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Home My WebLink About197-173XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN n Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: //~ Poor Quality Original'- Pages: Other ~ Pages: DIGITAL DATA n Diskettes, No. Other, No/Type 'OVERSIZED .Logs of various kinds Other COMMENTS: Scanned by:~Mitdred-Daretha Nathan Lowell Complete [] TO RE-SCAN Notes: Re-Scanned by: Beve~y Mildred Daretha Nalhan Lowell Date: /si 11 /27/07 il~~l~~~~l-fs~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~>~~ NOV 2 9 2007 NO. 4517 Company: State of Alaska Alaska Oil & Gas Cons Comm r ~ ~~ Attn: Christine Mahnken 333 West 7th Ave, Suite 100 { ~ Anchorage, AK 99501 FV Field: P.Bay, Milne Pt., Lisburne weu JOn 7F Lo Descri tion Date BL Color CD MPL-33 11661179 MEM INJ PROFILE REVISED) 11/13/07 1 L1-15A 11661181 MEM PROD PROFILE ~ 11121/07 1 MPH-08 11686799 USIT ~ _ 11118/07 1 02-096 11890327 USIT 11/21/07 1 LGI-04 11686752 RST f~-~t~ )S'~~ j~ 05/27/07 1 1 • • e PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 °~> 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~ ~~`)~~° ~;~~ 17j"~~1 .~ ~tfi _ n Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: TI-W. MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY O3, 2001 M P L A T E IA L- U N D W E R TH IS M ARK ER C:LORJ'~[LM.DOC --Well 'Compliance Report File on Left side of folder 197-173-0 MILNE POINT UNIT SB H-98 MD 09275 . TVD 043_92 Completion Date: L~/98 50- 029-22808-00 Completed Status: 1-OIL BP EXPLORATION Current: P&A Name Interval Sent Received T/C/I) D 8753 ~;ERRY MPT/GR/EWR4/CNP/SLD OH 10/28/98 10/28/98 L DGR/CNP-MD ~ 5951-9275 OH 10/28/98 10/28/98 L DGR/CNP-TVD t2~ 3048-4392 OH 10/28/98 10/28/98 L DGR/EWR4-MD j 5951-9275 OH 10/28/98 10/28/98 L DGR/EWR4-TVD .~ 3048-4392 OH 10/28/98 10/28/98 L GR/CCLPERF .'~NNAL 8444-9139 CH 5 6/12/98 6/15/98 Daily Well Ops ~/~7 _~_ Are Dry Ditch Samples Required? yes .~..~d Received?-.y. es--m~'~ Was the well cored? yes .~_~. Analysis Description Re~ ...... San~'p~e~i"~ Comments: Tuesday, May 30, 2000 Page 1 of 1 PLL-GG!-'~?G & LOC~.TION CL~..~_~C~ REPORT Sta~a cf A.!aska ..u~um 0zz ~ ~ c~sm~z~ ~~z~ ~_e well file, an~' =~-~m~= on .~lu.~ing, well head Well head Code STATE OF ALASKA ..~..- ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for CTD 1. Status of Well Classification of Service Well r-I Oil [--] Gas [--] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 197-173 399-201 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22808-00 ........ ~~. 9. Unit or Lease Name 4. Location of well at surface ~ .~:~. : .}.~,r ~__~ ~ ~ .: ..:: 2767' NSL, 4061' WEb, SEC. 34, T13N, R10E, UM - i ~~ Milne Point Unit ~ ~ ~ 10. Well Number At top of productive interval ~' 722'SNL, 1909'EWL, SEC. 1,T12N, R10E, UM i:~.¢.-F!~2F ~'~t MPH-08 At total depth ~ ~~..~ 11. Field and Pool 828' SNL, 2117' EWL, SEC. 1, T12N, R10E, UM ,., i ............. ~~ Milne Point Unit/Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 64.90'I ADb 380109 12. Date Spudded9/23/97 l13' Date T'D' Reached I 14' Date C°mp" Susp" °r Abandl15' Water depth' if Offsh°re I 16' N°' Of cOmpletiOns09/28/97 12/07199 N/A MSL, Zero 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Survey ~20. Depth where SSSV set121. Thickness of Permafrost 9275 4392 FTI 9167 4314 FTI [~ Yes [] No! N/A MD I 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD - 23. CASlNG~ LINER AND CEMENTING RECORD CASING S E'f-FING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 110' 24" 250 sx Arcticset I (Approx.) 7" 26# L-80 31' 9253' 8-1/2" 2047 sx PF 'E', 263 sx 'G', 191 sx PF 'C' 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 MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8608' Set Cement Retainer 8608' P&A with 23 Bbls Class 'G' 8608' Set Whipstock 27. 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-BBb GAS-MCF WATER-BBb CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATE OIL-BBb GAS-MCF WATER-BBb OIL GRAViTY-APl (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 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. TSBD 8937' 4148' TSBC 8973' 4174' TSBB 9010' 4200' 31. List of Attachments Summary of Daily Drilling Reports 32. I hereby certify that the,~/~s trite the best of my knowledgeSigned ' Terrie Hubble _ ,,, Title Technical Assistant Iil Date MPH-08 197-173 399-201 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'. RECEIVED Form 10-407 Rev. 07-01-80 Facility Date/Time 04 Dec 99 05 Dec 99 06 Dec 99 Progress Report M Pt H Pad Well MPH-08A Page 1 Rig Nabors 4ES Date 08 December 99 06:00-15:00 06:00-15:00 15:00 15:00-19:00 15:00-19:00 19:00 19:00-21:00 19:00-21:00 21:00 21:00-01:00 21:00-01:00 01:00 01:00-01:30 01:00-01:30 01:30 01:30-02:00 01:30-02:00 02:00 02:00-04:00 02:00-04:00 04:00 04:00-06:00 04:00-06:00 06:00 06:00-09:00 06:00-07:00 07:00 07:00-09:00 09:00 09:00-00:00 09:00-18:30 18:30 18:30-21:30 21:30 21:30-00:00 00:00 00:00-01:00 00:00-01:00 01:00 01:00-06:00 01:00-06:00 Duration 9 hr 9 hr 4 hr 4 hr 2hr 2hr 4hr 4hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 2 hr 2 hr 2 hr 2 hr 3 hr 1 hr 2hr 15hr 9-1/2 hr 3 hr 2-1/2 hr 1 hr 1 hr 5 hr 5 hr Activity Move rig Rig moved 100.00 % At well location - Slot Fluid system Fill pits with Seawater Take on seah20 & Rig lines to tiger tank & tree. Completed operations Wellhead work Removed Hanger plug Remove BPV. TBG psi. = 1100 psi. Annulus =1100 & test lines to 3000 psi. Equipment work completed Well control Circulated closed in well at 8627.0 ft displace well bore fluids with seah20 Hole displaced with Seawater - 150.00 % dis?Tlaced Wellhead work Installed Hanger plug set & test twc. to 3500 psi. Equipment work completed RECEIVED Wellhead work Removed Xmas tree Equipment work completed 9'~ D00 Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment dAtll~h0l~ Tested BOP stack test waived by John Spaulding with AOGC. Pressure test completed successfully - 3500.000 psi Wellhead work Removed Hanger plug Equipment work completed Removed Tubing hanger Equipment work completed Pull Single completion, 2-7/8in O.D. Pulled Tubing in stands to 1200.0 ft Completion string handling equipment failed - Change operation Serviced Completion string handling equipment Change out Nabors spooler over to Centrilift. Equipment work completed Pulled Tubing in stands to 0.0 ft Cont. Pooh & Lay dn edp equipment. Completed operations Well control Worked on BOP - Lubricator Remove Flow Nipple & ru Shooting Flg. Completed operations Electric wireline work Conducted electric cable operations RigSchlumberger & rih #1 with 5.93" GR/JB to 6330' & was unable to make forward progress Pooh & check for thrash. Rec. small piece of rubber. Run #2 with same was at 7000' at 0530 am & still making LUI WCl. lU [JIU~IC~ . Facility M Pt H Pad Progress Report Well MPH-08A Page 2 Rig Nabors 4ES Date 08 December 99 Date/Time Duration Activity 06:00 06:00-07:00 06:00-07:00 07:00 07:00-08:00 07:00-08:00 08:00 08:00-16:45 08:00-11:00 11:00 11:00-12:30 12:30 12:30-13:30 13:30 13:30-16:30 16:30 16:30-16:45 16:45 16:45-17:00 16:45-17:00 17:00 17:00-23:30 17:00-19:30 19:30 19:30-23:30 23:30 23:30-00:00 23:30-00:00 07 Dec 99 00:00 00:00-06:00 00:00-03:00 03:00 03:00-06:00 06:00 1 hr 1 hr 1 hr 1 hr 8-3/4 hr 3 hr 1-1/2 hr 1 hr 3 hr 1/4 hr 1/4hr 1/4 hr 6-1/2 hr 2-1/2 hr 4 hr 1/2 hr 1/2 hr 6 hr 3 hr 3 hr Began precautionary measures Electric wireline work (cont...) Conducted electric cable operations cont. to rih with 5.93" gr/jb to 6830' and stopped pooh & no recovery & rig dn same. Observed 2.00 klb resistance Well control Worked on BOP - Lubricator Equipment work completed 2-7/8in. Surge string workstring run Ran Tubing in stands to 8820.0 ft Rih with 6" O>D. reverse circ. basket. On bottom Reverse circulated at 8820.0 ft Reverse circ. @ 5-bpm 750 psi. Loss rate -_---33 bph. Hole displaced with Seawater - 200.00 % displaced Serviced Block line Line slipped and cut Pulled Tubing in stands to 0.0 ft Completed operations Tested Hole opener - Via annulus MU 6.3/16" swede gauge & attempt to dh through hanger & was unable, looks like it is a 29# hanger Function test completed satisfactorily Well control Worked on BOP - Lubricator Nipple down perf. fig. & nu flow nipple. Equipment work completed Electric wireline work Conducted electric cable operations rih wit h5.75" GR/JB to 6890' and was unable to make forward progress. Completed run with Junk basket/gauge ring from 0.0 ft to 6890.0 ft Conducted electric cable operations rih with HOWCO Cement retainer & log into position & set 3' below collar @ 8603' puts Retainer top at 8606' Completed run with Bridge plug from 0.0 ft to 8606.0 ft Well control Worked on BOP - Lubricator Nipple dn shooting fig & nu flow nipple. Completed operations 2-7/8in. Cement stinger workstring run Ran Tubing in stands to 8606.0 ft rih wit howco stinger. & engage in cmt. retainer & establish injection rate 3-bpm 1200 psi. On bottom Batch mixed slurry - 23.000 bbl Rig dowell & mix 23-bbl. premium "G" & put in place below retainer with 49.9 bbl. Sea h20 had a 400 good.psi' increase in psi. as cement hit perfs, all w~snt Completed operations Facility M Pt H Pad Progress RePort Well MPH-08A Page Rig Nabors 4ES Date 3 08 December 99 Date/Time 06:00-15:30 06:00-07:00 07:00 07:00-13:00 13:00 13:00-14:00 14:00 14:00-15:30 15:30 15:30-18:00 15:30-18:00 18:00 18:00-19:30 18:00-19:30 19:30 19:30-21:30 19:30-21:30 21:30 21:30-06:00 21:30-22:00 22:00 Duration 9-1/2 hr 1 hr 6 hr 1 hr 1-1/2 hr 2-1/2 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr 2 hr 2 hr 8-1/2 hr 1/2 hr Activity 2-7/8in. Cement stinger workstring run (cont...) Reverse circulated at 8606.0 ft reverse circ. 200 bbl. sea h20 @ 6-bpm 1700 psi. Hole displaced with Seawater - 200.00 % displaced Laid down 8606.0 ft of Tubing 275 joints laid out Circulated at 2150.0 ft Freeze protect well with diesel Hole displaced with Diesel - 100.00 % displaced Laid down 2215.0 ft of Tubing Lay dn tbg & MU 6-1/16" string mill & drift through hanger. (OK) Completed operations Wellhead work Installed Hanger plug fill hole with diesel & set twe & test sam~- Equipment work completed Nipple down BOP stack Rigged down BOP stack Equipment work completed Wellhead work Installed Xmas tree Equipment work completed · Wellhead work Installed Hanger plug Pull TWC & Install BPV. Equipment work completed RECEIVED 23 2000 Progress Report Facility M Pt H Pad Well MPH-08A Page l Rig Nordic3 Date 24 January 00 Date]Time 29 Dec 99 04:01-06:00 04:01-06:00 04:01-06:00 06:00-17:30 06:00-09:00 09:00 09:00-12:00 12:00 12:00-13:00 13:00 13:00-17:30 17:30 17:30-18:30 17:30-18:30 18:30 '- 18:30-19:30 18:30-19:30 19:30 19:30-22:30 19:30-22:30 22:30 22:30-23:00 22:30-23:00 23:00 23:00-06:00 23:00-06:00 23:00-06:00 Duration 1-3/4 hr 1-3/4 hr 1-3/4 hr 11-1/2 hr 3 hr 3 hr 1 hr 4-1/2 hr 1 hr 'lhr 1 hr 1 hr 3 hr 3 hr 1/2 hr 1/2 hr 7 hr 7 hr 7 hr Activity Move rig Rig moved 50.00 % Finish moving rig to MP H-Pad. Top drive cooling radiator failed. Rig moved 50.00 % Move rig off MP J-08A. Clean up contaminated snow from previous seawater spill. PU herculite. Start move to MP H-08A. Move rig (cont...) Rig moved 95.00 % (cont...) Move rig off MP J-08A. Clean up contaminated snow from previous seawater spill. PU herculite. Start move to MP H-08A. Top drive failed - Change operation Held safety meeting Core on cooling radiator for top drive startgd leaking. Filled catch pan. Less than one gallon spilled to pad. Crew shut down move. Leak contained. Notifications made. Cleaned up contaminated snow & ice. Completed operations Rig moved 100.00 % Finish spotting rig on MP H-08A. At well location - Cellar Rig accepted @ 1300 hrs on 12/29/99. Rigged up Drillfloor / Derrick Level rig. Berm and spot ancillary equipment. Stopped due to weather: Whiteout / Phase 3 Suspend operations Rig waited · Whiteout / Phase 3 .... Change out crew with convoy. Resumed operations Wellhead work Rigged down Xmas tree ND tree & adapter. Equipment work completed Nipple up BOP stack Rigged up BOP stack NU drlg spool & BOPE. Install riser & mousehole. Equipment work completed Test well control equipment Tested BOP stack Function tested BOPE. No test plug or TWC on location due to Phase 3 conditions. Function test completed satisfactorily Suspend operations Rig waited · Whiteout / Phase 3 Tried to stay busy during whiteout. Change out tongs. Plow drifts & move 3.5" DP. Reviewed Unit 4-STOP Training. Load pipe shed w/3.5" DP. Tally pipe. Cleaning up rig. Rig waited · Whiteout / Phase 3 Continue cleaning and painting rig. Pull top'drive radiator core out and plumb bypass. Test run-OK. Finish loading 3.5" DP. Clear drifts to MP J-Pad. 1¥/U¥~----. DI:IIUIU &Ol~C--ll)' 3lid . Put mud Facility M Pt H Pad Progress Report Well MPH-08A Page 2 Rig Nordic3 Date 24 January 00 Date/Time 30 Dec 99 06:00-06:00 06:00-00:00 31 Dec 99 00:00 00:00-06:00 00:00-06:00 00:00-06:00 06:00-06:00 06:00-06:00 01 Jan00 06:00-07:30 