT RES TO BIT: 44.72 FT GR TO BIT: 55.14 FT ORIGINAL HOLE FROM 4875 TO 5028 BIT DEPTH. $ LIS FORMAT DATA PAGE: 19 TABLE TYPE : CONS TUNI VALU DEFI CN BP EXPLORATION Company Name FN MILNE POINT Field Name WN MPJ-08 Well Name APIN 500292249700 API Serial Number FL 2574' FSL & 3343' FEL Field Location SECT 28 Section TOWN 13N Township RANG iOE Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation LATI 70.45164844N Latitude LONG 149.57591777W Longitude WITN LUTRIK Witness Name PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF DRILL FLOOR Log Measured From APD FT 65.2 Above Permanent Datum EKB FT 65.2 Elevation of Kelly Bushing EDF FT 65.2 Elevation of Derrick Floor EGL FT 35. Elevation of Ground Level TDD FT 6145. Total Depth - Driller TDL FT 6145. Total Depth - Logger BLI FT 6145. Bottom Log Interval TLI FT 2513. Top Log Interval DFT LSND Drilling Fluid Type DFD G/C3 9.800001 Drilling Fluid Density RMS OHMM 2.55 Resistivity of Mud Sample MST DEGF 70. Mud Sample Temperature RMFS OHMM 1.17 Resistivity of Mud Filtrate S MFST DEGF 70. Mud Filtrate Sample Temperatu BHT DEGF 145. Bottom Hole Temperature LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JAN-1996 13:00 TABLE TYPE : CURV DEFI DEPT Depth GR Gamma Ray ROPE RATE OF PENETRATION DER DIELECTRIC RESISITIVTY ATR CDR ATTN RESISTIVITY PSR CDR PHSF RESISTIVITY ATVR QRO VERY ENHANCED AMPLITUDE RESISTIVITY PSVR QRO VERY ENHANCED PHASE RESISITIVTY PAGE: 2O ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 i ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 5 i 1 4 68 0000000000 GR CDR GAPI O0 000 O0 0 5 i 1 4 68 0000000000 ROPE CDR F/HR O0 000 O0 0 5 1 1 4 68 0000000000 DER CDR OHMM O0 000 O0 0 5 1 1 4 68 0000000000 ATR CDR OHMM O0 000 O0 0 5 1 I 4 68 0000000000 PSR CDR OHMM O0 000 O0 0 5 1 i 4 68 0000000000 ATVR CDR OHMM O0 000 O0 0 5 i I 4 68 0000000000 PSVR CDR OHMM O0 000 O0 0 5 i 1 4 68 0000000000 LIS ~ape Verification Listfing Schlumberger Alaska Computing Center 11-JAN-1996 13:00 PAGE: 21 ** DATA DEPT. ATR.CDR DEPT. ATR.CDR DEPT. ATR.CDR 5028.500 GR.CDR -999.250 ROPE.CDR 47.271 DER.CDR -999.250 PSR.CDR -999.250 ATVR.CDR -999.250 PSVR.CDR 5000.000 GR.CDR -999.250 ROPE.CDR 166.916 DER.CDR -999.250 PSR.CDR -999.250 ATVR.CDR -999.250 PSVR.CDR 4820.500 GR.CDR 78.732 ROPE.CDR -999.250 DER.CDR -999.250 PSR.CDR -999.250 ATVR.CDR -999.250 PSVR.CDR -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAHE : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW MWD Curves and log header data for each BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH CDR 6144.5 $ LOG HEADER DATA bit run in separate files. STOP DEPTH 2458.