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Home My WebLink About194-101Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the °riginal file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages' Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy~Vincent Nathan Lowell Date: (~ ~ ~'~ ~si [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is/ Ol, ggFO c:LORIX~LM-DOC PLUGG_._N'G & LOCATION CLMA_RA~CE R~,PORT State cf Alaska 0iL & GA~ C~'~fSERVATION COMMISSION .~ev±ew ~he we3 ~ --'=~ o, and-c-~-~c on plugging, well head Well hear ' !oeo=jun c!earancs - uro~ide loc. c!e~ar, code. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Plugged Backfor Sidetrack WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [~ Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 194-101 399-231 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22495-00 4. Location of well at surface 9. Unit or Lease Name 2347' NSL, 2090' EWL, SEC. 28, T13N, R10E '~~' Milne Point Unit At top of productive interval~" '~~ 10. Well Number 4522' NSL, 200' W EL, SEC. 29, T laN, R10E ~,~_~ M PJ-09 At total depth 11. Field and Pool 2912' NSL, 1616' WEL, SEC. 20, T13N, R10E "~. %"C.' ~.~, ~,-'-~ Milne Point Unit / Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 65.06'I ADL 025515 12. Date Spudded7/29/94 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if °ffsh°re 116' N°' °f C°mpleti°ns8/6/94 12/5/99 N/A MSLI Zero 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Survey t20. Depth where SSSV set 121. Thickness of Permafrost 10860 7431 FTI 10083 6693 FTI [] Yes [] No! N/A MD I 1800' (Approx.) 22. Type Electric or Other Logs Run GR, RES, NEU, CBL, GR 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP Bo'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 54.5# K-55 32' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 31' 2936' 12-1/4" 572 sx PF 'E', 250 sx Class 'G' 7" 26# L-80 29' 10840' 8-1/2" 400 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None None MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5360' Set EZSV (Unable to Inj. Cement) 5355' Set Whipstock 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Not on Production I N/* I bi L Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. E) 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 16 20OO' Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, GOR, and time of each phase. (Subsea) Top Kuparuk 'C' 10263' 6932' Top Kuparuk 'B' 10263' 6932' Top Kuparuk 'A' 10423' 7064' 31. List of Attachments Summary of Daily Drilling Reports 32. Isignedhereby certify that the fo~regoing.,,~j~/~ is~true andJL~,~ ,~-~c°rrect to the best of my knowledge(~ ~,~' ] ~-~ TerrieHubble - / Title Technical Assistant III Date _ , '~__(~ MPJ-09 194-101 399-231 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23; Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 RECEIVED AlaMm 0it & Gas Cons. Commitmi Facility Date/Time 03 Dec 99 M Pt J Pad Duration 8-3/4 hr 4-1/4 hr 06:01-15:00 06:01-10:30 4-1/2 hr 10:30 10:30-15:00 lhr 1hr 15:00 15:00-16:00 15:00-16:00 16:00 16:00-21:00 16:00-21:00 5hr 5hr 9hr 1/2 hr Progress Report 21:00 21:00-06:00 21:00-21:30 Well MPJ-09A Page 1 Rig Nordic3 Date 06 January 00 21:30 21:30-22:30 22:30 22:30-00:00 04 Dec 99 00:00 00:00-01:30 01:30 01:30-03:30 03:30 03:30-04:00 04:00 04:00-05:00 05:00 05:00-05:45 05:45 05:45-06:00 1 hr 1-1/2 hr 1-1/2 hr 2hr 1/2 hr 1 hr 3/4 hr 1/4 hr Activity Move rig Rig