06:00-07:30 07:30 07:30-16:00 07:30-16:00 16:00 16:00-17:30 16:00-17:30 17:30 17:30-18:30 17:30-18:30 18:30 18:30-21:30 18:30-21:30 21:30 21:30-01:00 21:30-22:00 22:00 22:00-00:30 Duration 24 hr 18 hr 6 hr 6 hr 6 hr 24 hr 24 hr 1-1/2 hr 1-1/2 hr 8-1/2 hr 8-1/2 hr 1-1/2 hr 1-1/2 hr 1 hr 1 hr 3 hr 3 hr 3-I/2 hr 1/2 hr 2-1/2 hr Activity motors & mwd tools in pipe shed. Spill & Fire Suspend operations (cont...) Rig waited: Whiteout / Phase 3 (cont...) Continue cleaning and painting rig. Pull top drive radiator core out and plumb bypass. Test run-OK. Finish loading 3.5" DP. Clear drifts to MP J-Pad. Move Baroid & Sperry shacks & set up. Put mud motors & mwd tools in pipe shed. Spill & Fire Drills. Began precautionary measures Rig waited: Whiteout / Phase 3 Continue maintainence, Crew change w/convoy. Rig waited: Whiteout / Phase 3 Tested gas monitors. Continue maint, cleaning & painting. Convoy crew changes to MPU base camp. Rig waited: Whiteout / Phase 3 Service TD. Cut & slip Drlg line. Clean &-paint rig. Convoyed crews & fuel truck from MP Base Camp. Suspend operations (cont...) Rig waited: Whiteout / Phase 3 (cont...) Service TD. Cut & slip Drlg line. Clean & paint rig. Convoyed crews & fuel truck from MP Base Camp. Suspend operations (cont...) Rig waited: Whiteout / Phase 3 (cont...) Service TD. Cut & slip Drlg line. Clean & paint rig. Convoyed crews & fuel truck from MP Base Camp. Resumed operations Derrick management Racked back drill pipe PU & MU 3.5" DP. Receive whipstock, mills, MWD probe, & MWD engineer by roligon. D 1 Drill-OS- 1:15 min. 237 joints picked up BHA run no. 1 Made up BHA no. 1 Start loading BHA in pipe shed. Stopped: To hold safety meeting Suspend operations Rig waited: Whiteout / Phase 2 Crew change with convoy. Resumed operations BHA run no. 1 Made up BHA no. 1 Continue loading BHA, HWDP, & DC's. Spot cuttings box. Take on fuel & water. BHA no. 1 made up Test well control equipment Installed BOP test plug assembly Eqpt. work completed, running tool retrieved Tested BOP stack .' Test BOPE to 250 / 2000 psi. Left messages on NS & Anch AOGCC answering machines with no response. Facility Date/Time 02 Jan 00 03 Jan 00 M Pt H Pad 00:30 00:30-01:00 01:00 01:00-06:00 01:00-03:30 03:30 03:30-04:30 04:30 04:30-05:00 05:00 05:00-06:00 06:00-14:00 06:00-06:30 06:30 06:30-08:30 08:30 08:30-10:00 10:00 10:00-13:00 13:00 13:00-14:00 14:00 14:00-06:00 14:00-14:30 14:30 14:30-15:00 15:00 15:00-18:30 18:30 18:30-00:00 00:00 00:00-01:00 01:00 01:00-02:00 02:00 02:00-05:30 05:30 Progress Report Well MPH-08A Page 3 Rig Nordic3 Date 24 January 00 Duration 1/2 hr 5 hr 2-1/2 hr 1 hr 1/2 hr 1 hr 8 hr 1/2 hr 2 hr 1-1/2 hr 3 hr 1 hr 16hr 1/2 hr 1/2 hr 3-1/2 hr 5-1/2 hr 1 hr 1 hr 3-1/2 hr Activity Pressure test completed successfully - 2000.000 psi Installed Wear bushing Pull test plug. Set wear ring Eqpt. work completed, running tool retrieved BHA run no. 1 Made up BHA no. 1 PU & MU 12 DC's & 32its HWDP. BHA no. 1 made up R.I.H. to 2241.0 ft D 1 Drill-OS-45 sec. Stopped: To circulate Circulated at 2241.0 ft Circulate diesel out of well w/hot water. Hole displaced with Water - 120.00 % displaced R.I.H. to 4000.0 ft BHA run no. 1 (cont...) _-- Serviced Crown block Equipment work completed R.I.H. to 8608.0 ft Tagged retainer @ 8608 DPM. On bottom Circulated at 8608.0 ft Obtained bottoms up (100% annulus volume) Pulled out of hole to 1465.0 ft At BHA Pulled BHA LD drlg jars. i' ~ ~- ~ ~.t)~t~ BHA Stood back BHA run no. 2 Made up BHA no. 2 PU & load MWD. Stopped: To hold safety meeting Held safety meeting PreSpud meeting w/Nordic crew, Co Rep, Geologists, Sperry directional and MWD, & Baker Fishing. Completed operations Made up BHA no. 2 MU whipstock & bumper sub. Bumper sub not opening-change out. RIH w/BHA #2-Slow. Test MWD. BHA no. 2 made up R.I.H. to 8608.0 ft Blow down. Fill pipe @ 3900' & 6320'. On bottom Functioned downhole tools at 8608.0 ft Break circ. Orient & set whipstock 54 deg Right of Hi. Equipment work completed Circulated at 8590.0 ft Pump Hi-Vis spacer. Displace well to milling fluid. Hole displaced with Water based mud - 120.00 % displaced Milled Casing at 8617.0 ft Milled window f/8588' to 8600'. Milled 17'.- formation to 8617'. Sweeps as required. Completed operations RECE VEE) Facility M Pt H Pad Progress Re' ' ort Well MPH-08A Page 4 Rig Nordic3 Date 24 January 00 Date/Time 04 Jan 00 05 Jan 00 05:30-06:00 05:30-06:00 06:00-14:30 06:00-08:00 08:00 08:00-12:00 12:00 12:00-14:30 14:30 14:30-06:00 14:30-19:30 19:30 19:30-02:30 02:30 02:30-03:30 03:30 03:30-05:30 05:30 05:30-06:00 06:00-06:00 06:00-02:30 02:30 02:30-03:30 03:30 03:30-04:00 04:00 04:00-06:00 06:00 Duration Activity 1/2 hr Circulated at 8617.0 ft Circ sweeps while rotate & reciprocate through window. 1/2 hr Circulated at 8617.0 ft Continue Circ and pump sweeps while rotating & reciprocating pipe through window @ 8588' to 8600' 8-1/2 hr BHA run no. 2 (cont...) 2 hr Circulated at 8617.0 ft (cont...) Continue Circ and pump sweeps while rotating & reciprocating pipe through window @ 8588' to 8600' Obtained clean returns - 250.00 % hole volume 4 hr Pulled out of hole to 850.0 ft Blow down top drive, Mix and pump dry job. POOH to BHA Monitor well for 10 min O.K. At BHA 2-1/2 hr Pulled BHA Pull and stand back BI-IA. Lay down window mills, Top mill in full 6" gauge. Should have a good window. Completed operations 15-1/2 hr BHA run no. 3 5 hr Made up BHA no. 3 Change out MWD. M/U up/load tool, M/U BHA #3 'R IH test MWD O.K. BHA no. 3 made up 7 h..~~~t~D to 8435.0 ft RIH P/U 102 3-1/2" DP f/pipe shed, Run 24 stands out of derrick. P/U 27 it's 3-1/2" HWDP. [t'J{~{~ Stopped' To service drilling equipment 1 hr - Serviced Block line . ~, ~,~[,~.G0~tlll~II~ & cut drilling line 50' ~k$11 · ~h*~-.~ Equipment work completed 2 hr t~ll~,t~'x~. R.I.H. to 8570.0 ft RIH w/2 std's HWDP Orient MWD tool. Slid through window @ 8588' to 8600' Tag up @ 8620' On bottom 1/2 hr Drilled to 8630.0 ft Slid & drill out window 24 hr BHA run no. 3 (cont...) 20-1/2 hr Drilled to 9449.0 ft Directional drill 6" hole from 8630' to 9449' horizontal. Pumped 3 sweeps. Continue drilling "OA" sand top @ 9220' MD 4156' TVD. Started scheduled wiper trip: due to Footage drilled 1 hr Circulated at 9449.0 ft Pumped sweep and circulated up in to 7'; casing. String displaced with Lo/Hi vis combination - 125.00 % displaced 1/2 hr Pulled out of hole to 8712.0 ft Pull up to 8712' to circulate out sweeps from 7" casing. Stopped ' To circulate 2 hr Circulated at 8712.0 ft Circulate out sweeps and clean up 7" casin, g, 130 spm @ 2640 psi Obtained bottoms up (100% annulus volume) STATE OF ALASKA ALASKA L,,~_ AND GAS CONSERVATION CON~ISSION 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 .). Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2767' NSL, 4061' WEL, SEC. 34, T13N, R10E, UM At top of productive interval 722' SNL, 1909' EWL, SEC. 1, T12N, R10E, UM At effective depth 797' SNL, 2050' EWL, SEC. 1, T12N, R10E, UM At total depth 828' SNL, 2117' EWL, SEC. 1, T12N, R10E, UM 5. Type of well: [~ Development I--] Exploratory [--I Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 64.90' 7. Unit or Property Name Milne Point Unit 8. Well Number MPH-08 9. Permit Number 97-173 10. APl Number 50-029-22808 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 9275 feet true vertical 4392 feet Effective depth: measured 9167 feet true vertical 4314 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) Cemented MD TVD 110' 20" 250 sx Arcticset I (Approx.) 110' 110' 9222' 7" 2047 sx PF 'E', 263 sx 'G', 191 sx PF 'C' 9253' 4376' Perforation depth: measured true vertical 8940'-8960', 9014'-9034' 4150'-4164', 4203'-4218' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 8743' Packers and SSSV (type and measured depth) None 0il 8, Gas Cons. Anchorage 13. Attachments [] Description summary of proposal r-I Detailed operations program [--1 BOP sketch 14. Estimated date for commencing operation November 1, 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~1 Gas I--I 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 Signed Robed Laule _ _ Title Operations Drilling Engineer Commission Use Only Date Conditions of Approval: Notify Commission so representative witness I Approv , No. ,3 ¢ . -6 OoO¥ Plug integrity '~ BOP Test m,,~y Location clearance F,99 ~,,roe~ Mechanical Integrity Test Subsequent form required 10- I ORiGiNAL S NED-BY I~ed by order of the Commission Ro~ N. Chdste.son Commissioner Date' Form 10-403 Rev. 06/15/88 Submit In Triplicate t _ hare. d - erv ces rilling Alaska ~ To: Blair Wondzell - AOGCC From: Michael Triolo Subject: MPh-08 Application for sundry permit - P&A for Sidetrack Operations Date: 4 October 1999 Reference: API #50-029-22808 H-08 was drilled as part of the Sweet 16 project into an isolated hydraulic unit. The OB sand was fracced with 24 mlbs proplock and the OB was fracced with 55 mlbs proplock. The N sands were not perforated. The well was put on production in June 98 at circa 200 b/d. In October 98 the well was inadvertently drawn down to 650 psi BHFP and the resultant proppant production failed the PCP. The well rates were not economic to work over the well and it was shut in and freeze protected. The MPH-08 plug and abandonment is currently scheduled for Nabors 4ES in mid November pending Sundry approval. The plug and abandonment work for MPH-08 will precede the actual sidetracking of the well by Nordic 3. Pre-Rig work: 1) Amarada Survey 2) Test Intermediate Packoff to 5,000psi 3) Injectivity test 4) Pull dummy valve from lower GLM 5) Dummy GLM 6) 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) 9) 10) 12) 13) 14) 15) RIH with retainer on wireline with CCL. Set retainer @-8,597' depending on collar location. RIH with tubing sting into retainer and establish inj rate and press, depending on inj. rates, remain stung in or sting out. Batch mix cement, pump cement down tubing to top of retainer, sting in (if low inj rate) and squeeze to perf's. Sting out reverse circulate right on top of retainer to clean out tubing and top of retainer. POH to 2,000', freeze preotect, continue POH. ND BOP, NU tree and test to 5,000 psi. Pull TWC and set BPV Release Rig Tr(~e: 2 9/16" 5M M PU H'08 Wellhead: 11" 5M FMC Gan 6 _. O.,_~,3L Elev. = 36.0' 2-7/8" 8rd. EUE bottom and top, 2.5" CITM .... ----~' ~ ..... ii'ii RT To Tbg. Spool = 30.6' (N 22E) BPV profile. 20" 91 1 ppf, H-40 115' Camco 2 7/8" x 1 sidepocketl 1 37' KOP @ 300' i~im~ KBMM GLM I Max. hole angle = 78 to 80 deg. f/3600' to 7450' ~'~:~' I2'100' Hole angle thru' perfs= 44 deg. i Howco 7 .... ES" Cementer 2-7/8" 6.5 ppf, L-80, EUE 8rd tubing ( drift ID = 2.347, cap. = .00579 bpf) ~i:... 7" 26 ppf, L-80, BTC mod production csg. (drift ID = 6.276", cap. = 0.0383 bpi ) il, iill; ii?i Note' Well is equiped with ~'.~.. Positive displacement pump. i~'~i iii Two 7" x 20' marker Jts. from ' '~' 8562' to 8602' md Stimulation Summary ............. Camco 2 7/8" x 1" sidepocket I 8627' 06/11/98 'OB' Sand, 24,260 lbs. 12-20 KBMM GLM - Ottowa proppant behind pipe coated w/ PropLok resin - natural color (no dye)"ii'~I KUDU PCP, series 513, 200 06/13/98 - 'CA' Sand, 54,900 lbs. 12-20 Ottowa ~¢ii :;.::.iii~ TP 1800 3roppant behind pipe coated w/PropLok resin- Centrilift GSB3 LT HSN I 8719' natural color (no dye)i seal section Proposed Perforation Summary 63 hp motor, 1560v. / 26 amps. 9:1 Gear ratio Ref log' GR / CCL 06/xx/98 Size ~PF Interval (TVD) Baker sentry 'N' Sand gauges o be (ompleted at a laterdate 'CA' Sand 4.5" 4 ~940' - 8960' (4150'-4165') 'OB' Sand 4.5" 4 ~014' - 9034' (4203'-4217') 28 gm Jumbo Jet ("big hole") charges @ 0 - 180 deg. phasing (TTP = 5.2", EHD = 0.93"). 7" landing collar (PBTD) 9167' md : : 7" float collar 9209' md 7" float shoe 9251' md DATE ~EV. BY COMMENTS MILNE POINT UNIT 10-01-97 JBF Drilled and Cased by Nabors 22E WELL No · H-08 6/20/98 M. Linder Frac and completion by Nabors 4-ES APl · 50-029-22808 BP EXPLORATION (AK) Tree: 2 9/16" 5M 08(P ) Orig. KB Elev. = 64.9' (N 22E) MPU H- Pro_osed_ Orig. GL Bev. = 36.0' Wellhead: 11" 5M FMC Gen 6 . 2-7/8" 8rd. EUE bottom and top, 2.5" RT To Tbg. Spool = 30.6' (N 22E) CIW BPV profile. 20" 91.1 ppf, H-40 I 115' Camco 2 7/8" x 1" KOP @ 300' sidepocket KBMM GLM Max. hole angle = 78 to 80 deg. f/3600' to 7450' ! Howco 7 .... ES" Cementer J 2,100' Hole angle thru' perfs = 44 deg. I I 7" 26 ppf, L-80, BTC mod production csg. ( drift ID = 6.276", cap. = 0.0383 bpf ) Two 7" x 20' marker Jts. from 8,562' to 8,602' md Stimulation Summary - 06/11/98 -'OB' Sand, 24,260 lbs. 12-20 Ottowa proppant behind pipe coated w/ PropLok resin - natural color (no dye) 06/13/98 - 'CA' Sand, 54,900 lbs. 12-20 Ottowa proppant behind pipe coated w/ PropLok resin - natural color (no dye) Proposed Perforation Summary Ref lo.a: GR / CCL 06/xx/98 /Cement Size SPF 'N'lnterVaIsand (TVD) ~/ Cement to ~e co -npleted at a later date 4.5" 4 8,940' 8,960' (4,150'-4,165') - .';¢i[ .:i~i~ '~;~ ;;~ ;¢ ":~¢ :';;~ .