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-JAN-1996 13:00 PAGE: 22 DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): ID DRILLER (FT): TOP LOG INTERVAL (FTC: . BOTTOM LOG INTERVAL (FTC: BIT ROTATING SPEED (RPM) HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISTIVITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (~3): . RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF EWR FREQUENCY REMARKS: ************ RUN I ************* ADN RP TO BIT: 102.51 FT DENSITY TO BIT: 106.09 FT NEUTRON TO BIT: 110.43 FT DRILLED INTERVAL: 2513 TO 6145 FT CDR RP TO BIT: 47.89 FT RES TO BIT: 44.72 FT GR TO BIT: 55.14 FT MAIN LOG CONTAINING FIRST DRILLED DATA FROM CASING TO TD, INCLUDING SIDETRACK FROM 4875 TO TD. 15-AUG-94 LOGOS 20.4 FAST 2.5 MEMORY 6145.0 2513.0 6145.0 84.5 TOOL NUMBER RGS022 8. 500 2513.0 LSND 9.80 2.550 70.0 1.170 70.0 20000 LIS ?ape Verification List'ing Schlumberger Alaska Computing Center $ # LIS FORMAT DATA 11-JAN-1996 13:00 PAGE: 23 TABLE TYPE : CONS TUNI VALU DEFI CN BP EXPLORATION Company Name MILNE POINT Field Name FN WN MPJ-08 Well Name APIN 500292249700 API Serial Number FL 2574' FSL & 3343' FEL Field Location SECT 28 Section TOWN 13N Township RANG IOE Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation LATI 70.45164844N Latitude LONG 149.57591777W Longitude WITN LUTRIK Witness Name PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF DRILL FLOOR Log Measured From APD FT 65.2 Above Permanent Datum EKB FT 65.2 Elevation of Kelly Bushing EDF FT 65.2 Elevation of Derrick Floor EGL FT 35. Elevation of Ground Level TDD FT 6145. Total Depth - Driller TDL FT 6145. Total Depth - Logger BLI FT 6145. Bottom Log Interval TLI FT 2513. Top Log Interval DFT LSND Drilling Fluid Type DFD G/C3 9.800001 Drilling Fluid Density RMS OHMM 2.55 Resistivity of Mud Sample MST DEGF 70. Mud Sample Temperature RMFS OHMM 1.17 Resistivity of Mud Filtrate S MFS1 DEGF 70. Mud Filtrate Sample Temperatu BHT DEGF 145. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth GR Gamma Ray ROPE RATE OF PENETRATION TAB TIME AFTER BIT ATR CDR ATTN RESISTIVITY PSR CDR PHSF RESISTIVITY DER DIELECTRIC RESISITIVTY LIS Tape Verification Listlng Schlumberger Alaska Computing Center 11-JAN-1996 13:00 DEFI ATVR QRO VERY ENHANCED AMPLITUDE RESISTIVITY PSVR QRO VERY ENHANCED PHASE RESISITIVTY PAGE: 24 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALU~- 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 6 1 1 4 68 0000000000 GR CDR GAPI O0 000 O0 0 6 1 1 4 68 0000000000 ROPE CDR F/HR O0 000 O0 0 6 1 i 4 68 0000000000 TAB CDR O0 000 O0 0 6 1 I 4 68 0000000000 ATR CDR OHMM O0 000 O0 0 6 I i 4 68 0000000000 PSR CDR OHMM O0 000 O0 0 6 I i 4 68 0000000000 DER CDR OHMM O0 000 O0 0 6 i i 4 68 0000000000 ATVR CDR OHMM O0 000 O0 0 6 I 1 4 68 0000000000 PSVR CDR OHMM O0 000 O0 0 6 1 I 4 68 0000000000 ** DATA ** LIS rape Verification Listing Schlumberger Alaska Computing Center DEPT. 6144.500 GR.CDR ATR.CDR -999.250 PSR.CDR PSVR.CDR -999.250 DEPT. 6000.000 GR.CDR ATR.CDR 4.778 PSR.CDR PSVR.CDR 4.501 DEPT. 5500.000 GR.CDR ATR.