moved 100.00 % Move rig from MP J-01A to MP J-09A. Attempt to lay herculite. Wind blowing herculite. Finally laid herculite around cellar and as good as possible under rig area. Spot rig over cellar. Rig accepted @ 1030 hrs on 12/3/99. At well location - Cellar Rigged up Drillfloor / Derrick Berm around tanks and rig. Equipment work completed Wellhead work Removed Hanger plug Pull BPV. Equipment work completed Fluid system Fill pits with Seawater RU kill lines. Spot cuttings box and kill tank. RU lines & test to 120 psi w/air. Fill pits with 120 deg seawater. Completed operations Wellhead work Tested Chicksan lines PJSM. Test hardlines to 2000 psi-OK. Pressure test completed successfully - 2000.000 psi Circulated at 0.0 ft Pump down tbg w/1 bpm @ 1300 psi. No circulation. Attempt to pump down annulus. Pumped -1 bbl and pressure up to 2000 psi. Checked all surface equipment. Annulus frozen. Began precautionary measures Monitor pressures Steam wellhead and WO hot oil truck. RU HB&R. Test lines to 3000 psi. Resumed operations Circulated at 0.0 ft Pressure well to 2500 psi w/methanol and maintain pressure. Pumped a total of 7 bbls methanol to thaw well. Broke circulation Circulated at 0.0 ft Displace well with hot seawater. Monitor well-OK. Hole displaced with Seawater - 110.00 % displaced Installed Hanger plug Attempt to set TWC. Well started flowing. Shut in. SITP: 0 psi; SICP: 30 psi. Aborted equipment work Circulated at 0.0 ft CBU Hole displaced with Seawater - 120.00 % displaced Installed Hanger plug Set TWC. Eqpt. work completed, running tool retrieved Removed Xmas tree OLO-L t INI.J tl[..,~--.~ allU IZlLII:J.I-/L~,.~I. RECEIVED i--.;.:B 16 almlm & Co s. Oommi im Facility M Pt J Pad Progress Report Well MPJ-09A Page 2 Rig Nordic3 Date 06 January 00 Date/Time 05:45-06:00 06:00-08:00 06:00-08:00 08:00 08:00-10:30 08:00-09:30 09:30 09:30-10:30 10:30 10:30-15:00 10:30-14:30 14:30 14:30-15:00 15:00 15:00-15:30 15:00-15:30 15:30 15:30-23:30 15:30-16:30 16:30 16:30-23:30 23:30 23:30-00:15 23:30-00:15 05 Dec 99 00:15 00:15-00:30 00:15-00:30 00:30 00:30-06:00 00:30-03:30 03:30 03:30-05:45 05:45 05:45-06:00 Duration 1/4 hr 2hr 2hr 2-1/2 hr 1-1/2 hr lhr 4-1/2 hr 4hr 1/2 hr 1/2 hr 1/2 hr 8 hr lhr 7 hr 3/4 hr 3/4 hr 1/4 hr 1/4 hr 5-1/2 hr 3hr 2-1/4 hr 1/4 hr Activity Removed Xmas tree Finish ND tree and adapter. Wellhead work (cont...) Removed Xmas tree (cont...) Finish ND tree and adapter. Equipment work completed Nipple up BOP stack Rigged up BOP stack Work completed - BOP stack in position Rigged up Top ram Change rams to 3.5". Equipment work completed Test well control equipment Tested BOP stack Test BOPE to 250/3000 psi; annular to 250/2500 psi. Witnessing waived by John Spaulding-AOGCC Field Inspector. Pressure test completed successfully - 3000.000 psi Held safety meeting HSE meeting w/HSE Advisor. Discussed week's LCIR's. Completed operations Wellhead work Removed Hanger plug Pull TWC. Equipment work completed Pull Tubing, 3-1/2in O.D. Retrieved Tubing hanger MU landing jt. BOLDS. Pull hanger to floor. Monitor well. 19 bbls to fill. Equipment work completed Laid down 5324.0 ft of Tubing LD kill string. Strap & drift. 