-~'~;~s ~ ~-:-:¢~ ..:..~' ~;; ~;. ¢: ~';:'~ .~ .: i':' :':~"~::~i~i 'OB' Sand 4.5" 4 9,014' - 9,034' (4,203'-4,217') 28 gm Jumbo Jet ("big hole") charges @ 0 - 180 deg. phasing (TTP = 5.2", EHD = 7" landing collar (PBTD) 9,167' md 0.93"). ~:: 7" float collar 9,209' md 7" float shoe 9,251' md DATE REV. BY COMMENTS MILNE POINT UNIT 10-01-97 JBF r .rilled and Cased by Nabors 22E WELL No · H-.08 6/20/98 M. Linder Frac and completion by Nabors 4-ES APl · 50-029-22808 lO/04/99 M. Triolo Proposed decompletion by Nabors 4ES BP EXPLORATION (AK) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~ Oil E~] Gas I--} Suspended E~] Abandoned I--I Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-173 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ..... I~ 50-029-22808 4. Location of well at surface i ;:~..i, ~:,. ,~'-~, ~.~.~ '-,~ ;'-'~ ''f'~'~~ 9. Unit or Lease Name ?./,,¢_~'~' ../~'._~~,, ,,,.~_~-: ! .!~~ ~ Milne Point Unit 2767' NSL, 4061' WEL, SEC. 34, T13N, R10E, UM At top of productive interval ....... 10. Well Number 722' SNL, 1909' EWL, SEC. 2, T12N, R10E, UM ~: V?~:I~? ; MPH-08 At total depth ..... ,,¢~.~..¢_~ .... 11. Field and Pool 828' SNL, 2117' EWL, SEC. 2, T12N, R10E, UM '"' Milne Point Unit / Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 64.90'I ADL 380109 12. Date Spudded9/23/97 I 13' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if OffshOre 116' NO' Of cOmpletiOns9/28/97 6/18/98 N/A MSL! One 17. Total Depth (MD+TVD)I18. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 9275 4392 FTI 9167 4314 FTI [~Yes [--]No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD 23. CASING, LINER AND CEMENTING RECORD CASING SE%I-lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 110' 24" 250 sx Arcticset I (Approx.) 7" 26# L-80 31' 9253' 8-1/2" 2047 sx PF 'E', 263 sx 'G', 191 sx PF 'C' 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) 4-1/2" Gun Diameter, 4 spf 2-7/8", 6.5#, L-80 8721' MD TVD MD TVD 8940'-8960' 4150'-4164' 9014'-9034' 4203'-4218' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 70 bbls diesel Frac, 9014-9034' 24260# 12/20 Ottawa w/proplok behind pipe Frac, 8940'-8960' 54880# 12/20 Ottawa w/proplok behind pipe 27. PRODUCTION TEST Date First Production [Method of Operation (Flowing, gas lift, etc.) June 27, 1998 [ Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,.,..-,.o 0ii °" Cons. (;of 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 Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. ,,, TSBD 8937' 4148' TSBC 8973' 4174' TSBB 9010' 4200' ':~1. List of Attachments Summary of Daily Drilling Reports, Surveys 32' I hereby ~reg°ing i~c°rrect te~e best °f my kn°wledge Signed ~.s ~.~..~ ~~~.~ ~.~.~....~ ... ':r.~,~['.,. _.__~-¢/__. _ _________Title Drilling Engineering Supervisor Date MPH-08 97-173 Prepared By Name/Number: Kathy Campoamor, 564-5122 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 Progress Report Facility M Pt H Pad Well MPH-08 Rig Nabors 4ES Page 1 Date 12 August 98 Date/Time 22 Sep 97 00:01-01:30 01:30-03:00 03:00-06:00 06:00-12:00 12:00-15:00 15:00-22:00 22:00-23:00 23:00-02:30 23 Sep 97 02:30-03:00 03:00-03:30 03:30-04:00 04:00-06:00 06:00-20:30 20:30-21:00 21:00-22:00 22:00-23:00 23:00-00:30 24 Sep 97 00:30-06:00 06:00-08:00 08:00-09:00 09:00-11:00 11:00-12:00 12:00-13:00 13:00-15:00 15:00-23:00 23:00-00:00 25 Sep 97 00:00-01:30 01:30-02:00 02:00-02:30 02:30-06:00 06:00-09:30 09:30-10:30 10:30-11:00 11:00-14:00 14:00-18:30 18:30-19:30 19:30-22:30 22:30-00:00 26 Sep 97 00:00-01:00 01:00-02:00 02:00-06:00 06:00-09:00 09:00-16:30 16:30-18:00 18:00-18:30 18:30-20:30 20:30-22:00 22:00-23:00 23:00-01:00 27 Sep 97 01:00-06:00 06:00-14:00 14:00-14:30 14:30-15:15 15:15-16:15 Duration 1-1/4 hr 1-1/2 hr 3 hr 6 hr 3 hr 7 hr 1 hr 3-1/2 hr 1/2 hr 1/2 hr 1/2 hr 2hr 14-1/2 hr 1/2 hr 1 hr 1 hr 1-1/2 hr 5-1/2 hr 2 hr 1 hr 2 hr 1 hr 1 hr 2hr 8hr lhr 1-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 3-1/2 hr 1 hr 1/2 hr 3 hr 4-1/2 hr lhr 3hr 1-1/2 hr 1 hr 1 hr 4 hr 3 hr 7-1/2 hr 1-1/2 hr 1/2 hr 2 hr 1-1/2 hr lhr 2hr 5 hr 8 hr 1/2 hr 3/4 hr lhr Activity Rig moved 0.00 % Rig moved 10.00 % Rig moved 45.00 % Rig moved 70.00 % Rig moved 100.00 % Installed Divertor Serviced Top drive Made up BHA no. 1 Held safety meeting Tested Divertor Made up BHA no. 1 Drilled to 271.0 ft Drilled to 2380.0 ft Circulated at 2380.0 ft Pulled out of hole to 900.0 ft Serviced Top drive R.I.H. to 2380.0 ft Drilled to 3212.0 ft Drilled to 3489.0 ft Circulated at 3489.0 ft Pulled out of hole to 905.0 ft Pulled BHA Serviced Top drive R.I.H. to 3489.0 ft Drilled to 4674.0 ft Circulated at 4674.0 ft Pulled out of hole to 3303.0 ft Serviced Top drive R.I.H. to 4674.0 ft Drilled to 5287.0 ft Drilled to 5954.0 ft Circulated at 5954.0 ft Pulled out of hole to 5381.0 ft Pulled out of hole to 3950.0 ft Pulled out of hole to 905.0 ft Pulled BHA Made up BHA no. 2 Serviced Block line Serviced Top drive Singled in drill pipe to 1989.0 ft R.I.H. to 4500.0 ft R.I.H. to 5954.0 ft Drilled to 7204.0 ft Circulated at 7204.0 ft Pulled out of hole to 6800.0 ft Backreamed to 6800.0 ft Pulled out of hole to 4360.0 ft Serviced Top drive R.I.H. to 7204.0 ft Drilled to 7681.0 ft Drilled to 8538.0 ft Circulated at 8538.0 ft Pulled out of hole to 8538.0 ft Backreamed to 7190.0 ft Anchorage Facility Date/Time 28 Sep 97 29 Sep 97 30 Sep 97 Progress Report M Pt H Pad Well MPH-08 Rig Nabors 4ES Page 2 Date 12 August 98 16:15-17:00 17:00-18:00 18:00-20:00 20:00-05:30 05:30-06:00 06:00-07:30 07:30-12:30 12:30-13:00 13:00-14:15 14:15-16:00 16:00-17:00 17:00-22:00 22:00-00:30 00:30-04:30 04:30-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-20:45 20:45-21:00 21:00-00:00 00:00-00:15 00:15-01:45 01:45-02:30 02:30-05:45 05:45-06:00 06:00-07:00 07:00-07:30 07:30-08:00 08:00-08:15 08:15-08:45 08:45-11:00 11:00-13:30 13:30-15:00 15:00-16:30 16:30-18:30 18:30-21:00 Duration 3/4 hr 1 hr 2 hr 9-1/2 hr 1/2 hr 1-1/2 hr 5 hr 1/2 hr 1-1/4 hr 1-3/4 hr 1 hr 5hr 2-1/2 hr 4 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 12-1/4 hr 1/4 hr 3 hr 1/4 hr 1-1/2 hr 3/4 hr 3-1/4 hr 1/4 hr lhr 1/2 hr 1/2 hr 1/4 hr 1/2 hr 2-1/4 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr 2hr 2-1/2 hr Activity Pulled out of hole to 6650.0 ft Serviced Top drive R.I.H. to 8538.0 ft Drilled to 9275.0 ft Circulated at 9275.0 ft Circulated at 9275.0 ft Pulled out of hole to 943.0 ft Pulled BHA Downloaded MWD tool Made up BHA no. 3 Serviced Top drive R.I.H. to 9275.0 ft Circulated at 9275.0 ft Pulled out of hole to 9275.0 ft Pulled BHA Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 9253.0 ft (7in OD) Rigged up Cement head Circulated at 7253.0 ft Pumped Water based mud spacers - volume 50.000 bbl Mixed and pumped slurry - 507.000 bbl Displaced slurry - 348.000 bbl Circulated at 2098.0 ft Pumped Water based mud spacers - volume 50.000 bbl Mixed and pumped slurry - 414.000 bbl Displaced slurry - 80.000 bbl Cleared Flowline Rigged down Cement head Rigged down Casing handling equipment Removed Flowline Rigged down Divertor Installed Casing spool Installed Adapter spool Installed Xmas tree Laid out 5in drill pipe from derrick Progress Report Facility M Pt H Pad Well MPH-08 Rig (null) Page 1 Date 12 August 98 Date/Time 08 Jun 98 09 Jun 98 10 Jun 98 11 Jun 98 12 Jun 98 13 Jun 98 23:00-01:00 01:00-03:00 03:00-05:00 05:00-06:00 06:00-06:15 06:15-06:30 06:30-07:30 07:30-09:00 09:00-09:15 09:15-09:30 09:30-11:30 11:30-11:45 11:45-12:00 12:00-13:00 13:00-13:30 13:30-15:00 15:00-16:00 16:00-18:30 18:30-05:00 05:00-05:30 05:30-06:00 06:00-08:30 08:30-09:30 09:30-12:30 12:30-15:30 15:30-19:00 19:00-22:00 22:00-00:00 00:00-02:00 02:00-03:30 03:30-06:00 06:00-11:30 11:30-12:30 12:30-15:00 15:00-18:00 18:00-19:00 19:00-20:00 20:00-00:00 00:00-04:30 04:30-05:00 05:00-06:00 06:00-08:30 08:30-11:30 11:30-12:30 12:30-15:00 15:00-19:30 19:30-22:00 22:00-01:00 01:00-02:00 02:00-03:00 03:00-06:00 06:00-08:30 08:30-10:00 10:00-15:00 Duration 2 hr 2 hr 2hr 1 hr 1/4 hr 1/4 hr lhr 1-1/2 hr 1/4 hr 1/4 hr 2 hr 1/4 hr 1/4 hr 1 hr 1/2 hr 1-1/2 hr lhr 2-1/2 hr 10-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr lhr 3hr 3 hr 3-1/2 hr 3 hr 2hr 2hr 1-1/2 hr 2-1/2 hr 5-1/2 hr 1 hr 2-1/2 hr 3 hr 1 hr 1 hr 4 hr 4-1/2 hr 1/2 hr 1 hr 2-1/2 hr 3hr 1 hr 2-1/2 hr 4-1/2 hr 2-1/2 hr 3 hr lhr lhr 3hr 2-1/2 hr 1-1/2 hr 5hr Activity Rigged down Drillfloor / Derrick Rig moved 100.00 % Rigged up Drillfloor / Derrick Installed Fluid system Held safety meeting Monitor wellbore pressures Removed Xmas tree Installed BOP stack Retrieved Tubing hanger Installed BOP test plug assembly Tested All functions Retrieved BOP test plug assembly Installed Wear bushing Rigged up Drillstring handling equipment Made up BHA no. 1 Singled in drill pipe to 2078.0 ft Circulated at 2078.0 ft Drilled installed equipment - Cement retainer Singled in drill pipe to 8777.0 ft Drilled cement to 9131.0 ft Circulated at 9131.0 ft Reverse circulated at 9131.0 ft Tested Casing - Via annulus and string Pulled out of hole to 0.0 ft R.I.H. to 9111.0 ft Reverse circulated at 9111.0 ft Pulled out of hole to 0.0 ft Worked on BOP - Lubricator Perforated from 9014.0 ft to 9034.0 ft Worked on BOP - Bell nipple Ran Tubing to 1562.0 ft (3-1/2in OD) Ran Tubing to 8612.0 ft (3-1/2in OD) Installed High pressure lines Injectivity test - 100.000 bbl injected at 5344.0 psi Batch mixed slurry - 946.000 bbl FRAC job - 346.000 bbl injected at 4965.0 psi Reverse circulated at 8612.0 ft Monitor wellbore pressures Reverse circulated at 8980.0 ft Injectivity test - 10.000 bbl injected at 800.0 psi Batch mixed slurry - 20.000 bbl Circulated at 8980.0 ft Pulled Tubing in stands to 0.0 ft Worked on BOP - Lubricator Rig waited: Service personnel Perforated from 8940.0 ft to 8960.0 ft Worked on BOP - Lubricator Ran Tubing in stands to 8520.0 ft Installed High pressure lines Injectivity test - 150.000 bbl injected at 5600.0 psi FRAC job - 300.000 bbl injected at 4800.0 psi FRAC job - 528.000 bbl injected at 5616.0 psi Reverse circulated at 8520.0 ft Monitor wellbore pressures Progress Report Facility M Pt H Pad Well MPH-08 Rig (null) Page 2 Date 12 August 98 Date/Time 15:00-16:00 16:00-23:00 23:00-02:00 14 Jun 98 02:00-03:30 03:30-06:00 06:00-11:00 11:00-13:00 13:00-13:30 13:30-14:30 14:30-15:30 15:30-22:30 22:30-03:00 15 Jun 98 03:00-04:00 04:00-06:00 06:00-06:30 06:30-08:00 08:00-12:00 12:00-20:00 20:00-21:30 21:30-03:00 16 Jun 98 03:00-06:00 06:00-06:30 06:30-11:30 11:30-20:00 20:00-06:00 17 Jun 98 06:00-06:30 06:30-13:00 13:00-15:00 15:00-16:30 16:30-18:00 18:00-20:30 20:30-22:00 22:00-00:00 Duration 1 hr 7 hr 3hr 1-1/2 hr 2-1/2 hr 5hr 2hr 1/2 hr 1 hr 1 hr 7 hr 4-1/2 hr 1 hr 2 hr 1/2 hr 1-1/2 hr 4hr 8hr 1-1/2 hr 5-1/2 hr 3 hr 1/2 hr 5 hr 8-1/2 hr 10hr 1/2 hr 6-1/2 hr 2 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 2 hr Activity Reverse circulated at 8520.0 ft Laid down 8520.0 ft of Tubing Ran Drillpipe in stands to 8706.0 ft Batch mixed slurry - 350.000 bbl Reverse circulated at 8800.0 ft Reverse circulated at 9162.0 ft Reverse circulated at 9162.0 ft Flow check Laid down 939.0 ft of 3-1/2in OD drill pipe Serviced Block line Circulated at 8223.0 ft Laid down 8223.0 ft of 3-1/2in OD drill pipe Tested Variable ram Ran Tubing to 2262.0 ft (2-7/8in OD) Held safety meeting Pulled Tubing in stands to 2262.0 ft Rigged up sub-surface equipment - ESP Ran Tubing to 6453.0 ft (2-7/8in OD) Installed Completion equipment Ran Tubing to 8080.0 ft (2-7/8in OD) Pulled Tubing in stands to 6080.0 ft Held safety meeting Pulled Tubing in stands to 0.0 ft Serviced ESP Ran Tubing in stands to 8136.0 ft Held safety meeting Ran Tubing in stands to 8700.0 ft Installed Tubing hanger Installed Tubing hanger Rigged down BOP stack Installed Xmas tree Tested Xmas tree Freeze protect well - 70.000 bbl of Diesel Milne Point Unit, Alaska TO: FROM: Well Name: Main Category: Sub Category: Operation Date: Bill Hill Thackeray / Spearman MP H-08 'DRLG COMPL Eline Peal 6-11-98 Date: 16-11-98 Objective: E-line convey perforate the Schrader Bluff "OB" sands. Utilize tractor tool if necessary. Sequence of Events: RU Atlas MU Tools and guns on rollers PJSM P/T Lubricator to 500 psi Able to roll thru 80 degree hole to PBTD Make correlation pass to tie into MWD log 9/28/97 Depth correct. Drop back down and tag PBTD @ 9167.5' Position gun in "OB" interval Perforate "OB" sand from 9014-9034' with 4 ~,~" gun 4 spf Big Hole charges @ 0-180 phasing POOH. All shots fired RD Atlas Results: Perforated the Schrader Bluff "OB" sand from 9014-9034' (20') with 4 ~,,~" guns with 4 Big Hole spf at 0-180 degree phasing. Tie in log/date: Sperry MWD 9/28/97 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter Shot Density Orientation Phasing 5002922'0@000 . s .oP . i'::.?~.0./, 4/97 565 92 565 4~5~',~:~'.'~'500 55 749. O? 74ff 7~ ~ s 9 5I 14 1207.28 11~2193':'. 1128.0~ 1297.79 1276"~;5:1~ 1211.61 , .'. 1390· 55 1359:'~ 76 1294.86 1483.86 144~. 