¢DR 4.398 PSR.CDR PSVR.CDR 4.368 DEPT. 5000.000 GR.CDR ATR.CDR 4.074 PSR.CDR PSVR.CDR 4.415 DEPT. 4500.000 GR.CDR ATR.CDR 3.299 PSR.CDR PSVR.CDR 3.013 DEPT. 4000.000 GR.CDR ATR.CDR 6.937 PSR.CDR PSVR.CDR 6.697 DEPT. 3500.000 GR.CDR ATR.CDR 6.627 PSR.CDR PSVR.CDR 5.574 DEPT. 3000.000 GR.CDR ATR.CDR 6.410 PSR.CDR PSVR.CDR 5.472 DEPT. 2500.000 GR.CDR ATR.CDR -999.250 PSR.CDR PSVR.CDR 1000.000 DEPT. 2458.000 GR.CDR ATR.CDR -999.250 PSR.CDR PSVR.CDR -999.250 ** END OF DATA ** 11-0AN-1996 13:00 -999.250 ROPE.CDR 226.723 -999.250 DER.CDR -999.250 106.554 ROPE.CDR 4.600 DER.CDR 72.007 ROPE.CDR 4.628 DER.CDR 68.631 ROPE.CDR 4.238 DER.CDR 42.915 ROPE.CDR 2.952 DER.CDR 71.119 ROPE.CDR 6.519 DER.CDR 95.607 ROPE.CDR 5.673 DER.CDR 89.938 ROPE.CDR 5.531 DER.CDR 26.805 ROPE.CDR -999.250 DER.CDR 46.353 ROPE.CDR -999.250 DER.CDR 233.995 4.654 282.456 4.549 102.857 4.182 617.379 3.057 466.020 6.640 212.739 5.944 243.128 5.785 -999.250 -999.250 -999.250 -999.250 TAB.CDR ATVR.CDR TAB.CDR ATVR.CDR TAB.CDR ATVR.CDR TAB.CDR ATVR.CDR TAB.CDR ATVR.CDR TAB.CDR ATVR.CDR TAB.CDR ATVR.CDR TAB.CDR ATVR.CDR TAB.CDR ATVR.CDR TAB.CDR ATVR.CDR PAGE: 25 -999.250 -999.250 0.436 4.673 0.147 4.421 0.343 4.464 0.337 3.245 0.326 6.679 0.317 5.742 0.410 5.986 -999.250 1000.000 -999.250 -999.250 **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification List}ng Schlumberger Alaska Computing Center 11-JAN-1996 13:00 PAGE: 26 **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: i MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH CDR 4874.5 $ 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 (R~M) HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISTIVITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: STOP DEPTH 4747.0 15-AUG-94 LOGOS 20.4 FAST 2.5 MEMORY 6145.0 2513.0 6145.0 84.5 TOOL NUMBER RGS022 8. 500 2513.0 LSND 9.80 _kS Tape Verification Listing Schlumberger Alaska Computing Center 11-JAN-1996 13:00 MUD CHLORIDES (PPM): FLUID LOSS (C. 3): . . RESISTIVITY (OHMM) AT TEMPERATUR. E .(DEGF}: MUD AT MEASURED TEMPERATURE MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF /IN/: EWR FREQUENCY HZ REMARKS: ************ RUN i ************* ADN RP TO BIT: 102.51 FT DENSITY TO BIT: 106.09 FT NEUTRON TO BIT: 110.43 FT DRILLED INTERVAL: 2513 TO 6145 FT CDR RP TO BIT: 47.89 FT RES TO BIT: 44.72 FT GR TO BIT: 55.14 FT WASHDOWN FROM 4800' TO 4875' BIT DEPTH. $ LIS FORMAT DATA 2.550 70.0 1.170 70.0 0.000 0.0 20000 PAGE: 27 TABLE TYPE : CONS TUNI VALU DEFI CN BP EXPLORATION Company Name FN MILNE POINT Field Name WN MPJ-08 APIN 500292249700 FL 2574' FSL & 3343' FEL SECT 28 TOWN 13N RANG iOE COUN NORTH SLOPE STAT ALASKA NATI USA LATI 70.45164844N LONG 149.57591777W WITN LUTRIK PDAT MSL EPD FT O. LMF DRILL FLOOR APD FT 65.2 EKB FT 65.2 EDF FT 65.2 Well Name API Serial Number Field Location Section Township Range County State or Province Nation Latitude Longitude Witness Name Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor LIS Tape Verification Listing 11-jAN-1996 13:00 PAGE: 28 Schlumberger Alaska Computing Center TUNI VALU DEFI 35. Elevation of Ground Level EGL FT TDD FT 6145. TDL FT 6145. BL! FT 6145. TLI FT 2513. DFT LSND DFD G/C3 9.800001 RMS OHMM 2.55 MST DEGF 70. RMFS OHMH 1.17 HFST DEGF 70. BHT DEGF 145. Total Depth - Driller Total Depth Logger Bottom Log Interval Top Log Interval Drilling Fluid Type Drilling Fluid Density Resistivity of Mud Sample Mud Sample Temperature Resistivity of Mud Filtrate S Mud Filtrate Sample Temperatu Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth GR Gamma Ray ROPE RATE OF PENETRATION DER DIELECTRIC RESISITIVTY ATR CDR ATTN RESISTIVITY PSR CDR PHSF RESISTIVITY ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE --i .......... .......... .... 