170 joints laid out Test well control equipment Tested Bottom ram Set test 'plug. Test lower pipe ram and break to 250/3000 psi-OK. LD Test jt & test plug. Pressure test completed successfully - 3000.000 psi Wellhead work Rigged up Wear bushing Equipment work completed Electric wireline work Conducted electric cable operations PJSM. RU Schlumberger w/lubricator. Ran 5.83" GR/JB to 5395'. POH. Completed run with Junk basket/gauge ring from 5395.0 ft to 0.0 ft Set downhole equipment (wireline) RIH w/EZSV retainer. Tie in to CBL dated 4/18/99. Set retainer @ 5360'. Completed run with Cement retainer to 5360.0 fl Conducted electric cable operations POH. RECEIVED 20O0 Oil & C-,as Cons. Commi, Facility Date/Time M Pt J Pad Progress Report 05:45-06:00 Well MPJ-09A Page 3 Rig Nordic3 Date 06 January 00 06:00-06:30 06:00-06:30 06:30 06:30-16:00 06:30-07:00 07:00 07:00-08:00 08:00 08:00-08:30 08:30 08:30-10:00 10:00 10:00-12:00 12:00 12:00-12:30 12:30 12:30-13:00 13:00 13:00-14:00 14:00 14:00-16:00 16:00 16:00-02:00 16:00-17:00 17:00 17:00-20:15 20:15 20:15-21:00 21:00 21:00-21:15 21:15 21:15-21:30 21:30 21:30-22:30 22:30 22:30-00:15 Duration 1/4 hr 1/2 hr 1/2 hr 9~1/2 hr 1/2 hr lhr 1/2 hr 1-1/2 hr 2hr 1/2 hr 1/2 hr 1 hr 2hr lOhr lhr 3-1/4 hr 3/4 hr 1/4 hr 1/4 hr 1 hr 1-3/4 hr Activity Conducted electric cable operations Fin POH & RD Schlumberger. Electric wireline work (cont...) Conducted electric cable operations (cont...) Fin POH & RD Schlumberger. Completed run with Setting tools from 5360.0 ft to 0.0 ft 3-1/2in. Drillpipe workstring run Rigged up Drillstring handling equipment Work completed - Drillstring handling equipment in position Ran Drillpipe in stands to 2000.0 ft Stopped: To change handling equipment Rigged down Instrument lines RD Baker TEC wire sheave for Nabors 4ES. Equipment work completed Ran Drillpipe in stands to 5360.0 ft Fin RIH w/cement stinger. Tag retainer & verify w/ 20k down. On bottom Functioned Cement retainer Break circ. Sting into retainer. Attempt to inject. Press up to 2000 psi. Very slow bleed off. Unsting & check surface equipment. Sting in & pressure to 3000 psi. Bled to 2800 in 10 min. Began precautionary measures Cleared Standpipe manifold Blow down lines. Equipment work completed Tested Casing Stung into retainer. Test 7" f/30 min-OK. Pressure test completed successfully - 3000.000 psi Monitor pressures WO AOGCC approval to proceed with well plan. Resumed operations Pulled out of hole to 0.0 ft POH w/stinger. At Surface: 0.0 ft BHA run no. 1 Made up BHA no. 1 MU milling assembly. BHA no. 1 made up R.I.H. to 5360.0 ft On bottom Held safety meeting PreSpud meeting & TL Awards. Completed operations Pulled out of hole to 5100.0 ft Start POH. Dragging 10-15k. Observed 15.00 klb overpull R.I.H. to 5360.0 ft On bottom Circulated at 5360.0 ft Circ @ 7.5 bpm. Obtained clean returns - 200.00 % hole volume Pulled out of hole to 1474.0 fl RECEIVED Ala a Oil & Gas Cees. Commi, ak3n Anc ora Facility Date/Time 06 Dec 99 M Pt J Pad 00:15 00:15-01:00 01:00 01:00-02:00 02:00 02:00-06:00 02:00-05:00 05:00 05:00-06:00 06:00-22:00 06:00-08:30 Duration 3/4 hr lhr 4hr 3hr lhr 16hr 2-1/2 hr 08:30 08:30-09:30 1 hr 09:30 09:30-10:30 1 hr Progress Report Well MPJ-09A Page 4 Rig Nordic3 Date 06 January 00 10:30 10:30-15:00 4-1/2 hr 15:00 15:00-17:00 2 hr 17:00 17:00-20:30 3-1/2 hr 20:30 20:30-22:00 1-1/2 hr 22:00 22:00-06:00 8 hr 22:00-02:00 4 hr 07 Dec 99 02:00 02:00-04:30 2-1/2 hr 04:30 04:30-06:00 1-1/2 hr 06:00-06:00 24 hr 06:00-01:30 19-1/2 hr RECEIVED Activity At BHA Pulled BHA BHA Stood back Serviced Block line Slip & cut drlg line. Line slipped and cut BHA run no. 2 Made up BHA no. 2 MU whipstock assembly. Orient. MU BHA. Test MWD. BHA