50 1376.60 1574.33 1518.60 1453.70 .. 1671.18 159R. 48 1534 · 58 1764 . 92 1676,. 90 1612 · 00 Y-SUN DRILLING SERVICES ANCHOR. AGE ALASKA PAGE DATE OF SURVEY: 092897 MWD gURVEY JOB NUMBER: AK-MM-70279 KELLY BUSHING ELEV. = 64.90 FT. OPERATOR: BP EXPLORATION COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 0 0 N .00 E .00 0 0 N .00 E .00 0 33 N 26.48 E .61 1 30 .S 46.44 E 1.94 3 4 S 47.85 E 1.77 3 39 S 41.59 E .75 4 5 S 43.27 E .48 5 14 S 50.15 E 1.44 6 21 S 47.42 E 1.22 8 23 S 43.21 E 2.37 11 10 S 46.33 E 3.05 14 40 S 52.69 E 4.13 17 25 S 58.25 E 3.37 20 34 S 63.28 E 3.85 24 31 S 61.76 E 4.42 27 46 S 63.91 E 3.64 29 52 S 64.61 E 2.28 33 11 S 63.33 E 3.74 33 34 S 63.12 E .41 35 3 S 64.12 E 1.70 .00N · 00N :. 39N .04S -2.45S · 00E · 00E · 19E 1.25E 3.86E VERT. SECT. .O0 .00 -.03 1.10 4.57 6 . 26S 7 . 60E 9 . 73 10.90S -11.85E 15 . 74 15.80S 17.13E 22.77 22 . 10S 24 . 29E 32 . 13 30.13S 32.33E 43.13 41.27S 43.46E 58.36 54.39S 59.07E 78.46 68.97S 80.44E 104.26 83.47S 106.57E 134.14 99.52S 137.33E 168.80 118.14S 173.72E 209.60 137.66S 214.23E 254.43 158.44S 256.72E 301.60 182.45S 304.29E 354.78 205.92S 351.63E 407.49 1854.76 1750.23 1685.33 1944.61 1822.78 1757.88 2035.82 1894.54 1829.64 2128.43 1964.37 1899.47 2219.67 2029.75 1964.85 2310· 58 2091.56 2026.66 2404.03 2151.74 2086.84 2497.06 2208.54 2143.64 2589.19 2261.62 2196.72 2681.72 2310.96 2246.06 2772.76 2355.04 2290.14 2864.06 2394.74 2329.84 2957.17 2430.81 2365.91 3050.28 2462.81 2397.91 3145.77 2491.31 2426.41 35 31 S 63.20 E .78 36 48 S 58.58 E 3.36 39 24 S 56.73 E 3.10 42 42 S 58.36 E 3.76 45 44 S 60.76 E 3.79 48 34 .S 58..90 E 3.-47. - 51 15 S 61.67 E 3.65 53 29 S 59.68 E 2.94 56 8 S 59.47 E 2.88 59 24 S 59.18 E 3.54 62 39 S 59.50 E 3.58 65 46 S 58.85 E 3.48 68 38 S 59.91 E 3.25 71 8 S 59.89 E 2.69 74 7 S 60.60 E 3.21 228.95S 398.15E 459.26 254.75S 444.42E 512.24 284.88S 491.95E 568.48 317.49S 543.28E 629.25 349.69S 598.15E 692.87 383..21S 655.76E 759.52 418.61S 717.86E 830.99 454.71S 782.07E 904.65 492.84S 846.99E 979.94 532.77S 914.31E 1058.20 573.38S 982.82E 1137.84 615.51S 1053.40E 1220.04 659.22S 1127.27E 1305.87 703.05S 1202.90E 1393.28 748.28S 1282.01E 1484.41 3~9~ 3989 3884 3980 40?5 S~ SERVICE~i'!~IDR'ILLING . No~ ~0~ ~o~o~. 'COMP~ATiON DATE??10/ 4/97 TR~::~.-?~~- SEA M~D ~RTI~~'/~R~IC~ D~P~ D~ PTH~'..:~'~,:::~ ;h:DE PTH 3235.82 ~: 25~5'.:'~?~ ~".A~50.84 73 7 s 5 36 4'Q:~::~'26 · ,~ .~,.~,~,~?/,~ .,~ :.> 4169 4264 4360 4455 4551 46.46 4741 4836 4932 5027 5123 5215 5313 5409 5505 5600 5695 5792 5885 5951 2633 . ~.,568,75 · 2651. 1'86' 66 2670: ~1605 · 50 2689. 1'24 . 74 ',,"£L '!',,. '-~ . ,~j~,'i.,.'.~ ,.. · 81 2707.9'i~i{:'~ii}'2643 - O1 .55 2724 6.7,,~;~2659 77 .27 2742 '6'~?.~'I~; 2677 70 .47 · 05 2779,7~}:?,"~- 2714 . 84 ,~.. , .07 27967:::~'<~}~.'' 2731.76 .22 28147~?~74; '2749.84 .95 2832[~}~80 2767.90 .27 2850~85 2785.95 .58 2870'?: 40 2805.50 .~.~ ,~,. .os 2 S 9r" 0 2a24.40 · 38 2 d .ZZ 2a42.2Z · 92 2 f'5.a .60 29~3.35 2878.45 .48 2 , 2.0z 2s 7. .77 3ff0t. 33 2936.43 .05 30'~9.29 2954.39 .87 3036 29 2971.39 .37 3048.54 2983.64 5997.79 3057.36 2992.46 6094.48 3076.22 3011.32 6189.84 3095.41 3030.51 6283.22 3114.77 3049.87 6374.15 3132.70 3067.80 Y-SUN DRILLING SERVICES ANCHOR. AGE ALASKA PAGE DATE OF SURVEY: 092897 MWD SURVEY JOB NUMBER: AK-MM-70279 KELLY BUSHING ELEV. = 64.90 FT. OPERATOR: BP EXPLORATION COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 74 22 S 61.08 E .58 790.515 1357.70E 76 15 S 58.95 E 2.98 835.835 1436.23E 77 6 S 56.90 E 2.42 882.155 1510.14E 79 12 .S 57.86 E 2.47 931.205 1586.78E 77 48 S 57.85 E 1.51 979.395 1663.46E 1571.06 1661.73 1748.92 1839.8~ 1930.36 78 13 S 60.35 E 2.67 1025.985 1741.31E 80 24 S 60.32 E 2.40 1069.925 1818.47E 78 18 S 60.49 E 2.16 1116.985 1901.33E 78 57 S 61.25 E 1.03 1162.615 1983.20E 77 41 S 61.85 E 1.46 1207.005 2065.13E 2021.08 2109.87 2205.15 2298.86 2391.98 79 57 S 61.86 E 2.40 1250.635 2146.69E 79 39 S 62.41 E .65 1294.215 2229.12E 78 44 S 62.77 E 1.03 1337.495 2312.58E 78 5 S 62.74 E .67 1380.195 2395.50E 80 9 S 61.23 E 2.65 1424.275 2478.34E 2484.41 2577.57 2671.47 2764.59 2858.35 79 20 S 61.64 E .95 1468.985 2560.46E 78 45 S 62.79 E 1.34 1512.525 2643.10E 79 30 S 60.69 E 2.29 1557.035 2725.89E 78 40 S 60.51 E .89 1602.975 2807.43E 77 39 S 60.16 E 1.12 1649.145 2888.48E 2951.81 3045.12 3139.05 3232.63 3325.91 79 30 S 59.93 E 1.94 1695.865 2969.55E 78 15 S 59.63 E 1.39 1741.465 3047.84E 79 46 S 59.79 E 1.55 1790.245 3131.35E 79 12 S 59.70 E .59 1837.645 3212.61E 78 19 S 59.48 E .95 1885.235 3293.69E 3419.47 3510.07 3606.79 3700.86 3794.87 77 37 S 59.63 E .76 1932.415 3373.97E 78 44 S 58.07 E 1.99 1980.565 3453.62E 79 45 S 57.79 E 1.10 2030.785 3533.78E 79 21 S 56.72 E 1.20 2080.695 3611.38E 79 4 S 57.08 E .69 2115.825 3665.28E 3887.99 3981.06 4075.60 4167.79 4232.06 79 0 S 56.63 E .97 2140.745 3703.44E 78 30 S 56.93 E .59 2192.705 3782.77E 78 16 S 56.31 E .68 2244.095 3860.77E 77 48 S 56.49 E .54 2294.645 3936.86E 79 26 S 57.45 E 2.09 2343.225 4011.59E 4277.57 4372.29 4465.56 4556.77 4645.80 SHARED SERVICES DRILLING MPu /-MPH-08 500292280800 NoRTH SLOPE BOROUGH COMPUTATION DATE: 10/ 4/97 Y-SUN DRILLING SERVICES ANCHOR_AGE ALASKA DATE OF SURVEY: 092897 MWD SURVEY JOB NUMBER: AK-MM-70279 KELLY BUSHING ELEV. = OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN ! ! PAGE 3 64.90 FT. COURSE DLS~ TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 6471~..83 3150.88 3085.98 79 5 S 57.05 E .54 2395.14S 4092.30E 6567.04 3168.94 3104.04 79 1 S 56.69 E .38 2446.23S 4170.59E 6662.20 3187.36 3122.46 78 39 S 56.40 E .50 2497.70S 4248.48E 6759.05 3206.'77 3141.87 78 13 -S 55.81 E .74 2550.61S 4327.24E 6853.04 3224.24 3159.34 80 20- S 56.77 E 2.46 2601.85S 4404.05E 6949.51 3240.59 3175.69 80 8 S 56.95 E .28 2653.83S 4483.65E 7044.95 3257.11 3192.21 79 55 S 57.16 E .31 2704.95S 4562.54E 7138.78 3273.91 3209.01 79 26 S 58.55 E 1.55 2754.06S 4640.69E 7235.38 3291.83 3226.94 79 10 S 58.50 E .28 2803.62S 4721.65E 7332.78 3310.29 3245.39 78 59 S 58.37 E .23 2853.69S 4803.14E 7430.16 3329.76 3264.86 77 56 S 60.51 E 2.41 2902.19S 4885.28E 7525.36 3352.54 3287.64 74 21 S 61.15 E 3.82 2947.24S 4965.97E 7620.25 3380.96 3316.06 70 46 S 61.17 E 3.77 2990.90S 5045.26E 7711.30 3413.28 3348.38 67 38 S 58.96 E 4.13 3033.35S 5119.02E 7807.20 3451.50 3386.60 65 22 S 58.80 E 2.37 3078.80S 5194.30E 7903.08 3492.88 3427.98 63 29 S 58.10 E 2.07 3124.04S 5268.00E 7997.74 3536.49 3471.59 61 39 S 61.19 E 3.49' 3166.51S 5340.47E 8093.67 3584.24 3519.34 58 39 S 64.03 E 4.05 3204.80S 5414.31E 8188.96 3636.64 3571.74 54 37 S 62.48 E 4.44 3240.59S 5485.37E 8284.80 3694.15 3629.25 51 37 S 63.58 E 3.25 3275~37S 5553.69E 8379.90 3754.90 3690.00 48 57 S 63.63 E 2.82 3307.89S. 5619.21E 8474.47 3818.99 3754.09 45 42 S 64.37 E 3.47 3338.37S 5681.70E 8571.52 3887.26 3822.36 44 52 S 62.76 E 1.46 3369.07S 5743.45E 8666.89 3955.16 3890.26 44 20 S 61.14 E 1.31 3400.56S 5802.56E 8761.66 4022.70 3957.80 44 45 S 61.95 E .73 3432.23S 5861.01E 8856.62 4090.41 4025.51 44 16 S 63.49 E 1.24 3462.75S 5920.17E 8950.92 4157.94 4093.04 44 15 S 61.75 E 1.29 3493.01S 5978.61E 9046.24 4226.32 4161.42 44 4 S 63.11 E 1.01 3523.75S 6037.47E 9141.21 4294.86 4229.96 43 32 S 63.63 E .67 3553.21S 6096.23E 9216.25 4349.36 4284.46 43 17 S 63.12 E .57 3576.33S 6142.34E 9275.00 4392.12 4327.22 43 17 S 63.12 E .00 3594.54S 6178.28E VERT. SECT. 4741.69 4835.06 4928.28 5022.99 5115.16 5210.12 5304.02 5396.28 5491.19 5586.80 5682.19 5774.59 5865.08 5950.18 6038.10 6124.56 6208.56 6291.63 6371.04 6447.56 6520.54 6589.86 6658.67 6725.58 6792.03 6858.50 6924.22 6990.55 7056.15 7107.61 7147.83 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM cURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7147.86 FEET AT SOUTH 59 DEG. 48 MIN. EAST AT MD = 9275 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 120.35 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 9,275.00' MD RY-SUN DRILLING SERVICES~-~ ANCHORAGE ALASKA SILARED~.'SERVICES DRILLING MPU / MPH-08 500292280800 NORTH./SLOPE' BOROUGH ~cOMpUTATION DATE: 10/ 4/97 DATE OF SURVEY: 092897 JOB NUMBER: AK-MM-70279 KELLY .BUSHING ELEV. = 64.90 OPERATOR: BP EXPLOR3kTION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH .. '.'~ TRUE SUB- SEA ~'MEASDi· ~ERTI'cAL VERTICAL ~"DEPTH.' '!".~D'~i~'TH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION ;'::d 0'. :i' ,., ,' ..ii100 -64.90 .00 N .00 E .00 20602~:00."i866~6 1801.76 272.66 S 473.08 E 133.34 128.32 3060f00..2'~46,'411 2381.51 679.21 S 1161.78 E 553.59 420.26 40002:00 2674~'i6 2609.26 1171.88 S 2000.10 E 1325.84 772.25 5000'00 2864"5'0 2799.60 1635.73 S 2865 11 E 2135.50 809.66 6000 '00 3057~i~79 2992.89 2141.94 S 3705.25 E 2942.21 806.72 7000.0'0 32491~12'5 3184.35 2680.95 S 4525.35 E 3750.75 808.54 8000.00 3537 57 3472.67 3167.47 S 5342.21 E 4462.43 711.68 9000.00 4'193'10 4128.20 3509.20 S 6008.79 E 4806.90 344.47 9275.00 4392.12 4327.22 3594.54 S 6178 28 E. 4882.88 75.98 THE CALCULATION PROCEDURES ~ BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. PAGE FT. S~P. SERVICES, DRILLING MPU '/ MPH-08 5.00292280800 . NORTH 'SLOPE BOROUGH COMPUTATION DATE: ?ERRY-SUN DRILLING SERVI~.-~ ANCHORAGE ALASKA PAGE 10/ 4/97 DATE OF SURVEY: 092897 JOB NUMBER: A,K-MM-70279 KELLY BUSHING ELEV. = 64.90 FT. OPERATOR: BP EXPLORATION .,,INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH '- ' . TRUE SUB- SEA . . . ' MEASD-. VERTI~AL VERTICAL ''DEPTH-~'; '.:'D~'PTH?" ,'. DEPTH · ? '~ ' '" ~"'~.:~"'~i~'/,"":"~i" '" ° oo ... 565.37 665.72 766.26 867.26 ,~.664:;:.90 ".,'.,?.600 O0 864 -,.:90 "" ',~1'800. O0 964 '~0 ~,;;,900.00 1064.90. 1000.00 1164 ,'~90,.?..:~'1100 O0 1264 ;i'gQ :'),._,.12 O0. O0 1364.90 1300.00 969.10 1072.41 1177.44 1285.07 1396.36 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 N .00 E .00 N .00 E .06 N .03 E .47 N .71 E 1.84 S 3.19 E .O0 .00 .00 .00 .00 .01 .01 .08 .07 5.90 S 7.28 E 10.87 S 11.83 E 16.45 S 17.91 E 23.39 S 25.70 E 33.43 S 35.50 E .24 .17 .47 .23 .82 .35 1.36 .55 2.36 1.00 46.62 S 49.43 E 4.20 1.84 62.23 S 70.04 E 7.51 3.31 78.76 S 97.50 E 12.54 5.03 97.07 S 132.75 E 20.17 7.63 119.33 S 176.15 E 31.46 11.29 1511.00 1464.90 1400.00 1629.69 1564.90 1500.00 1750.26 1664.90 1600.00 1872.82 1764.90 1700.00 1997.76 1864.90 1800.00 143.61 S 226.62 E 172.08 S 283.83 E 202.24 S 344.06 E 233.80 S 407.50 E 271.92 S 471.91 E 46.10 14.64 64.79 18.69 85.36 20.58 107.92 22.56 132.86 24.94 2129.18 1964.90 1900.00 2270.80 2064.90' 2000.00 2425.19 2164.90 2100.00 2595.12 2264.90 2200.00 2794.55 2364.90 2300.00 317.76 S 543.74 E 368.14 S 630.37 E 426.55 S 732.41 E 495.35 S 851.25 E 583.27 S 999.54 E 164.28 31.42 205.90 41.62 260.29 54.40 330.22 69.93 429.65 99.43 3056.80 2464.90 2400.00 3440.52 2564.90 2500.00 3951.66 2664.90 2600.00 4470.93 2764.90 2700.00 5001.87 2864.90 2800.00 706.15 S 893.49 S 1149.06 S 1387.12 S 1636.64 S 1208.24 E 591.90 162.25 1527.53 E 875.62 283.71 1958.51 E 1286.76 411.15 2408.95 E 1706.03 419.27 2866.69 E 2136.97 430.94 5519.73 2964.90 2900.00 6037.28 3064.90 3000.00 6545.81 3164.90 3100.00 7089'.34 3264.90 3200.00 7568.86 3364.90 3300.00 1892.33 S 3305.73 E 2554.83 417.86 2162.07 S 3735.81 E 2972.38 417.56 2434.79 S 4153.17 E 3380.91 408.53 2728.57 S 4599.30 E 3824.44 443.53 2967.36 S 5002.50 E 4203.96 379.52 RRY-SUN DRILLING SERVICE ANCHORAGE ALASKA ::/MEASD '":,VE~ I,CAL],: :V.E, RTI CAL ':783~,.':347 3464'[:~90' '?.3.400'. 00 :8~395:':(02,~).' :376'A:?.0:~.;~3700 O0 8539' 96:/ '3864':90-;'.,'~3800. O0 DATE OF SLTRVEY: 092897 PAGE JOB NUMBER: AK-MM-70279 KELLY BUSHING ELEV. = 64.90 FT. OPERATOR: BP EXPLORATION · : :. :~!.:?INTERPOLATED-V~LUES FOR EVEN 100 FEET OF SUB-SEA DEPTH : ~;"~' ' ",I:. ... i~ '. ~' - ,.;,; '-; ' r; . ,- . ~:.~.~.~ ~, ;,.,; :~ :! . . :( ',/i: :: {,.,~,~!~:. ;:.