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I ~S Tape Verification Listing · Schlumberger Alaska Computing Center 11-JAN-1996 13:00 PAGE: ** SET TYPE - CHAN ** ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 7 1 1 4 68 0000000000 GR CDR GAPI O0 000 O0 0 7 1 1 4 68 0000000000 ROPE CDR F/HR O0 000 O0 0 7 1 I 4 68 0000000000 DER CDR OHMM O0 000 O0 0 7 1 1 4 68 0000000000 ATR CDR OHMM O0 000 O0 0 7 1 I 4 68 0000000000 PSR 006 OHMM O0 000 O0 0 7 1 1 4 68 0000000000 29 ** DATA DEPT. A'FR.CDR DEPT. ATR.CDR 4874.500 GR.CDR -999.250 ROPE.CDR 72.289 DER.CDR -999.250 PSR.O06 -999.250 4747.000 GR.CDR 77.044 ROPE.CDR -999.250 DER.CDR -999.250 PSR.O06 -999.250 -999.250 -999.250 END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 8 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 2 LIS Tape Verification Listing ' Schlumberger Alaska Computing Center 11-JAN-1996 13:00 PAGE: 30 DEPTH INCREMENT: 0.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH CDR 5645.5 ADN 5645.5 $ 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 (R~M) HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 4844.0 4789.0 TOOL STRING (TOP TO BOTTOM) vE oO coo ............. ADN DENS/NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): . DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: HUD DENSITY (LB/t): HUD VISCOSITY (S): HUD PH: HUD CHLORIDES (PPM): FLUID LOSS (~3): . RESISTIVITY (OHMH) AT TEHPERATURE (DEGF): HUD AT MEASURED TEHPERATURE (MT): HUD AT MAX C]RCULATIONG TEHPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (HT): NEUTRON TOOL HATRIX: HATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF /INI: EWR FREQUENCY HZ 15-AUG-94 LOGOS 20.4 FAST 2.5 MEMORY 6145.0 2513.0 6145.0 30 84.5 TOOL NUMBER RGS022 ADNO01 8.500 2513.0 LSND 9.80 2.550 1.170 0.000 SANDSTONE 2.65 70.0 70.0 0.0 20000 ~S Tape Verification List{ng - Schlumberger Alaska Computing Center 11-JAN-1996 13:00 REMARKS: ************ RUN I ************* ADN RP TO BIT: 102.51FT DENSITY TO BIT: 106.09 FT NEUTRON TO BIT: 110.43 FT DRILLED INTERVAL: 2513 TO 6145 FT CDR RP TO BIT: 47.89 FT RES TO BIT: 44.72 FT GR TO BIT: 55.14 FT UPLOGGED CDR AND ADN DATA $ LIS FORMAT DATA PAGE: 31 TABLE TYPE : CONS TUNI VALU DEFI CN BP EXPLORATION Company Name FN MILNE POINT Field Name WN MPJ-08 Well Name APIN 500292249700 API Serial Number FL 2574' FSL & 3343' FEL Field Location SECT 28 Section TOWN 13N Township RANG IOE Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation LATI 70.45164844N Latitude LONG 149.57591777W Longitude WITN LUTRIK Witness Name PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF DRILL FLOOR Log Measured From APD FT 65.2 Above Permanent Datum EKB FT 65.2 Elevation of Kelly Bushing EDF FT 65.2 Elevation of Derrick Floor EGL FT 35. Elevation of Ground Level TDD FT 6145. Total Depth - Driller TDL FT 6145. Total Depth - Logger BLI FT 6145. Bottom Log Interval TLI FT 2513. Top Log Interval DFT LSND Drilling Fluid Type DFD G/C3 9.800001 Drilling Fluid Density RMS OHMM 2.55 Resistivity of Mud Sample HST DEGF 70. Mud Sample Temperature RMFS OHMM 1.17 Resistivity of Mud Filtrate S MFST DEGF 70. Mud Filtrate Sample Temperatu BHT DEGF 145. Bottom Hole Temperature LiS Tape Verification Listing ' Schlumberger Alaska Computing Center 11-JAN-1996 13:00 TABLE I'YPE : CURV DEFI DEPT Depth GR Gamma Ray ROPE RATE OF PENETRATION DER DIELECTRIC RESISITIVTY ATR CDR ATTN RESISTIVITY PSR CDR PHSF RESISTIVITY ATVR QRO VERY ENHANCED AMPLITUDE RESISTIVITY PSVR QRO VERY ENHANCED PHASE RESISITIVTY DCAL Differential Caliper PEF PhotoElectric Factor TNPH Thermal Neutron Porosity DPHI Density Porosity DRHO Delta RHO RHOB Bulk Density ROBU RHOB UPPER QUAD ROBR RHOB RIGHT QUAD ROBB RHOB LOWER QUAD ROBL RHOB LEFT QUAD PAGE: 32 DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listfng ~ Schlumberger Alaska Computing Center 11-JAN-1996 13:00 PAGE: ** SET TYPE - CHAN ** ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 8 1 1 4 68---6666666666- GR CDR GAPI O0 000 O0 0 8 1 1 4 68 0000000000 ROPE CDR F/HR O0 000 O0 0 8 1 1 4 68 0000000000 DER CDR OHMM O0 000 O0 0 8 1 i 4 68 0000000000 ATR CDR OHMM O0 000 O0 0 8 1 i 4 68 0000000000 PSR CDR OHMM O0 000 O0 0 8 1 I 4 68 0000000000 ATVR CDR OHMM O0 000 O0 0 8 i i 4 68 0000000000 PSVR CDR OHMM O0 000 O0 0 8 1 1 4 68 0000000000 DCAL ADN IN O0 000 O0 0 8 1 1 4 68 0000000000 PEF ADN BN/E O0 000 O0 0 8 I I 4 68 0000000000 TNPH ADN PU O0 000 O0 0 8 1 1 4 68 0000000000 DPHI ADN PU O0 000 O0 0 8 1 i 4 68 0000000000 DRHO ADN G/C3 O0 000 O0 0 8 i 1 4 68 0000000000 RHOB ADN G/C3 O0 000 O0 0 8 1 I 4 68 0000000000 ROBU ADN G/C3 O0 000 O0 0 8 I 1 4 68 0000000000 ROBR ADN G/C3 O0 000 O0 0 8 1 1 4 68 0000000000 ROBB ADN G/C3 O0 000 O0 0 8 1 1 4 68 0000000000 ROBL ADN G/C3 O0 000 O0 0 8 I i 4 68 0000000000 33 ** DATA ** DEPT. 5645.500 GR.CDR -999.250 ROPE.CDR -999.250 DER.CDR ATR.CDR -999.250 PSR.CDR -999.250 ATVR.CDR -999.250 PSVR.CDR DCAL.ADN -999.250 PEF.ADN -999.250 TNPH.ADN -999.250 DPHI.ADN DRHO.ADN -999.250 RHOB.ADN -999.250 ROBU.ADN -999.250 ROBR.ADN ROBB.ADN -999.250 ROBL.ADN -999.250 DEPT. 5500.000 GR.CDR 70.263 ROPE.CDR 33.835 DER.CDR ATR.CDR 4.471 PSR.