no. 2 made up R.I.H. to 3200.0 ft Finish RIH w/whipstock. Fire Drill-OS-30 sec. BHA run no. 2 (cont...) R.I.H. to 5290.0 ft (cont...) Finish RIH w/whipstock. Fire Drill-OS-30 sec. Stopped · To take survey Took MWD survey at 5200.0 ft Orient whipstock. Set @ 5355' DPM. PU: 90k; SO: 75k. Set 40 deg left of high. Shear off. Acceptable survey obtained at 5200.0 ft Circulated at 5350.0 ft Displace well to milling fluid. Hole displaced with Water based mud - 100.00 % displaced Milled Casing at 5334.0 fl Milled window f/5334'-5346'. Milled to 5363' Completed operations Circulated at 5363.0 ft Pump sweeps. Reciprocate back and forth through window. Window in good shape. Monitor well-OK. Pump dry job. Blow down. Hole swept with slug - 200.00 % hole volume Pulled out of hole to 1491.0 fl At B HA Pulled BHA LD MWD & mills. Mulls in gauge. Clear floor. BHA Stood back BHA run no. 3 Made up BHA no. 3 PU 4.75" directional tools. Upload MWD. Orient. Check MWD. Blow down. BHA no. 3 made up R.I.H. to 5362.0 ft SLM in hole. D1 Drill-OS-35 sec. On bottom Drilled to 5415.0 ft Continue directional drilling 6.125" hole F/5415' to 6283' ECD 10.7 while sliding for direction and angle. Up/wt 85k, Dn/wt 75K w/rotary. Pumped sweep @ 5992' 38 bbl's Hi-vis Hi-wt w/fiber. Brought up a good load of cuttings. ECD 11.1 BHA run no. 3 (cont...) Drilled to 6283.0 ft (cont...) Continue directional drilling 6.125" hole F/5415' to 6283' ECD 10.7 while sliding for direction and an c. ujJ/vYt OJl~, ,L~II/WIL I~lX.~ WI IUtflly. ! ILIIItIJCU SWCcp ] 6 Alata Oil I Ceas. Cami on i i Facility M Pt J Pad Date/Time Duration 08 Dec 99 01:30 01:30-03:00 1-1/2 hr 03:00 03:00-05:00 2 hr 05:00 05:00-06:00 1 hr Progress Report Well MPJ-09A Rig Nordic3 vIztJ T" ,:. I ~ ~' ~ ~ ~, LOUtj · a a l&Gaa 0ona. Pag?~i~10~ Date 06 January 00 Activity @ 5992' 38 bbl's Hi-vis Hi-wt w/fiber. Brought up Stopped: To circulate Circulated at 6283.0 ft Circulate & reciporcate pump sweep Hi-vis Hi-wt w/ fiber ECD 11.1, Clean hole for short trip. Hole swept with slug - 200.00 % hole volume Pulled out of hole to 2000.0 ft POOH to 7" csg window. Hole in good condition. Blow down top drive. POOH stand back DP & HWDP At top of check trip interval R.I.H. to 5334.0 ft RIH w/3.5" DP to 7" Window @ 5334'. Continue cleaning pit for BARADRILn fluid. @ 0600 hrs 06:00 At 5334in casing shoe 06:00-06:00 24 hr BHA run no. 3 (cont...) 06:00-06:30 1/2 hr 06:30 06:30-11:00 4-1/2 hr 11:00 11:00-12:30 1-1/2 hr 12:30 12:30-15:00 2-1/2 hr -:~ 15:00 15:00-06:00 15 hr 09 Dec 99 06:00-06:00 24 hr 06:00-12:00 6 hr 12:00 12:00-14:30 2-1/2 hr 14:30 14:30-16:00 1-1/2 hr 16:00 16:00-17:30 1-1/2 hr 17:30 17:30-06:00 12-1/2 hr Serviced Top drive Equipment work completed Cleared Trip tank Clean mud tanks & trip tank. Take on new 9.1 ppg BARADRILn fluuid Equipment work completed R.I.H. to 6283.0 ft RIH to 5334' 7" window. Orient tool to whipstock. Trip through 6-1/8" open hole to 6283' Hole iiin good condition. On bottom Circulated at 6283.0 ft Circulate bottoms up, Pump Hi-vis, Lo-Vis Sweep ahead of new BARADRILn 9.1 ppg drilling fluid. Hole apeared to have been clean. Obtained req. fluid properties - 100.00 %, hole vol. Drilled to 7210.0 ft Geostreer horizontal 6.125" hole f/6283' to 7210'. pumped sweeps ECD 10.7 MAX 11.4 w/sweep. BHA run no. 3 (cont...) Drilled to 7515.0 ft Continue drilling from 7210' to 7515' md. ECD = 10.7-10.8, max ECD while circulating sweeps = 11.4. Solids