~:;':,,T. RUE suBJsEA TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4374.44 170.48 4490.92 116.48 4571.97 81.05 4630.12 58.15 4675.06 44.94 3093.94 S 5219.29 E 3190.25 S 5385.21 E 3258.30 S 5519.77 E - 3312.91 S 5629.38 E 3358.88 S 5723.66 E 8680;51 3964.9.0 "3900.00 3405.15 S 5810.90 E 8820.99 4064.'90 ' 4000.00 3451.64 S 5897.91 E 8960.64 4164;90 4100.00 3496.22 S 5984.59 E 9099.88 4264.90 4200.00 3540.57 S 6070.73 E 9237.60 4364.90 4300.00 3582.95 S 6155.40 E 4715.61 40.55 4756.09 40.48 4795.74 39.65 4834.98 39.24 4872.70 37.72 9260.00 4381.20 4316.30 3589.89 S 6169.10 E 4878.80 6.10 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: Jim Spearman FROM: Jim Fox DATE: 06/13/98 RE: MPU H-08 'OA' SAND DATA FFIAC, SCOUR, AND FRAC SERVICE CO'S.: Dowell, Halliburton, Nabors, and Peak JOB SUMMARY 54,900 lbs. of 12-20 Ottawa sand proppant coated with Halliburton PropLok resin was placed behind pipe in the OA Sand before screening out. Treating pressures stayed constant through to the end of design so an additional 50% excess was pumped. The wellbore screened out with 8 ppg slurry on the perfs just before going to flush. Of the 74,600 lbs. of proppant pumped 19,700 lbs. was left in the wellbore. From the start there was a moderate amount (220 psi) NWFP. Unsuccessfully a 50 bbl. gel sweep was displaced into the formation in an attempt to reduce this NWFP. A scour consisting of: 25 bbl. gel pad, 50 bbl 1 ppg slurry, and 25 bbl. gel sweep was over displaced by 5 bbls. This managed to reduce the NWFP from 170 to 130 psi. In comparison, 60 psi of NWFP was lost during the data frac. Friction pressure in the tubing was higher than usual in this well due to the tubing length and the use of the PH6 tubing with a slightly smaller ID (2.75" as compared to regular 9.3 ppf tbg. w/2.992"). Notes: · The proppant was coated with Halliburton PropLok resin at a treating rate of 3/8 gal. / 100 lbs. The resin was not dyed as in some wells in the past as the dye was suspected of contributing to reduction of resin coating of proppant. · 12-20 Ottawa sand was used due to it's ability to coat with resin better than Carbolite, it's angularity aides in not being produced back into the wellbore, and is lower cost. · Due to breakup all gel was premixed at 60 ppt HEC on A Pad in 100 bbl. loads, transported to frac tanks on site, and heated with hot oil unit to 90 deg. It was heated to assure good coating with resin. Requested that gel be heated to 90 deg but was apparently a little warmer on top than on bottom. Two 100 bbl. loads of 80 deg. gel was added to the tanks prior to the scour and one prior to the frac. · During the injectivity test and data frac the gel was circulated to the end of the tubing, bullheaded at 2 bpm (matrix rate) to the perfs and shut in for a couple minutes before coming up to rate. The scour and frac were bullheaded from the start. · A Petredat memory pressure / temp. gauge was set in a GLM near the bottom of the frac string (8439' md), Initially it was intended to get a SBHP (rather than with E-Line) with a secondary purpose of getting downhole pressure data during the frac. As it turned out the gauge was still on I hour samples when the gauge got on depth and on into the circulation of the gel for the injectivity test so there will be only a couple data points. The temperature is primarily used to correct the pressure reading and is the temperature of the gauge itself and not necessarily the fluid in the tubing. 08/10/98 11:03 AM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL ...... PUMPING~UMMARY TIME RATE ANNP WHP STAGE BPM PSIG PSIG BBL CUM COMMENTS BBL INJECTIVITY TEST Design Rate, Bbls Max Rate, Final lAP psi ISIP, NWFP Treat grad, BPM Pumped bpm psi friction, psi psi/ft max. 100 & 5 25 1106 890 220 0.73 bbl. wtr DATA FRAC Bbls Bbls gel to Time gel on Final lAP ISIP, psi NWFP Treat grad, Pumped Perfs perfs STP, psi friction, psi psi/ft 200 150 & 5 wtr. 10. min. 1077 915 160 0.72 SCOUR Rate, Slurry Pumped Sand Final lAP psi ISIP, NWFP Treat grad, BPM pumped psi friction, psi psi/ft 20 50 bbl. @ 1 ppg 2200 lbs, 1053 918 135 0.72 FRAC Sand Lead prop Tail prop Design total Tresaver pumped, behind pipe, behind behind pipe, Liner Sand, rubber left in Job was lbs. lbs. pipe, M# lbs. M# hole? /size /size screened out 74,600 54880 not appl. 75,000 19,700 not appl. 12/20 DATE/TIME OPERATIONS SUMMARY 06/13/98 0145 Pre-job safety meeting 0225 Pressure test surface equipment to 9100 psi 0231 Start circulating gel down tubing for injectivity test. 0252 Start displacing gel for injectivity test. 0256 Slow rate down to 20 bpm. 0257 S/D pumps and monitor pressure falloff. 0328 Start circulating in gel for data frac. 0348 Start displacing gel for data frac. 0358 S/D pumps and monitor pressure falloff. 0445 Start pumping 50 bbl. gel sweep. 0452 S/D pumps and monitor pressure falloff. 0515 Start pumping scour. 0525 S/D pumps and monitor pressure falloff. 0738 Start pumping pad for frac. 0808 Wellbore screened out. S/D pump and prepare to reverse out. PUMPING SUMMARY TIME RATE ANNP WHP STAGE CUM COMMENTS BPM PSIG PSIG BBL BBL 06/11/98 INJECTIVITY TEST DISPLACEMENT = 80.9 BBLS 0231.5 0 / 8 0 0 0 0 Prepare to start circulating the 100 bbl. 70 ppt HEC gel pad down to the end of the tubing. 0233 8.0 153 1716 10 10 At rate. 0237 8.0 150 1876 44 44 0239 8 / 2 150 1981 60 60 Reduce rate to 2 bpm. Pod temp. = 71 deg. 0241.5 2.0 920 1903 65 65 0244 2.0 934 1926 70 70 0247 2.0 943 1931 76 76 0249.5 2 / 0 974 1995 80 80 W/gel on perfs S/D pumps to allow pressures to stabilize. 0252 0 / max. 473 585 81.0 81.0 Start injecting gel into perfs for injectivity test. 0253 24 1232 5268 96 96 0253.5 25.1 1210 5208 100 / 0 100 Switch to water for displacement. 0255 25.1 1174 5100 40 140 0256 24.5/20 1145 5282 66 166 0257 20 / 0 1106 5140 86.8 186.8 With 5 bbls. overdisplacement S/D pumps and monitor pressure falloff. ISIP - 890 psi, NWFP -- 216 psig. .0258 0 810 910 0300 0 766 887 '" PUMPING SUMMARY :'-~J TIME RATE ANNP WHP STAGE CUM COMMENTS BPM PSIG PSIG BBL BBL 0305 0 704 832 0310 0 659 777 0320 0 614 727 DATA FRAC 0328 0 / 8 14 118 0 186.8 Start circulating in 200 bbls. of 70 ppt. HEC gel pad. 0331 8 160 1624 216 0334 8 160 1766 52 239 0335 8 / 2 160 1606 62 249 Slow down to 2 bpm and SI annulus. 0336 2 936 1784 251 0340 2.0 965 1858 258 0342 2.2 955 1858 262 0344 2.0 ! 0 937 1862 267.0 S/D pumps and allow pressures to stabilize. 0348 0 ! 20 708 777 267.0 Prepare to start pumping data frac. 0348 + 20 1164 4471 273 At rate. 0350 20.1 1148 4408 315 0353 20.1 1120 4279 372 0354 19.9 1116 4288 200 ! 0 387 Switch to water. 0356 20.1 1096 5034 430 0358 20 ! 0 1077 6250 85 471.8 S/D pumps. Monitor pressure falloff. ISIP: 915, NWFP = 162 psi. 0400 0 832 942 0405 0 801 901 0410 0 775 869 0420 0 748 828 0430 0 731 809 0440 0 717 786 SWEEP 0445 0 / 20 728 773 0 471.8 Start pumping 50 bbl. gel pad. 0446 20 1102 6504 12 484 At design rate. 0448 20.4 1051 5089 50 / 0 522 Switch to water for flush. 0450 20.1 1047 4660 48 570 0451 19.7 1094 5492 68 590 0452 20 / 0 1091 5600 86 608 Overdisplace gel by 5 bbl. ISlP = 920, NWFP = 171 psi. 0455 0 798 878 0500 0 765 841 0510 0 726 791 ~-' PUMPING SUMMARY "'-t' TIME RATE ANNP WHP STAGE CUM COMMENTS BPM PSIG PSIG BBL BBL !0515 0 716 796 SCOUR 0515 0 / 20 717 805 0 608.0 Prepare to start scour treatment. 516.5 20 1106 6591 11 619 At design rate of 20 bpm. 0517 19.9 1062 5767 24 / 0 632 ! ppg starting down hole. 0519.7 19.2 1036 4073 55 / 0 687 Switch to gel & gel on perfs 0521 20.1 1064 4160 26 / 0 713 Start water flush and sand on perfs. 0522 20.2 1091 4160 17 730 0523+ 19.9 1076 4865 50 763 Sand through perfs. 0525 20 / 0 1053 5694 85.5 763 With 4 bbls overdisplacement shut down pumps. ISIP = 918, NWFP = 135 psi 0527 0 832 910 0530 0 810 883 0535 0 788 860 0540 0 775 841 0548 0 765 828 FRAC 0738 0 / 20 688 759 0 0 Start pumping 70 ppt. HEC gel pad for frac. 0739 20 1094 6508 9 9 At rate. 0740 20.2 1038 5700 34 34 0742.5 19.9 1012 4169 81 81 Gel on perfs. 0744 19.9 1065 4220 109 109 Pod temperature = 70 deg. 0747 20.1 1067 4142 160/0 160 Sand slurry starting down hole. 0749 20.1 1059 4080 50 210 0750.5 20.1 1050 4078 81 241 1 ppg slurry starting on perfs. 0752 20.1 1059 4050 109 269 0754 19.9 1047 4192 313 2 ppg slurry starting on perfs 0755 20.1 1039 4215 337 3 ppg slurry starting on peris 0756.5 20.1 1030 4531 361 4 ppg slurry starting on perfs 0758 20.3 1027 4778 385 5 ppg slurry starting on perfs 0759 19.9 1029 4966 409 6 ppg slurry starting on peris 0801.5 19.9 1050 5176 456 7 ppg slurry starting on perfs 0804 20.1 1061 5245 505 8 ppg slurry starting on perfs 0805 20.1 1061 5218 528 0806.5 20.1 1090 5218 563 0807.5 19.9 1134 5236 578 0808 19.0 / 0 2898 5616 587.9 Screened out, S/D pumps, prepare to reverse out. Page 6 FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 763 Bbls FRAC: 588 Bbls 1351 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME PETREDAT WINDOW Pressure measurements - 60 hrs @ 15 sec intervals starting 6/13 @ 0300 FLUID ADDITIVES 70 ppt. HEC gel: filtered seawater for make up water (no KCI added) 2.9 #/bbl Dowell HEC gel 2 gal/1000 F-75N (surfactant) run only in Injectivity Test and Data Frac Halliburton surfactant - run through frac Fluid QC was more complicated that usual in that the gel had to be mixed in 100 bbl. batches (due to breakup gel is being built by Baroid on A Pad). Viscosities when mixed varied f/125 to 135 at temperatures of approx. 80 deg. F. With a target pH of 6.5 citric acid was used to achieve a range of 5.8 to 6.2. A turbidity measurements was made on frac gel (batch # 15 ) with a reading of 205. Filtered seawater was coming in at 1.3 to 4.2 NTU. Once gel was on site in the frac tanks the gel was heated to 100 deg. with hot oil unit (temperature going through coils was limited to 165 deg. to avoid gel degradation). The temperature when measured in the two tanks were up to 138 deg. in one and 87 in the other. The tanks were equalized when pumping gel in hopes of averaging out the temperatures. Heating gel while circulating gel after it is mixed is not efficient as the gel tends to channel through the tank. This is further complicated by the fact that with the extra gel required for the scour an extra 200 bbl. of unheated (80 deg.) gel was added to one of the tanks just before the frac. Fann 300 readings of the fluid in the tanks were 70 at 138 deg. and 129 @ 87 deg. with pH at 5.82 and 5.66. BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: Jim Spearman FROM: Jim Fox DATE: 06/11/98 RE: MPU H-08 'OB' SAND DATA FRAC, SCOUR, AND FRAC SERVICE CO'S.: Dowell, Halliburton, Nabors, and Peak II JOB SUMMARY 24,300 lbs. of 12-20 Ottawa sand proppant coated with Halliburton PropLok resin was placed behind pipe in the OB Sand before screening out. There was a slight net pressure build as pad reached the perforation and then a couple quick small increases in pressure as the 5 ppg to 6 ppg slurry hit perfs. This was followed by what appeared to be a screen out and flush was requested. Shortly thereafter the pressure broke back 200 psi and stabilized momentarily before starting to build again. With 38 bbls of flush pumped and 6 ppg. on perfs the wellbore screened out and pumps were slowed down and eventually shut down. Of the 33,640 lbs. of proppant pumped 9370 was left in the wellbore. From the start there was high (300 psi) NWFP. A scour consisting of: 73 bbl. gel, 25 bbl 1 ppg slurry, 25 bbl. 2 ppg slurry, and 50 bbl. gel sweep was over displaced by 5 bbls. This managed to reduce the NWFP by approx. 50 psi but at 210 psi it was still higher than hoped for. 40 psi of NWFP was lost during the data frac without the use of sand. Friction pressure in the tubing was higher than usual in this well due to the tubing length and the use of the PH6 tubing with a slightly smaller ID (2.75" as compared to regular 9.3 ppf tbg. w/2.992"). Late in the displacement of the injectivity test the rate had to be decreased as the pressure to which the surface lines had been tested to prior to the operation was approached. Prior to the data frac the surface treating lines were re-pressure tested to 8750 psi for steps to follow. Notes: · The proppant was coated with Halliburton PropLok resin at a treating rate of 3/8 gal. / 100 lbs. The resin was not dyed as in some wells in the past as the dye was suspected of contributing to reduction of resin coating of proppant. · 12-20 Ottawa sand was used due to it's ability to coat with resin better than Carbolite, it's angularity aides in not being produced back into the wellbore, and is lower cost. · Sand concentration during scour increased to as high as 2.6 ppg at the end of the slurry. · Due to breakup all gel was premixed at 60 ppt HEC on A Pad in 100 bbl. loads, transported to frac tanks on site, and heated with hot oil unit to 110 deg. It was heated to assure good coating with resin. Requested that gel be heated to 100 deg but was apparently a little warmer on top than on bottom. One 100 bbl. load of 80 deg. gel was added to the tanks prior to the scour and one prior to the frac. · Data frac gel volume was reduced from a design of 200 bbl. to 150 bbl. in order to conserve limited gel volume for the scour and frac. · During the injectivity test and data frac the gel was circulated to the end of the tubing, bullheaded at 2 bpm (matrix rate) to the perfs and shut in for a couple minutes before coming up to rate. The scour and frac were bullheaded from the start. 08/10/98 11:01 AM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL .... PUMPING'-',SUMMARY TIME RATE ANNP WHP STAGE CUM BPM PSIG PSIG BBL BBL COMMENTS INJECTIVITY TEST Design Rate, Bbls Max Rate, Final lAP psi ISIP, NWFP Treat grad, BPM Pumped bpm psi friction, psi psi/ft max. 101 25 1154 850 300 0.66 DATA FRAC Bbls Bbls gel to Time gel on Final lAP ISIP, psi NWFP Treat grad, Pumped Perfs perfs STP, psi friction, psi psi/ft 150 150 & 5 wtr. 8:0 1146 890 260 0.67 SCOUR Rate, Slurry Pumped Sand Final lAP psi ISIP, NWFP Treat grad, BPM pumped psi friction, psi psi/ft 20 25 bbl. @ 1 ppg 2650 lbs, 1090 880 210 0.67 25 bbl. @ 2 ppg FRAC Sand Lead prop Tail prop Design total Tresaver pumped, behind pipe, behind behind pipe, Liner Sand, rubber left in Job was lbs. lbs. pipe, M# lbs. M# hole? /size /size screened out 33,640 24,260 not appl. 100,000 9380 not appl. 12/20 DATE/TIME OPERATIONS SUMMARY 06/11/98 1130 Pre-job safety meeting 1230 Pressure test surface equipment to 6600 psi 1332 Start circulating gel down tubing for injectivity test. :1350 Start displacing gel for injectivity test. 1354 Slow rate down to 20 bpm. 1355 S/D pumps and monitor pressure falloff. 