¢DR 4.761 ATVR.CDR 4.908 PSVR.CDR DCAL.ADN 0.693 PEF.ADN 3.279 TNPH.ADN 43.500 DPHI.ADN DRHO.ADN 0.107 RHOB.ADN 2.187 ROBU.ADN 2.171 ROBR.ADN ROBB.ADN 2.250 ROBL.ADN 2.200 DEPT. 5000.000 GR.CDR 74.866 ROPE.CDR 106.505 DER.CDR ATR.CDR 4.664 PSR.CDR 4.248 ATVR.CDR 4.658 PSVR.CDR DCAL.ADN 0.969 PEF.ADN 3.538 TNPH.ADN 46.300 DPHI.ADN DRHO.ADN 0.103 RHOB.ADN 2.194 ROBU.ADN 2.145 ROBR.ADN ROBB.ADN 2.299 ROBL.ADN 2.257 DEPT. 4789.000 GR.CDR -999.250 ROPE.CDR -999.250 DER.CDR ATR.CDR -999.250 PSR.CDR -999.250 ATVR.CDR -999.250 PSVR.CDR DCAL.ADN -999.250 PEF.ADN -999.250 TNPH.ADN -999.250 DPHI.ADN DRHO.ADN -999.250 RHOB.ADN -999.250 ROBU.ADN -999.250 ROBR.ADN ROBB.ADN -999.250 ROBL.ADN -999.250 -999.250 -999.250 -999.250 -999.250 4.661 4.769 29.800 2.149 4.365 4.333 26.700 2.189 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing ~ Schlumberger Alaska Computing Center 11-JAN-1996 13:00 PAGE: 34 **** FILE TRAILER FILE NAME : EDIT .008 SERVICE : FLIC VERSION : 001¢01 DATE : 96/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/01/11 ORIGIN : FLIC TAPE NAME : 94289 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION , MILNE POINT, MPJ-08, 50-029-22497-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/01/11 ORIGIN : FLIC REEL NAME : 94289 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION , MILNE POINT, MPJ-08, 50-029-22497-00 SEQUENTIAL REEL NO. SEQUENTIAL FILE NO. WELL # 001:MPJ-08 DEPTHS : 5800.000 TO OUTPUT TO : mpj-08.TIF **** LIS WRITE **** 1 1 9000.000 FT CURVES OUTPUT FROM PETCOM DATABASE TO LIS IMAGE : PETCOM OUTPUT CURVE CURVE UNITS DEPTH DEPT FT TVD TVD FT SGRC GR AAPI SEXP RPX OHMM SESP RPS OHMM SEMP RPM OHMM SEDP RPD OHMM SROP ROP FT/H SFXE FET HOUR MICROFILMED u e_ · SEQUENTIAL REEL NO. SEQUENTIAL FILE NO. WELL # 001: MPJ-08 DEPTHS : 5800.000 TO OUTPUT TO : RAWDATA.TIF **** LIS WRITE **** 1 1 9000.000 FT -. CURVES OUTPUT FROM PETCOM DATABASE TO LIS IMAGE : PETCOM OUTPUT CURVE CURVE UNITS DEPTH DEPT FT ROP100 ROP FT/H GR100 GR AAPI RPXl00 RPX OHMM RPSl00 RPS OHMM RPM100 RPM OHMM RPD100 RPD OHMM FET100 FET HR ROP200 ROP FT/H GR200 GR AAPI RPX200 RPX OHMM RPS200 RPS OHMM RPM200 RPM OHMM RPD200 RPD OHMM FET200 FET HR ROP300 ROP FT/H GR300 GR AAPI RPX300 RPX OHMM RPS300 RPS OHMM RPM300 RPM OHMM RPD300 RPD OHMM FET300 FET HR 3 3 4~ 65,20 6 5.2 0 -999,250 -999,250 2 !~ -- F', C T ..- 1. 9 ~ 4 ';?: 1: ( 759°9 1 4r~57.0 2 ,'~ 7 5 9. C, P~EI P AGE: -99g.25o -999.250 -999.~50 D~HC.$~AC (;~.~AD 999,250 999,250 999.250 -999.250 -999.250 -999.250 -999.250 77.044 fi!es. (ir,' '!" ) -' O i',. G R :.; ,C: (:; ? 2 2 · 5 5 0 ~, 6 5 70.0 PAGE: 0.5 FT -999.250 PAGE: -999.250 Curves ~:~nd ioq ~',e,:~rter data ~or each bit r;in ~n separate r,,.,~ if, t4 i'.'.! R 25~7 .u fi!es. PAGE: 10 n- ~2 8 ,sno I . t70 70.0 70.0 PAGg: -999.250 -999.250 12 20,4 6:I ,~;5.n 2517.C' 2;;-OCT-190% '~1:,:9 1,3 # q . L*.' {"-' ?. 55J '70.0 "'hlLl¢~:ber::lO~i /,.]asEa ("o,-,"~",~tir, c" 14 SIZE REPR POCDS5 ; ........ . ............. 4 68 O000000OO0 4 68 o000000000 D F: i:~' m. '999,250 '999.250 15 C~]rvns <~ io :.(~% er ,";,~r~ta ior each ~it run i~ seperat, e 2517 .C, ~:5i3,0 files. PAGE: 16 2 · 55{~ 7 0.0 70.0 PAgE~ mm~ ~ ~! , ~m~mmmmm~mmmmmmmmmmmmImmmmmmmm 17 -999,250 -999.250 -999.250 ~999.250 999,250 -999,250 ZO-r~C'T--19a4 :/21:4o PAGE: 18 245R.n ! 5 - a U ~5 - 9 a PaST 2.5 251,7.0 2 5 1 3. n files. PAGe: 19 70.0 70.0 PAGE: 2O -999.250 -999.250 21 ;:?L:':L ~-'"Pi"i:~, ':F~J-'::)':, 50-929-22497-09