level in mud beginning to climb. Began precautionary measures Circulated at 7515.0 ft Circulate bottoms-up and pump sweep. Obtained clean returns - 100.00 % hole volume Pulled out of hole to 6283.0 ft Short trip to 6283' to condition hole. Hole in good shape. Run back to bottom. Began precautionary measures Circulated at 7515.0 ft Swap out 240 bbls of mud reduce solids load. Obtained req. fluid properties - 100.00 %, hole vol. Drilled to 8030.0 ft Continue drilling from 7515' to 8030' md. ECD -- 10.8-10.9 ppg. Having trouble dropping angle to .... STATE OF ALASKA ALASKA ,JIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development [] Exploratory [] Stratigraphic I~Service 4. Location of well at surface 2347' NSL, 2090' EWL, SEC. 28, T13N, R10E At top of productive interval 4522' NSL, 200' WEL, SEC. 29, T13N, R10E At effective depth 2495' NSL, 1523' WEL, SEC. 20, T13N, R10E At total depth 2912' NSL, 1616' WEL, SEC. 20, T13N, R10E 6. Datum Elevation (DF or KB) KBE = 65.06' 7. Unit or Property Name Milne Point Unit 8. Well Number MPJ-09 9. Permit N.up~er 194-101 v 10. APl Number / 50- 029-22495v/ 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10860 VCfeet 7431,4~eet 10083 feet 6693 feet Plugs (measured) Junk (measured) Cement plug at 10083' (4/97) 5' Perforated Sub, XO Sub, three 2-3/4" seal units and ball seat assembly left in frac pack assembly at 5468' (10/98) Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate Production Liner 80' 13-3/8" 2905' 9-5/8" 250 sx Arcticset (Approx.) 112' 112' 572 sx PF 'E', 250 sx 'G' i . ~ 2936' 2529' 10811' 7" 400 sx Class 'G' 10840' 7479' Perforation depth: measured 5460'- 5480', 5680'- 5700', 5780'- 5800' (open) ...... ' ': , 10328' - 10342', 10355' - 10361', 10442' - 10462', 10475 - 10507 (squeezed) vertical 3905' - 3917', 4047' - 4060', 4114' - 4127' (open) .. true 7049'- 7061', 7072' - 7077', 7144'- 7161', 7172' - 7198' (squeezed) Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80, EUE 8rd tubing to 5324' Packers and SSSV (type and measured depth) Sand Frac Pack Assembly with a 7" HES Versatrieve packer at 5395' and a 7" HES 'BBI' packer at 5580'; 7" HES 'BBI' packer at 5725'; 7" HES Fas Drill Bridge Plug at 5815'; 7" x 3-1/2" SABL-3 Baker packer w/K-anchor at 10019' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation November 22, 1999 16. If proposal was verbally approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Name of approver Date approved Contact Engineer Name/Number: Fred Johnson, 564-5427 Mik Triolo, 564-5774 Prepared By Name/Number: Terrie Hubble, 564-4628 17. hereby cert~ th,_/a~t~e~foreg/¢~/~s true and correct to the best of my knowledge Signed '"h U'¢//~ / '/~ t., aries Mallary Title Senior Drilling Engineer (/ Commission Use Only Condition_s_g, fjApproval: Notify Commission so representative ma.y witness rOu~ Plug integrity "~ BOP Test'~ Location clearance__ Mechanical Integrity Test __ Approved by order of the Commission Date IApprova, No.j~¢... ~c~/ Subsequent form required 10- Robert N. Chdstenson Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate MPJ-09A P&A Existing Completion Prior t,- Sidetrack Operations Summary" P__re-Rig O~)eration~ -- li'~ ,Test 7, packoff 1. MIRU Nordic 3. 