1418 Re pressure test surface equipment to 8750 psig. 1426 Start circulating in gel for data frac. 1446 Start displacing gel for data frac. 1454 S/D pumps and monitor pressure falloff. 1605 Start pumping scour. 1618 S/D pumps and monitor pressure falloff. 1731 Start pumping pad for frac. 1749 Wellbore screened out. S/D pump and prepare to reverse out. PUMPING SUMMARY TIME RATE ANNP WHP STAGE, CUM , COMMENTS BPM PSIG PSIG BBL IIBBL 06/11/98 INJECTIVITY TEST DISPLACEMENT = 80.9 BBLS 1332 0 / 8 0 0 0 0 Start circulating 100 bbl. 60 ppt HEC down tubing. 1333 8 11 1637 5 5 @ rate, taking returns to pits 1335 8.2 9 1641 22 22 1338 8.0 11 1632 46 46 1340 8 / 2 9 1586 65 65 Slow down to 2 bpm and SI annulus. 1342 2.0 1027 1756 68 68 injecting in formation at matrix rate to get gel to perfs. 1344 2.0 1167 1884 73 73 1348 2.0 / 0 1253 1980 81.0 81.0 S/D and left pressures satbilze. 1350 0 / max. 711 799 81.0 81.0 Come up to max. rate. 1352 22.3 1369 5193 101 / 0 101 Switch to seawater. 1353 25.3 1320 5290 25 126 1354 20 1221 5300 50 151 Slow down to 20 bpm as per design. 1354.5 18.5 1213 5340 64 165 Continue to slow down rate due to pressure restrictions. 1355 15 / 0 1158 4653 87 188.1 S/D pump and monitor pressure falloff. 1357 0 769 872 1400 0 690 799 1405 0 597 707 1410 0 516 671 ' " PUMPING SUMMARY .... TIME RATE ANNP WHP STAGE CUM COMMENTS BPM PSIG PSIG BBL BBL 1415 0 464 DATA FRAC 1426 0 / 8 0 94 0 188.1 Start circulating gel down to tubing tail at 8 bpm taking returns to the pits. 1427 8 11 1540 5 193 At rate. 1429 8.2 11 1504 20 208 1431 8.2 11 1486 220 1434.5 8 / 2 12 1499 62 250 Slow down rate to 2 bpm and shut in annulus. Bullhead gel to the perfs at matrix rates. 1436 2.0 1100 1582 65 253 1438.5 2.0 1145 1627 259 1443 2 / 0 1149 1591 81.1 269.2 With gel at perfs S/D pumping and allow pressure to stabilize 1446 0 / 20 737 790 81.1 269.2 Start displacement of data frac. 1446.5 20 1270 5102 276 At rate. 1448 20.2 1222 5134 297 1450 20.4 1177 4612 150 338 Switch to water for displacement. 1452 19.7 1167 5190 378 1453 19.7 1157 5990 404 1454.5 20 / 0 1146 6805 85.7 423.1 S/D pumps and monitor pressure falloff. 1456 0 817 904 1500 0 768 858 1505 0 719 808 1510 0 672 762 1520 0 591 666 1530 0 519 593 1538 0 470 547 SCOUR 1605 0 / 20 339 428 0 423 Prepare to start pumping gel pad 1606 20 1145 2066 17 440 At rate. 1609.5 20.4 1093 4328 73 / 0 496 1 ppg starting downhole. 1610 19.9 1126 3816 95 518 1611 19.9 1140 3906 108 531 2 ppg starting downhole 1612 19.7 1135 3898 127 550 Flush starting downhole. 1613.5 20.1 1129 4218 154 577 Prop. on perfs. 1615 20.4 1129 4205 189 612 1616 20.1 1126 4590 205 628 1617 19.7 1096 5734 228 651 ..... PUMPING SUMMARY ~' TIME RATE ANNP WHP STAGE CUM COMMENTS BPM PSIG PSIG BBL BBL 618.5 19 / 0 1091 6612 257.5 680.5 S/D pumps ISIP - 880 psi, NWFP - 211 psi 2936 lbs. of sand pumped. 620 0 859 959 623 0 817 918 1731 0 470 556 0 0 Prepare to start. Gel temp. on top of tank = 90 deg. F. 1732.5 20.5 1132 6370 18.2 18 At design rate. 1734 20.1 1111 5371 50 50 1735 20.1 1106 3880 75 / 0 75 Sand at 1 ppg at surface. Pad (almost) at perfs. 1737 20.1 1131 3825 32 104 1738 19.9 1152 3834 52 127 1739.5 20.1 1158 3890 78 153 Prop. on perfs. 1741 19.9 1142 3990 187 2 ppg on perfs. 1742 19.6 1146 4095 204 3 ppg on perfs. 1743 20.1 1149 4232 227 4 ppg on perfs. 1744.5 19.7 1172 4296 252 5 ppg on perfs. 1746.5 19.9 1334 4571 291 6 ppg on perfs 1747 20.6 1770 5189 0 308 Flush starting down hole. 1748 20.4 1708 4992 21 329 1749 20 / 0 2463 3381 38 346 Wellbore screened out - S/D pumps. Prepare to reverse out. Page 6 FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 918 Bbls FRAC: 346 Bbls 1264 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME PETREDAT WINDOW NONE FLUID ADDITIVES 60 ppt. HEC gel: 2% KCI make up water 2.5 #/bbl Dowell HEC gel 2 gal/1000 F-75N (surfactant) run only in Injectivity Test and DataFRAC Halliburton surfactant - run through frac Fluid QC was more complicated that usual in that the gel had to be mixed in 100 bbl. batches (due to breakup gel is being built by Baroid on A Pad). Viscosities varied f/86 to 97 at temperatures of 76 to 82 deg. F. With a target pH of 6.5 citric acid was used to achieve a range of 6.0 to 6.5. Once gel was on site in the frac tanks the gel was heated to 100 deg. with hot oil unit (temperature going through coils was limited to 165 deg. to avoid gel degradation). The temperature when measured in the tank was up to 120 deg. apparently due difference in where the temperature was being measure. Circulating gel while heating is not efficient as the gel tends to channel through the tank. This is further complicated by the fact that with the extra gel required for the scour an extra 100 bbl. of unheated (80 deg.) gel was added to one of the tanks just before the frac. Fann 300 readings of the fluid in the tanks were 63 and 55 and pH at 5.25 and 5.5. A couple turbidity measurements were made on frac gel (batch # 3 and 7) with readings of 192 and 212. Filtered seawater was coming in at 1.3 to 4.2 NTU. Milne Point Unit, Alaska TO: Bixby / March FROM: Thackeray Well Name: IMp H-08 Main Category: I DRLG COMPL Sub Category: JEline Perf Operation Date: 16-12-98 Date: 16-13-98 Objective: E-line convey perforate the Schrader Bluff "CA" sands. Sequence of Events: RU Atlas MU Tools and guns on rollers PJSM P/T Lubricator to 500 psi Able to roll thru 80 degree hole to PBTD Make correlation pass to tie into MWD Icg 9/28/97 Depth correct. Drop back down and tag PBTD @ 8986' Position gun in "CA" interval Perforate "CA" sand from 8940-8960' with 4 ~,~" gun 4 spf Big Hole charges @ 0-180 phasing POOH. All shots fired RD Atlas Results: Perforated the Schrader Bluff "CA" sand from 8940-8960' (20') with 4 ~/~" guns with 4 Big Hole spf at 0-180 degree phasing. Tie in Icg/date: Sperry MWD 9/28/97 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter 18940 II8960 II4~/~ Shot Density Orientation Phasing Ci !::! ILI-- I I~ G S~I:tL~I C ~ S To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~)"1 MWD Formation Evaluation Logs - MPH-08, AK-MM-70279 October 28, 1998 MPH-08: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22808-00 2"x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22808-00 2" x 5" MD Neutron & Density Logs: 50-029-22808-00 2"x 5" TVD Neutron & Density Logs: 50-029-22808-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia PLEASE ACKNOWLEDGE RECEIFF BY SIGNING AND RETURNING THE ATYACHED COPIES OF THE TRANSMITTAL LE~ER TO THE ATYENTION OF: Sperry-Sun Drilling Services Atto: Ali Turker 5631 Silverado Way, Suite G. BP Exploration (Alaska) Inc. Petro-teehnieal Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A I"1, ...... i__--I.._t--.z__ l_- ~'~ ...... 0 F! I I--I.. I I%1 CS S I:: Ft ~./I C I~: S WELl, LOG TRANSMITT~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs October 28, 1998 1 LDWG formatted Disc with verification listing. API#: 50-029-22808-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THF. ATFACHF. D COPIES OF THE TRANSM1TFAL LE'ITER TO ~ ATYENTION OF: Sperry-Sun Drilling Services Atto: Ali Turker 5631 Silverado Way, Suite G. Anch~orage~da,ska 9~51.8 n,'.'t,T ? 8 ~"'~'"~ Date: ~~ge BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Sign 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A ~-,__ _ , , .... State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 12-Jun-98 Transmittal of Final Prints. Please sign and return copy to the following' Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 and BP Exploration (Alaska) Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 .~~G Name -13 G-13 Services Bluelines R/F Sepia SBT/GR/CCL 1 1 CCL/GR PERF, PACKER 1 1 MPH-13 CCL PERF 1 1 'MPH-13 CCL PERF 1 I Film /'M PH-13 GR/CCL DEPTH REF 1 I 4~PH-13 ¢5'---/3o /MPI-05 /~ I~---, INJ PROFILE STATIC PRESS SRVY 1 1 1 1 ~1~-- INJ PROFILE 1 1 ci"/. 2'~% /IVIPB-25 · fl~?. t8c¢ H-13 ~./~b /~MPH-08 ~?./2~ /I~PG-13 CCL PERF 1 1 GR/CCL PERF, PACKER 1 1 GR/CCL PERF 1 1 GR/CCL PERF Received by: ~ Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. TONY KNOWLES, GOVERNOR ~SI~A OIL AND GAS CONSERVATI ON COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 19, 1997 Chip Alvord Senior Drilling Engincer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re~ Milne Point Unit MPH-08 BPX Exploration (Alaska) Inc. Pcrmit No. 97-173 Sur. Loc: 2767'NSL. 4061'WEL. Scc. 34. TI3N. RIOE. UM Btmholc Loc: 4463'NSL. 3228'WEL. Scc. 1. T12N. RIOE. UM Dcar Mr. Alvord: Enclosed is the approvcd application for permit to drill thc above rcfercnccd well. Thc pcnnit to drill does not cxcmpt you from obtaining additional pcrmits rcquircd bx' law from other govcmmcntal agcncics, and docs not authorizc conducting drilling operations until all other requircd pcrmitting dctcrminations arc made. Blowout prcvcntion cquipmcnt (BOPE) must bc tcstcd in accordancc with 20 AAC 25.035. Sufficicnt notice (approximatcly 24 hours) of thc BOPE tcst pcrformcd bcforc drilling bclow the surfacc casing shoc must bc givcn so that a rcprcscntativc of thc Commission max' witncss thc tcst. Notice may be givcn bx' contacting thc Commission pctrolcum ficld inspcctor on thc North Slope pagcr at 659-3607. Chairman BY ORDER OF THE COMMISSION STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coM llSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill I--I Redrill Ilb. Type of well I--I Exploratory [] Stratigraphic Test [~ Development Oil [] Re-Entry [] DeepenI [] Service I'"'1 Development Gas []Single Zone r-I Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 65.5' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 380109 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2767' NSL, 4061' WEL, SEC. 34, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 4629' NSL, 3511' WEL, SEC. 1, T12N, R10E, UM MPH-08 At total depth 9. Approximate spud date Amount $200,000.00 4463' NSL, 3228' WEL, SEC. 1, T12N, R10E, UM 09/28/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025518, 817'I No Close Approach 2560 9251' MD / 4383' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 79.33° Maximum surface 1400 psig, At total depth (TVD) 4000' / 1800 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 8-1/2" 7" 26# L-80 BTC-Mod 9220' 31' 31' 9251' 4383' 868 sx PF 'E', 130 sx 'G', 100 sx PF 'C' 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 MD TVD Structural Conductor Surface Intermediate Liner Production SEp 1 2 ]997 Perforation depth: measured ~8 .~ Cji .& .Gas Cons, true vertical ' '- ~rl¢~.'_~ .~ 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Robertson, 564-5159 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipAIvord ~ ~-. ~ Title Senior Drilling Engineer Date .~11,1~)7 Commission Use Only Permit Number APl Number I Approval Date See cover letter ~',,~.../"7,./~ 50- 42~ ~- 2_..2. (~'O ~'I ~' -" / ~ --- ~'~ for other requirements Conditions of Approval: Samples Required []Yes [~No Mud Log Required []Yes Hydrogen Sulfide Measures []Yes'~No Directional Survey Required '[~Yes [] No Required Working Pressure for DOPE J~2M; []3M; []5M; []10M; []15M Other: dr~g~nal Signed By by order of 0avid W. Johnston Approved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: I Well Name: James E. Robertson IMPH'08 I Well Plan Summary IType of Well (producer or injector): SCHRADER BLUFF PRODUCER 564-5159 ISurface Location: Target Location: Bottom Hole Location: 2767 FSL, 4061 FEL, S34 T13N R10E UM 4629 FSL, 3511 FEL, S01 T12N R10E UM 4463 FSL, 3228 FEL, S01 T12N R10E UM I AFE Number: 1337092 Estimated Start Date: I 28 SEPT 97 I IUD: I I ITVD: Rig: I Nabors 22E Operating days to complete: 14,383' I 17.0 I KBE: I 65.5 ft I Well Design: Schrader Bluff Producer Formation Markers: Formation Tops MD TVDSS KOP Base of Permafrost 1890 1725 Top of Ugnu 7908 3392 Top M Sand 8439 3697 Top NA (Target) 8741 3926 Top of Schrader Bluff Sands (EMW 8.6 ppg) NB 8775 3952 NCND 8815 3983 NE 8837 4000 NF 8897 4046 OA 8939 4078 OA4 8980 4109 OB 9O2O 414O Top of Seabee 9051 4161 Base of Schrader Bluff Sands (EMW 8.3 ppg) TD 9251 4317 TD at 200' MD past base of Schrader Casing/Tubing Program: Hole ,~ize ' Csg~ Wt/Ft Grade Conn. Length Top Bottom Tbg O.D. MD/TVD MD/TVD (bkb) 24" 20" 91.1# H-40 Weld 80' 32'/32' 112' / 112' 8-1/2" 7" 26# L80 BTC-MOD 9220' 31 '/31' 9251' / 4383' Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/fi) to the reservoir at +4000' TVDSS, the maximum anticipated surface pressure assuming a reservoir pressure of 1800 psi (8.65 ppg EMW), is 1400 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: MWD from surface to TD LWD (GR/Resistivity/Neutron Density) from top of Ugnu to TD with a controlled drilling speed of no more than 200 ft/hr through the Ugnu and Schrader Bluff intervals from 7908' - 9251' MD. Cased Hole Logs: NONE Mudloggers are NOT required for this well. Mud Program: Spud Mud ISpecial design considerations I See "Drilling Hazards and Risks" section about dealing with the I possibility of hydrates SPUD TO TOP OF SCHRADER BLUFF: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 80 15 8 10 9 10-15 (initial) to to to to to to to 10.2 100 35 15 30 10 8-10 (final) TOP OF SCHRADER BLUFF TO TD: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 50 10 3 7 9.0 4 to to to to to to to 9.8 80 20 10 20 9.5 6 (as required) Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Line. A Completion/Workover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1300' MD IMaximum Hole Angle: Close Approach Well: 79'33° NONE Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A facility. Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection. Annular Injection: No wells on G-Pad have been permitted for annular injection. MP H-08 Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. N/U and function test 21-1/4" Hydril MSP 2M diverter system. Build Spud Mud. 5. Drill 8-1/2" surface hole as per directional plan to 9251' MD / 4383' TVD. Run Directional MWD from surface to TD and run LWD GR/Resistivity/Neutron Density from the top of the Ugnu to TD, or 7908' to 9251' MD. NOTE: Fill hole with mud and check diverter for leaks before spudding in. NOTE: Short trip no deeper than 300' md past the base of permafrost. NOTE: Utilize lubricants as necessary to enhance sliding performance. NOTE: The well will probably require two bits. Drill to the top of the Ugnu with the first bit, then POOH to change the bit, pick up the LWD tools, and trade out MWD tools. NOTE: Drill at a controlled rate of no more than 200 fi/hr through the Ugnu and Schrader Bluff sands to ensure good LWD readings. 6. At TD, make a wiper trip to the last bit trip depth and condition the hole, making sure to record any tight spots. 7. POOH and LD BHA. 8. Run and cement 7", 26#, L-80, BTC-Mod casing. Cement job will be performed in two (2) stages, as per the cement program, with an ES cementer set at least 200' MD below the permafrost. 9. N/D Diverter. N/U FMC Gen 6 Wellhead and Tree. Note that MPH-08 will have 2-7~8" tubing. RDMO Nabors 22E drilling rig to drill next well. (End of Nabors 22E operations) DRILLING HAZARDS AND RISKS: See the latest Milne Point H-Pad Data Sheet prepared by Pete Van Dusen for information on H pad. Particularly close attention should be paid to hydrate experiences on previous H-Pad wells. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. 1. Hydrates: HYDRATES WERE ENCOUNTERED ON THE WELLS RECENTLY DRILLED ON MILNE POINT 'H' PAD DURING THE SUMMER OF 1997. PLAN ON LECITHIN TREATMENT AS WELL AS WEIGHTING UP TO AN APPROPRIATE MUD WEIGHT TO MANAGE THE HYDRATES. 9.8 PPG WORKED ON MP H-14, MP H-10, H-11i, AND H-12 THROUGH THE HYDRATE ZONE. The cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to minimize the movement of hydrates into the wellbore. 2. Close Approach: There are no close approach problems with MP H-08. 3. Lost Circulation: Lost circulation has been experienced when drilling the Schrader sands and can be countered by having LCM on hand. MPH-05 experienced lost returns at 3708' TVDSS while drilling with heavy 11.5 ppg mud that was used to deal with hydrates. LCM should be kept on hand, particularly if the mud is weighted up to counteract gas cut mud due to hydrates. 4. Stuck Pipe Potential: No stuck pipe incidents have occurred on H Pad to date. If heavy gravels are encountered while drilling the surface hole section, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. The past few wells on Milne Point 'H' Pad have encountered severe tight hole problems; especially swabbing problems while POOH. A few changes will be noted in the mud discussion of the final wellplan as an effort to alleviate some of the tight hole/packing off problems. 5. Formation Pressure: The expected pore pressure for this well is 8.6 ppg EMW in the Schrader Bluff NA and NB sands, and 8.3 ppg EMW at TD just past the OB sands. 6. Directional Drillinq Concerns Due to the relatively shallow depth of the Schrader Bluff wells and the large stepouts, some directional drilling will have to be done in the permafrost. Note that care must be taken when drilling through the base of the permafrost as severe doglegs may develop. 7. Cement Because of the single casing string, the cement jobs will be critical to the success of the Schrader wells. Also, the relatively small 8-1/2" by 7" annulus will require extra attention to pump rates and pressures. Ensure that copies of all of the strip charts from the cement job are sent to the Operations Drilling Engineer. Plan on using a 'C' cement for the second stage tail cement due to probability of hydrates. MP H-08 7" SURFACE/PRODUCTION CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 7" CIRC. TEMP: ~ 80°F SPACER: 50 BBL Weighted Spacer (Weighted to TD mudweight). STAGE1 LEAD: TYPE 'E' PERMAFROST ADDITIVES: WEIGHT: APPROX #SACKS: FLOCELE (0.25 #/sk) 12.0 ppg YIELD: 2.17 ft3/sk MIX WATER: 11.63 gal/sk 512 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM THE TOP OF THE STAGE1 TAIL AT 7938' MD TO THE ES CEMENTER STAGE TOOL (2100' MD > 200' MD BELOW BASE OF PERMAFROST) + 50% EXCESS. STAGE1 TAIL CEMENT TYPE: ADDITIVES: WEIGHT: APPROX #SACKS: FLUID LOSS: PREMIUM SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%), CBL (0.1 #/sk), FLOCELE (0.1 #/sk) 13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk 130 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 0-55 cc/30 mins @ 80°F FREE WATER: TAIL CEMENT FROM TD (9251' MD) TO 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (8438' MD) + 50% EXCESS + 80' OF 7" 26# CASING CAPACITY FOR SHOE TRACK. EST TOC 7938' MD SPACER: 50 BBL Weighted Spacer (To weight of mud circulated before pumping Stage2). STAGE2 LEAD: TYPE 'E' PERMAFROST ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 356 SACKS YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM TOP OF STAGE2 TAIL AT 1525' MD TO SURFACE +300% EXCESS. STAGE2 TAIL: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'C' PERMAFROST Retarder 15.6 ppg 100 SACKS YIELD:0.95 ft3/sk MIX WATER: 3.60 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. 575' OF ANNULAR VOLUME AT 30% EXCESS FROM ES CEMENTER AT 2100' MD. EST TOP 'C' 1525' MD WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 7-1/8" x 8-1/4" Rigid Straight Blade Centralizers - one (1) per joint on the bottom twenty-three (23) joints of 7" casing. Run two centralizers on the bottom joint of casing and on the top centralized joint of casing as well. (23+2 = 25 Rigid Straight Blade Centralizers). 2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. OTHER CONSIDERATIONS: Perform any necessary laboratory tests on samples of the water to be used in the cement job to ensure that it is adequate. Also 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 8.0-10.0 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the fly -- batch mixing is not necessary. DISPLACEMENT OF CEMENT: Because Nabors 22E will be moving off of the well after the cement job, displacement fluid is an important consideration as the fluid will be left in the hole for some time. The proposed displacement procedure is as follows: 1. Pump away first stage as per the detailed cement program and displace with seawater a volume equal to the capacity of the 7" casing from TD up to the ES Cementer at 2100' md followed by mud weighted to the weight used to drill the hydrate section of the hole. 2. After bumping the plug, quickly check to ensure that the floats are holding and then shear the ES cementer to the open position. 3. Circulate the weighted mud through the ES cementer for two hours to clean and condition contaminated cement. 4. Pump the second stage as per the detailed cement program. When cement returns are seen at surface, drop the second stage plug and displace with diesel. The completion rig will recover the diesel freeze protection fluid for reuse on another well. Anadr£LL Se hlun~ez~e r Alaska Dlstr Lct 1121 Hast 80th Avenue Anchorage, AK 99518 (907} 349-4511 Fax 344-2L60 WelL. MPH-08 (P2) Pield ..... '...: MILES 'P01NT, HPAD Computation..: Minimum Curvature Units ........ =,t:r'~ Surface Lat..: 70.13774751 ~ Surface Long,: 149.53863001 W DIRHCT£ONAh WELL PLAI~ for $~ARCD SERVICES DRILblN~ ~egal Oeacri@tio~ Surface ...... : 2767 FS~ 4062 PHL S~4 T13N R[0H ~M TA~G~T ....... : 4629 F~ 3511 P~L SOL T12N ~I~H UM BHL .......... : '4463 FS~ 3228 FHL S0~ T12N RLOH UM A/~KA Zone: 4 X-~oord ¥-Coord 556584.41 6009918.79 562442.00 6006548.00 ~62~26.49 6006304.29 STAT~0N M~A~U~HD ~NCLN 1 D~T! P£CATION. DH~TH K~ 0.00 O.00 ~P/BUZ~ ~.5/~OO 300,00 0.00 400.00 SUILO 2/~00 ,500:00' .3.00 600.00 5.00 PROPOSED WKLL PRO~IL~ DI~BCT£ON V~RT2 CAL AZ£MUTH TVD 0.00 0,00 -65 .SO 0.00 300,00 ~:34.50 ~20 .'35 399,99 3:34.49 220,35 499.91. ~34,4L 120.35 5~9.66 ~34.1.6 Prepared ..... : 01 JuL 1997 Vert aect az.~ 120.35 KS elevation.: 65.50 ft Magnetic Ik:l~: +27-991 (E) Scale Factor.: 0,99990364 .................. AKA-DPC APPROVED FOR PERMITTING ONLY ~OORD~NATHS-FRO~ ALASKA Zone 4 TOOL D~/ ~h~ X Y PA~ 100 0.00 N 0.00 H 556564.41 6009918.~9 H9 0.00 ~.0~ N 0.00 H ~56564.41 6009918.~9 120R 0-00 0.66 S 1.1~ H 556~85.54 6009918.L4 120R L.60 2-6~ S 4,~2 H ~56~88.95 60~9916.18 ~2~ L.50 6.17 S 10.54 H ~6594.99 60099L2170 120R 2.00 2.5/200 700.00 7.00 800.00 9.50 900.00 L2.00 1000.00 L4.50 1300.00 .LT.00 220.35 699.LL 633.6L 120.35 798.06 732.56 120,35 896.30 830.80 ~20.35 993.63 928,L3 120.35 L089.87 1024.37 22,66 37,01 55.66 78.58 105.72 L~.45 S 19,56 H 556604.05 6009905.49 HS 2.00 L8.70 S 31,94 H 556616.49 6009900.33 HS 2.50 28.13 S 48,03 H 556632.65 600989L.03 RS 2.50 39.71 S 67.8L H 556652.5/ 6009879.60 HS 2,50 53.42 $ 91.23 ~ 556676.03 6009856.06 HS 2.50 1200.00 19.S0 1300,00 22.00 120.35 L~84.83 11L9.33 137.04 120.36 L278.3t 12L2.8~ 172.46 69,25 $ 118,25 E 556703.17 6009850.45 HS 2,50 87.15 8 148.82 C 55673].87 6009652,78 HS 2.50 Z I> "0 frl (Anadr/'ll (c)97 MPHOP2 3.0C 11:03 AM P) I,O MgH-08(P2) OL Ju~ 2997 PaNe 2 STATION M~ASURKD I DHFt£ ~ [CAT10~ DH 1400.00 lSOO .o6 ~600.00 aUILD 3/~00 1700.00 ENCLN ANGLH 24.50 27,00 29.50 32.00 35.00 m 2 £860.00 36.80 1890.26 36.80 1920.00 36.B0 2000.00 39.20 2100.00 ~2.20 2200.00 45.20 2300.00 48.20 2400.00 53.20 2500.00 54.20 2600,00 59.20 2700.00 60.20 2800.00 63.20 2900.00 66,20 3000.00 69.20 ~200.00 ?2.20 Z ~ .~ 3200.00 75-20 " ~ 3300.00 98.20 ~-.~/10~',.D;~ .3327.*,0 ',9.01 ~ ~ ~600.00 ~2.63 o ~ ~D~ ,eoo.oo e~ ,~. ~J vsoo .oo es.6~ (~adrl~.]. (c)97 NPH8P2 3.0C L1:03 ~ P) P~2OPOSHD WSLL PROFILB D£RBCT[ON VHRT£CAL-DHE'TKS AZEMUT~ TVD S1~ - ~HA 120.35 1370,2£ 3304.71 120.35 2460.27 1394,~9 120.35 1548.$5 1482.85 120-35 1634.29 £$6~.99 120.35 1717.67 1652 , l~ 120.35 1966.27 1~00.77 120.35 1990.50 1725.00 120.35 1814.31 1748.82 120.35 18~7.35 181L.85 120.35 1953.~5 L88~.6~ 120.35 2025-44 1959.94 120.35 2094.02 2028.52 120.~5 2/58-69 2093,19 120.35 2219.28 2153.78 320.35 2295.63 2210.13 120.35 2327.59 2262.07 120.35 2374.97 2309.47 120.35 2417.7~ 2352.21 120.35 2455.65 2390.15 120.35 2488.69 2423.19 120.35 2516.76 2451.26 120.35 2539.76 247,.26 120.35 2545.11 24~9.61 120.35 3352.88 3287.36 120.35 3359.88 3294,38 12O.35 3384.70 33L9.20 120.35 3416.22 3350.93 120.35 3454.26 3388.76 SHC~ION DEDART 211.93 '255.37 302 .~0 353.83 409.0! COORDI/4AT~S-~ROM ALASKA ~one 4 'I'~,OL DL/ WELL~ X Y PACH 100 L07.10 ~ 182.B8 E ~6768.08 6009B~3.09 HS 2.50 329.05 ~ 220.3~ E 556805.73 6009791.43 ~ 2.~0 152.96 S 26/.22 H 556846.75 6009767.83 HS 2.50 178.80 S 30~.33 H ~5689k.06 6009742.~ HS 2.~0 206.69 S 352.95 H 556938.88 60097~4.81 ~ 3.00 444.20 224.47 S 383.31 E 556969.37 600969~.26 HS 3.00 462.32 233.63 $ 398.95 H 556985,O8 6009688.22 HS 0.00 480,14 242.63 $ 414,32 H 557000.$2 6009679.34 ~g 0,00 529,39 267,52 8 456,82 H ~57043.20 6009654,77 BS ~.00 594.59 300,4'6 g $£3,09 H 557099.71 6009622,26 HS 663.67 335.37 S 572.70 E 557159.58 6009589.80 14S 3.00 736.44 ~72.~4 S 635.49 E S57222.65 6009551.51 H$ 3.00 812.70 410.68 S 901.30 ~ ~57208.72 6009513.48 HS 3.00 892.23 450.87 S ~69,93 ~ 557357.67 6009473.81 ~S 3.00 974.04 492.61 S 841-2] ~ 557429,25 6009432.62 ~S 3.00 1060.27 535.79 S 914.94 H 557503.30 6009390.01 EtS 3.00 1148.31 580.28 S 990.91 ~ 557579.59 6009346.11 I~S 3.00 1230.7£ 625,96 S L060.91 ~ 5576~7.94 6009301,02 H$ 3.00 1331.22 672.70 S 1148.74 E 557738.11 6009254.08 H$ 3.00 142~.59 720.39 S 1230.E8 E 5570~9.90 6009207.82 H$ 3.00 1521.56 768.89 S 1312.99 ~ 557903,07 6009159.96 HS 3.00 16LB.B6 828.06 8 1396.96 H 559987.40 6009111.~3 BS 3.00 1645-43 831;48 ~ 1419.88 ~ 558010.42 6009098.