2. Circ well. ND Tree, NU Stack and Test. 3. POOH w/3-1/2" tbg. Note: Plan to rerun 3-1/2" tbg, tubing hanger, tree. 4. RU E-line. Set EZSV on EL @ 5360'. Note: EZSV to be used as base for setting whipstock. EZSV must be set so that window is not milled thru 7" casing coupling 5. RIH w/th stinger. Cmt sqz existing perfs. Circ hole clean on top of EZSV. POOH 6. Prepare to sidetrack weJ~ using a casing whipstock. RECEIVED ~; ov c, 9 1999 Naska Oil & Gas Cons. C0mmissio. Anchorage Tree: 3-1/2", 5M Wellhead: FMC G 5 11" 5m Tbg head FMC w/ 11" x 3-1/2" tbg. hnr. w/ NSCT and 3"" CIW H BPV profile WKM 11" 5m csg Head 13-3/8" 54.5 ppf, K55 I 112' I I I MPU J-09 Orig. KB Elev. = 46.6' (N 22E) Orig. GL Elev. = 17.0' RT To Tbg. Spool = 28.8' (N 22E) KOP @ 6OO' Max. hole angle = 52 to 59 deg. f/ 2,500' to 9,500' Hole angle thru' perfs = 33 deg DLS = 6.6 deg./100' @ 9,750' 95/8", 40 ppf, L-80 Btrc. 12,936' md I 7" 26 ppf, L-80, NSCC production casing ( drift ID = 6.151 ", cap. = 0.0383 bpf ) PRESENT CONDITION RECEIVED g 0V O 9 t99! Lfl~ 0il & 6as Cons, 6o[ Anchorage Stimulation Summary N-Sand frac pack: 9/29/98 - 93.4 M# 16/20 carbolite behind screens. O^ Sand PropLok Frac: 9/26/98 - 48.5 M# of resin coated16/20 Carbolite behind pipe. OB Sand PropLok Frac: 9/26/98 - 99.8 M# of resin coated 16/20 Carbolite behind pipe. Perforation Summary Ref Icg: 4/18/97 CBT/GR/CCL Size [ SPF 4.5" [5&4 4.5" [4 ~ 4.5" 15&4 Interval (TVD) 'N' Sand 5460'-5480' 3 'CA' Sand 5680'-5700' OB' Sand 5780'-5802' 4 t38'-3853' 4047'-4060' 122'-4135' Initial perf's. SWS 37 gr. RDX 51B 'big hole' charges, 72 deg. phasing. Lastest perf's 9/22/98: SWS HSD 43C UP (big hole). Abandoned Perforations Ref Icg: 8/16/94 SBL/GR/CCL Size SPF/ ,nterva, / (TVD) 14" 14 1~),328' - 10,342' (7p49'-7081') 14" 14 1~,355' - 10,361' (7F)72'-7077') 14" 14 1~,442' - 10,462' (7~144'-7161') [4" 14 lf,475'-10,507'(~72'-7199') Fish left in See fishing folder in well file for frac pack detail of fish. assembly. I ~ ~ 7" HES Versatrieve pkr. [ 5395' ~ [ [ Closing sleeve ass'bly [ 5401' ~ I I m 3.5", 9.2 ppf, N-80, LTC , ~ I I blank pipe (ID =2.991") [ 5426' ~ ~ ~ m 3.5", 0.02" Ga. welded d,~b I-screen (ID :2.991", ,I 5455' I ,.,B,.:,% B I'HES Honed Tube (ID: 2.75'>1 5485' ~~~ End O~e~SSembly I 5494' .................................................................... ..:.:.-.:.:.:.:.:...:...-.: -.:.:.-.:...-.-.......-...-.-.-...:.:.-.- 5580' [ 5725' I 7"HES Fas Drill bridge plug [ 5815' I 7" Howco ES cementer I 6018' I Tubing chemical cut at 9893' (14' above collar) Partial jet cutter cut @ 9990' I 10,019' J 7"x 3.5" SABL-3 Baker Pkr. I I 3.5" WLEG 10,068' TOC tagged @ 10,083' 4/13/97 7" float collar [ 10,797' [ 7" float shoe [ 10,840' [ DATE I -14-95 REV. BY COMMENTS Drilled cased Nabors 22E 2-15-95 Completion Nabors 4 ES MILNE POINT UNIT WELL J-09 APl NO: 50-029-22495 Tree:3-1/8", 5M '~IPU J'09 Orig. KBElev.= 46.6'(N .~:) Wellhead: FMC Gen 5 11" x 11" 5M Orig. GL Elev. = 17.0' Tbg Head w/3-1/2" ESP/HT tbg. hnr. RT To Tbg. Spool = 28.8' (N 22E) w/ NSCT threads top and bottom and 3" CIW H BPV profile. Wellhead is WKM11"5m I 112, I' 13-3/8" 54.5 ppf, Ko55 KOP @ 600' Proposed P&A Status Max. hole angle = 52 to 59 deg. f/ Prior to Sidetrack 2,500' to 9,500' Hole angle thru' perfs = 33 deg DLS = 6.6 deg./100' @ 9,750' 9 5/8", 40 ppf, L-80 Btrc. 12,936' md I~ 7" 26 ppf, L-80, NSCC production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) 3.5", 9.2# L-80 EUE 8rd tbg I I Stimulation Summary N-Sand frac Dack: 9/29/98 - 93.4 M# Cmt Retainer at 536O' 16/20 carbolite behind screens. CA Sand ProDLok Frac: 9/26/98 - 48.5 M# of resin coated16/20 Carbolite ~"~"~' 7" HES Versatrieve pkr. I 5395' : : C,osino s,e,ve behind pipe. OB Sand ProoLok Frac: 9/26/98 - !~::~::~!~::~!~ : 3.5", 9.2 ppf, N-80, LTC 99.8 M# of resin coated 16/20 Carbotite ~?~i~:~i;!;i~?~i; : blank pipe (ID =2.991") I 5426' behind pipe. i i~:~i~ii:~ii~.~ii 3.5", 0.02" Ga. welded ~:~:~*~:~*~::-------------'-~ screen (ID =2.991 ") I 5455' Ref log: 4/18/97 CBT/GR/CCL ~ HES Honed Tube (ID = 2.75")1 5485' I · - I 5485' I Size SPF Interval (TVD) ~ En~l of assembly I 5494' Fish Suck 'N' Sand in Packer HES 7" 'BBI' packer 5580' 4.5" 5&4 5460'-5480'3,38'-3853' 'dA' Sand ~ 4.5" 4 5680'-5700' 4047'-4060' OB' Sand ~, 7" HES BBI BBI packer I 5725' 4.5" 5&4 5780'-5802' 4 122'-4135' Initial perf's. ~ SWS 37 gr. RDX 51B 'big hole' charges, ~ 7" HES Fas Drill bridge plug I 5815' Lastest perf's 9/22/98: ) 7" Howco ES cementer I 6018' SWS HSD 43C UP (big hole). Tubing chemical cut at 9893' (14' above collar) Abandoned Perforations ~ Partial jet cutter cut @ 9990' I 10,019' 7"x 3.5" SABL-3 Baker Pkr. ~:/:~://:~!~:~::~;i~:;:;:/:~i~:/;:/:~;:/:~!~::~!:!~://:~ 3.5" WLEG 10,068' Size SPF Interval (TVD) ~i~i;~i~!~ii!i~TOC tagged @ 10,083' 4/13/97 '?X'X'X'?X?X':X'..'.'?X?X?X'X'X'X' 4" 4 1 ,,328'- 10,342' (7)49'-7081'):-::-::=-::-:-::-:-=----:--:--:=-::.-::::: I 7" float collar 10,797' I .:.:.:.:.:.:.:.:.:.:.:.: :.:.: :..-...................:.:.:.:.:. 4" 4 I ,,355' 10,361' (7)72'-7077') ~ ~ I - 7" float shoe I 10,840' J DATE REV. BY COMMENTS MILNE POINT UNIT 1 -14-95 Drilled cased Nabors 22E 2-15-95 Completion Nabors 4 ES WELL J-09 04 / 19/97 JBF S ;hrader Bluff Re-completion by Nabors 4ES 08/15/97 M.Linder Schrader Bluff sand test #2 BP EXPLORATION (AK) RECEIVED r,.!0',/09 1999 Alaska. Oil & Gas Cons. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS j'; ~,~ , [] Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other Run Frac Pac'~¢.~t~'~bly ............ "~ 1. Operations performed: [] Operation Shutdown 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2347' NSL, 2090' EWL, SEC. 28, T13N, R10E At top of productive interval 4522' NSL, 200' WEL, SEC. 29, T13N, R10E At effective depth 2495' NSL, 1523' WEL, SEC. 20, T13N, R10E At total depth 2912' NSL, 1616' WEL, SEC. 20, T13N, R10E 12. Present well condition summary Total depth: measured 10860 feet true vertical 7431 feet Effective depth: measured 10083 feet true vertical 6693 feet 5. Type of well: [] Development [] Exploratory [] Stratigraphic I--]Service 6. Datum Elevation (DF or KB) KBE = 65.06' 7. Unit or Property Name Milne Point Unit 8. Well Number MPJ-09 9. Permit Number / Approval No. 94-101 / 10. APl Number 50-029-22495 11. Field and Pool Milne Point Unit / Schrader Bluff Plugs (measured) Junk (measured) Cement plug at 10083' (4/97) 5' Perforated Sub, XO Sub, three 2-3/4" seal units and ball seat assembly left in frac pack assembly at 5468' (10/98) Casing Length Size Structural Conductor 80' 13-3/8" Surface 2905' 9-5/8" Intermediate Production 10811' 7" Liner Cemented 250 sx Arcticset (Approx.) 