~8 HS 3,00 ~806.03 2933.97 ~ 5010.18 ~ 5616L6.22 6007023.20 ~S 0.00 5839.92 2961.09 S 5039.42 H 561645.59 6007006.30 LS 4.00 5936.78 3000.03 S 5123.00 g 561729.~3 6006958.00 ~S 4.00 6031'.66 304~.98 S 5204.88 E 5618~1.76 6006910.68 6S 4.00 6~24.L~ 3094.~0 S ~284.66 ~ 56L891.89 6006864.57 h~ 4.00 MDH-0B(P2) 0L Jul 1999 Page STAT ION £DENTIPICATIO~ DEPTH ANG'LR 7907.80' 65.32 0000.00 6L.63 0100.00 5?.63 8'200.00 53.63 8300.0° 49.63 8400,00 45.63 TOP M SAND 8438.64 44.08 6500.00 42.63 END 4/L0O DROP 8540.91 40.00 I~A/TO~ SCHRADER 8740.71 40.00 TAROET 8740.71 40.00 NB 8794.66 40.00 ~C/ND eS15.t2 40.00 NB 8839.3L 40.00 ~ 8897.36 40.00 OA 8939,L4 40.00 0A4 8979,60 40.00 OB 9020.07 40.00 BASE SCHRADER 905L,40 40.00 7m CASII~ POINT 925L.40 40.00 TD 925L.~0 40,00 PROPOSED W~LL PROFILE mmmmmmm :==aammmm DIR.I{CT£ON VERTECAh-D~[:'TRS 8ECTIO~ AZ IMUTI{ ?VD SUB- flE~m~ DEPART 120.35 3457 .$0 3392.00 613 L.21 120.35 3498.67 3433.~ 6213.69 120.35 3549.22 3483,72 6299.9~ 120.35 3605.67 3540.37 6382.47 120,35 366~.73 3602,23 6460.86 L20.35 3735.11 3669.61 6534~72 L20.35 3762.50 3697.00 656L.97 L20.35 3807.&8 3941.98 6603.90 L20.35 3838.29 3972.79 6630-31 ~20.3~ 3992,50 3926.00 6756-87 ~20.35 3991.50 3926.00 6758.87 120.35 4017,50 3952.00 6780.69 120.35 ~048,50 3983.00 6806.70 120.35 4065.50 4000.00 6820.97 120.35 4111,5G 4046,00 6859,56 120.35 4143.50 4098,00 6886,42 120,35 4174,50 4L09.00 6912,43 120,35 4205.~O ~/40.00 6938,44 120.35 4229.50 4164.00 6958,58 120.35 4382.7t 431~,2£ 708~.14 L20.35 4382.7~ 4317.2~ 7087.14 C00RDENATHS-FROM ALASKA ~one 4 TOOL DL/ WEbLH~P X Y PACH 3098.29 S 5290,7B H 56~898.03 600686~,03 LS 4.00 3239.97 S 536~95 K 56L969,52 6006819,09 LS 4.00 3183.56 S 5436,39 E ~62044,27 60067~6.87 LS 4,00 3225.26 S 550~.60 H 562~35.79 6006735.72 L~ 4.0~ 3264,87 B 5575.24 ~ 562183.72 6006696,63 L9 4,00 3302.19 S 5638.98 H 562247.74 6006659.79 LS 4.00 33L5-96 S 5661.50 H 56227~.~6 6006646,20 LS 4.00 3337.05 S 5698.~£ H 562307.52 6006625.39 LS 4.00 3350.50 S 572£,4~ E 562330,59 60066~2.11 ~ 4.00 3435.46 S 5832.4! E 562442,0~ 6006540.00 RS 0,00 3415.46 B 5832.43 B S62442.00 6006548.00 RS 0.00 3426.49 S 585~.23 H 562460.91 6006537.12 RS 0.00 3439.63 $ 5873.68 H 562483.45 6006524.15 H8 O.O0 3446,84 S 5885.99 H 562495.81 6006517,03 HS 0,GO 3466,35 S 59~9.30 H 562529.26 6006497,9B HS 0.OO 3479.92 S 5942.47 B 562552.54 6006464.39 HS 0.O0 3493,06 S 5964.9L E 562575.08 6006471.42 }IS 0.00 3506,21 S 5987.36 E 562597,62 6006450.45 H$ 0.00 3526.38 S 6004,74 E 5626£5.08 6006448.40 H6 0.00 3581.35 S 6115.67 E S62726.49 6006384.29 0.00 '3581.35 $ 6'LL5.67 R 562726.49 6006384.29 0.00 Z (Anadrill (c) 97 MPHBP2 3.0C IL.-03 AM P] _ , ANADRILL AKA~DPC APPROVED FOR PERMITTING ONLY PLAN "O ITl · . ...... SHARED SERVICES DR:I'LL:ING . i i i i i i ii i i i tlnadri ] ] Sch]umb~em_.~ MPH-08 (P2) VEFtlICAL SECTION VIEW Section at: 120.35 TVD Scale.' ! inch: 1000 feet Oep Scale · ! inch : t000 feet Drawn .... · 0~1 Jul 1@§7 ii Marker Identification MD BKB SECTN INCLN m .oP/mm.o ~.~/~oo 3oo ~oo o o.o e'- c) BUZL.D :UFO0 ~00 ~00 ~ C- , ' O) BUILD ~.5/100 700 690 ~3 7.0 E) BU/LO 3/100 1700 t63d 354 32.0 0 ~ ', Fl END 3/'!00 BUZLD t~O 1766 444 36.8 I~ ' G} BUILD 3/100 ~9~0 ~BJd d~ 36.8 H) END 3/~00 SUit0 33~7 ~5 ~d5 70.0 " ' ]) DROP 4/100 7565 3353 5806 79.0 , ~) END 4/~00 OROP 05~ ~838 ~30 , , .-- K) TARGET 8741 3~] ~759 dO.e ~ L) 2' CASING POZNT 9251 4~83 7087 .... ~..... . .... '--- ~ h~r- ~ 'm 10 9251 4~83 7087 40. , ,. ANADRILL A~ . FO t' PEiIMi?'TIN~ ' ~~~~~~' ~kmm ~. . . , ,-~~ .... ~-. . '==: ~===-- . . ']~P~ '~ " ~ ..... ~r~I _Il ~i~m_ ff 3_fe~L L ~~ ~i~-- - . ........... ~ ~ ~ ~ii~iii ~ ~ ..... : ....L j~ i IiI . I I I l 0 5o0 ~000 ~500 2000 2500 3000 35oo 4000 4500 SD00 Sect ion Departure (Anadr I ) ] lc) 97 NPHB:]2 3.0C I l: 3 ! 114 P) ' ,: ' ' : . , · ,, , , k-DP( Z :;;U SHARED SERVICES BRILLING _ _ VERTICAL SECTION VIEW Section at: TVD Scale' 1.inch : 100 feet ~L Dep Scale · ! inch : 100 fee[ Drawn .... · 01 Jul 1997 ........... ~r~'~-~ 4~adrJ J] SchJumberger. } .... Marker Identifica[ton ND BKB SECTN INCLN A) END 4/100 DROP B~41 28~B 6620 ~8,00 B~ ~ARGET 87~ ~9~ 6759 40:.00 : ' APPROVED. ~ .... FO'P. 'PEP. M~TTIN ~ '% ()N b~' . . - . 6500 6550 6600 6650 6700 6750 61300 6850 6900 6950 7000 7050 7100 7150 7200 Section Departure i! (Ana~r~ll (c)97 ItPHBP2 3.0C 1~,;48 AN PI SHARED "'SEIqV ' ICES DRILLING AnadrJ ] ] Sch ]u~berger i i N1PH-08 (P2) PLAN VIEW CLOSURE · 7087 leer at Azimuth ~20.35 I OECLINAT]ON.: +27.99t (E) ISCALE ....... : ~ inch = lO00 feet I ~ Marker Identificatinn MD N/S E/W "~,~ A) KB 0 0 N 0 E B) KOP/B~[LD J.5/~O0 ~0 0 N 0 E ~ ,UILD2/,O0~ 500 3S 5E I) ~P 4/~00 , 7565 2g34 S 5010 E '. J) E~ 4/t00 DROP 8541 3353 S 5721 E ' . ~' K) lARGE3 874~ 34~5 S 5832 E ~ ... '~,. L) 7' CAS]NS POIN3 g251 ' 3~ S 6116 E , '. ~ '" ~ TAR~'T [RadiL~ 100 te,~t ) '~ ' ..... ...... ANAD ~ILL kKA-DPC . . 500 0 5o0 lO00 1500 2000 2500 3000 3500 4000 4500 5000 5500 600o 6500 7000 7500 8000 <- HESl · EASt ->, , iiii i i ii i i i i i LI, aadrilL {c)91 NI:TIBP~ 3.nc 11:56 All J;) z H 2000.00 MON. H-2 N 2000,O0 + q- 4- 4- + -F + + 15'40'59" .,'+ + + + oo + N 800.00 VICINITY MAP N.T.S. -LEGEND + H-5 · H-6 · H-2 · -~H-8 + -q~- H-7 H PAD I + + + AS-BUILT CONDUCTOR LOCATION · EXISTING WELL MON. H-1 NOTES 1. DATE OF SURVEY: dULY 28-.30, 1995. :2.REFERENCE FIELD BOOK: MP95-16 (pgs. 45-48). 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. 4. GEODETIC COORDINATES ARE NAD 192'7. 5. PAD SCALE FACTOR IS 0.9999036. SURVEYOR'S CERTIFICATE' i HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE-LAND. SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE 'BY ME OR UNDER MY DIRECT SUPERVISION AND. THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF dULY 50, 1995. 6. HORIZONTAL/VERTICAL CONTROL IS BASED ON MONUMENTS H-1 AND H-2. LOCATED WITHIN PROTRACTED SECTION 34, T. 13 N., R. 10 E., UMIAT MERIDIAN ALASKA WEU_ A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSiTION(OMS) POSITION(O.DD) BOX ELEV. OFFSETS Y= 6,009,918.79 N= 1,230.58 70'26'15.891', 70.4577475' 56.0' - 2-767' FSL H-_~ X= 556,584.41 E== 879.71 149'32'19.068'. -149.5386300' 4.061' FEL H-~! Y=6,009,860.68 N~ 1,170.14 70'26'15.321" 70.4375891' 36.4' 2,709' FSI_ X=.. 556,567.80 -E= 879.43 149'32'19.569" 149.5387690' 4,079' FEL I J o J~/~, RENUMI~RED ~L~LL 7 TO ~ 8 AND 8 TO 7 PER RENU~R£O ~ H--5 O~ONAL A$-BUtLT JACOBS C~EC~E~. O'HANLEY o^'~_: 7/31/95 ~A~NG: MPHP~ ~ Nm L BP EXPLORATION MILNE POINT UNIT H PAD CONDUCTOR AS-BUILT WELLS H-7 & H-8 ISHEET:I 0~- 1 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET O?:-~-';-.'g7 CF:,o172'::..;,97H ~r,,m O0 ....,...., THE ATTACHED CHECK IS IN PAYMENT FOR fTEMS DESCRIBED ABOVE. ~lr~ll~,,l~ -- ~ .~.__.,--._ .-.-.,~_.,-,-- ..... · WELL PERMIT CHECKLIST COMPANY _,~ WELL NAME ,,'~/~'¢'~' FIELD & POOL , ~"'"2-...,,,~/'/--'/20 INIT CLASS ~/"~ _z2~L.-' ..,~--~.,//. GEOL AREA ADMINISTRATION PROGRAM: exp [] dev~redrll [] serv [] wellbore seg ri ann. disposal para req c'-3 UNIT# f,/,.'~,,,,'~- ~ ON/OFF SHORE ENGINEERING 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 drilling 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 ........... 14. 15. 16. 17. 18. 19. 20. 21. N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N REMARKS APPR 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................... (~ N Surface casing protects all known USDWs ........... (_~ N C MT vol adequate to circulate on conductor&surf c sg ..... CMT vol adequate to tie-in long string to surf csg ........ N CMT will cover all known productive horizons .......... ' Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved .... Adequate wellbore separation proposed ............. ~ N If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... ) N BOPEs, do they meet regulation ..... ) N BOPE press rating appropriate; test to "~'Z~' ' ' I~sigl ~ N Choke manifold complies w/APl RP-53 (May 84) ........ - '" Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. GEOLOGY .R D~,TE/ 3O. Permit can be issued w/o hydrogen sulfide measures ..... Y N.,,~ 31. Data presented on potential overpressure zones ....... y/~~ ~~~ 32. Seismic analysis of shallow gas zones ............. 33. Seabed conOifion survey (if off-shore) ............. 34. Contact name/phone for weeklyproqress reports ~ Y N [exploratory only] ...... GEOLOGY: ENGINEERING: COMMISSION: JDH ~ RNC~ Comments/Instructions: HOW/Ijt - A:\FORMS\cheklist rev 07/97 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. Sperry-Sun Drilling Services LIS Scan Utility Tue Oct 20 10:04:51 1998 Reel Header Service name ............. LISTPE Date ..................... 98/10/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 98/10/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writin9 Library. Services Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: MWD RUN 2 AK-MM-70279 ZIEMKE BURLEY MPH-08 500292280800 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 20-0CT-98 34 13N 10E 2767 4061 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD .00 64.90 36.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 20.000 112.0 PRODUCTION STRING 9.875 9275.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL DEPTHS ARE DRILLER'S DEPTHS. DEPTH CORRECTION IS WAIVED AS PER THE E-MAIL MESSAGE FROM KATIE NITZBERG ON 09/23/98. MWD IS PDC. 3. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 4. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PPLASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD) . 5. STABILIZED LITHO DENSITY (SLD) DATA IS NOT AVAILABLE FOR RUN 2 DUE TO A SOFTWARE FAILURE IN SENSOR. 6. ALL MWD RUNS REPRESENT MPH-08 WITH API# 50-029-22808-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9275'MD, 4392'TVD. SROP = SMOOTHED P~ATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME FOR RESISTIVITY SENSOR. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVER_AGE OF FAR DETECTORS' COUNT RATES. ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR LOG PROCESSING: HOLE SIZE: 9.875" MUD FILTRATE SALINITY: 800.000 PPM. MUD WEIGHT: 9.300 PPG. FORMATION WATER SALINITY: 14545.000 PPM. FLUID DENSITY: 1.000 G/C3. MATRIX DENSITY: 2.650 G/C3. LITHOLOGY: SANDSTONE. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START DEPTH FCNT 5850.0 NCNT 5850.0 NPHI 5850.0 ROP 5850.0 FET 5864.0 RPX 5864.0 RPD 5864.5 RPM 5864.5 RPS 5864.5 GR 5886.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: STOP DEPTH 9162 0 9162 0 9162 0 9275 0 9188 0 9188 0 9188.0 9188.0 9188.0 9207.5 EQUIVALENT UNSHIFTED DEPTH -- Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 2 5951.0 9275.0 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 NPHI MWD PU-S 4 1 68 ROP MWD FT/H 4 1 68 FET MWD HOUR 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 Name Min Max Mean DEPT 5850 9275 7562.5 GR 13.2167 115.441 61.1038 RPX 1.6501 110.318 10.7217 RPS 1.7272 2000 12.8959 RPM 1.7743 2000 15.0879 RPD 1.9571 2000 16.1539 NPHI 16.6187 69.2953 37.981 ROP 8.0269 1029.2 259.105 FET 0.1779 23.1245 1.77307 FCNT 402 851 543.293 NCNT 2008 3274.42 2501.7.7 Nsam 6851 6643 6649 6648 6648 6648 6540 6851 6649 6540 6625 First Reading 5850 5886.5 5864 5864.5 5864.5 5864.5 5850 5850 5864 5850 5850 Last Reading 9275 9207.5 9188 9188 9188 9188 9162 9275 9188 9162 9162 First Reading For Entire File .......... 5850 Last Reading For Entire File ........... 9275 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RLTN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT NCNT NPHI ROP FET RPX RPD RPM RPS GR $ LOG HEADER DATA DATE LOGGED: SOFTWARE 5850 0 5850 0 5850 0 5850 0 5864 0 5864 0 5864 5 5864 5 5864.5 5886.5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9162.0 9162.0 9162.0 9275.0 9188 0 9188 0 9188 9188 9188 9207 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA 28-SEP-97 5.07 5.46 MEMORY 9275.0 5951.0 9275.0 43.3 80.3 TOOL NUMBER P0830CRDGP6 P0830CRDGP6 P0830CRDGP6 OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MI/D TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9.880 9.9 SPUD/LSND 9.30 73.0 9.5 800 3.8 2.500 1.983 1.875 3.750 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 NCNT MWD 2 CNTS 4 1 68 32 9 FCNT MWD 2 CNTS 4 1 68 36 10 NPHI MWD 2 PU-S 4 1 68 40 11 32.2 Name Min Max Mean DEPT 5850 9275 7562.5 ROP 8.0269 1029.2 259.105 GR 13.2167 115.441 61.1038 RPX 1.6501 110.318 10.7217 RPS 1.7272 2000 12.8959 RPM 1.7743 2000 15.0879 RPD 1.9571 2000 16.1539 FET 0.1779 23.1245 1.77307 NCNT 2008 3274.42 2501.77 FCNT 402 851 543.293 NPHI 16.6187 69.2953 37.981 First Last Nsam Reading Reading 6851 5850 9275 6851 5850 9275 6643 5886.5 9207.5 6649 5864 9188 6648 5864.5 9188 6648 5864.5 9188 6648 5864.5 9188 6649 5864 9188 6625 5850 9162 6540 5850 9162 6540 5850 9162 First Reading For Entire File .......... 5850 Last Reading For Entire File ........... 9275 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/10/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/10/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File