572 sx PF 'E', 250 sx 'G' 400 sx Class 'G' MD TVD 112' 112' 2936' 2529' 10840' 7479' Perforation depth: measured 10328' - 10342', 10355' - 10361', 10442' - 10462', 10475' - 10507' (squeezed) 5460' - 5480', 5680' - 5700', 5780' - 5800' (open) true vertical 7049' - 7061 ', 7072' - 7077', 7144' - 7161 ', 7172' - 7198' (squeezed) 3905' - 3917', 4047' - 4060', 4114' - 4127' (open) Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80, EUE 8rd tubing to 5324' Packers and SSSV (type and measured depth) Sand Frac Pack Assembly with a 7" HES Versatrieve packer at 5395' and a 7" HES 'BBl' packer at 5580'; 7" HES 'BBl' packer at 5725'; 7" HES Fas Drill Bridge Plug at 5815'; 7" x 3-1/2" SABL-3 Baker packer w/K-anchor at 10019' 13. Stimulation or cement squeeze summary Sand Frac Intervals treated (measured) 5460' - 5800' Treatment description including volumes used and final pressure 5460' - 5480' 09/29/98 (N Sand) - 93.4 M# 16/20 Carbolite behind screens, 2536 psi 5680' - 5700' 09/26/98 (CA Sand) - 48.5 M# of resin coated 16/20 Carbolite behind pipe, 2300 psi 5780' - 5800' 09/26/98 (OB Sand) - 99.8 M# of resin coated 16/20 Carbolite behind pipe, 2679 psi 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 5. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant III " Prepared By Name/Number: I16. Status of well classifications as: [] Oil [] Gas [] Suspended Service Date Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Facility M Pt J Pad Progress Report Well MPJ-09 Page Rig (tl~itt~ JL/a,~t-..r qsir..q Date 1 10 February 99 Date/Time 17 Sep 98 18 Sep 98 19 Sep 98 20 Sep 98 21 Sep 98 06:00-06:15 06:15-11:00 11:00-19:30 19:30-20:00 20:00-21:00 21:00-21:15 21:15-22:00 22:00-23:00 23:00-23:30 23:30-01:15 01:15-01:30 01:30-01:45 01:45-02:15 02:15-03:00 03:00-05:00 05:00-06:00 06:00-09:00 09:00-10:00 10:00-10:30 10:30-11:30 11:30-12:00 12:00-13:00 13:00-14:00 14:00-16:00 16:00-18:00 18:00-19:30 19:30-21:15 21:15-21:30 21:30-22:15 22:15-22:30 22:30-23:30 23:30-01:00 01:00-06:00 06:00-06:15 06:15-09:30 09:30-10:30 10:30-13:30 13:30-14:00 14:00-18:00 18:00-18:15 18:15-19:00 19:00-19:30 19:30-23:30 23:30-00:30 00:30-02:30 02:30-05:00 05:00-06:00 06:00-07:30 07:30-08:30 08:30-18:00 18:00-18:15 18:15-02:00 02:00-02:30 02:30-03:30 Duration 1/4 hr 4-3/4 hr 8-1/2 hr 1/2 hr lhr 1/4 hr 3/4 hr lhr 1/2 hr 1-3/4 hr 1/4 hr 1/4 hr 1/2 hr 3/4 hr 2hr lhr 3hr lhr 1/2 hr lhr 1/2hr lhr lhr 2hr 2hr 1-1/2 hr 1-3/4 hr 1/4 hr 3/4 hr 1/4 hr lhr 1-1/2 hr 5hr 1/4 hr 3-1/4 hr lhr 3hr 1/2 hr 4hr 1/4 hr 3/4 hr 1/2 hr 4hr lhr 2hr 2-1/2 hr lhr 1-1/2 hr lhr 9-1/2 hr 1/4 hr 7-3/4 hr 1/2 hr lhr Activity Held safety meeting Rig waited · Equipment Rig moved 100.00 % Rigged up Drillfloor / Derrick Installed High pressure lines Held safety meeting Installed High pressure lines Tested High pressure lines Retrieved Hanger plug Circulated at 5244.0 ft Monitor wellbore pressures Installed Hanger plug Removed High pressure lines Removed Xmas tree Installed BOP stack Installed Well control Tested All functions Rig waited · Equipment Retrieved Hanger plug Retrieved Tubing hanger Flow check Laid down 34.0 ft of Tubing Installed Retrievable packer Removed BOP stack Removed Tubing head spool Installed Tubing head spool Installed BOP stack Installed BOP test plug assembly Tested BOP stack Retrieved BOP test plug assembly Retrieved Retrievable packer Rigged up Completion string handling equipment Laid down 2034.0 ft of Tubing Held safety meeting Laid down 3351.0 ft of Tubing Retrieved Electrical submersible pumps Rigged up Drillstring handling equipment Made up BHA no. 1 Singled in drill pipe to 4320.0 ft Held safety meeting Singled in drill pipe to 5443.0 ft Reverse circulated at 5459.0 ft Circulated at 5459.0 ft Circulated at 5459.0 ft Circulated at 5459.0 ft Circulated at 5459.0 ft Rest hole at 5459.0 ft Rest hole at 5459.0 ft (cont...) Circulated at 5459.0 ft Reverse circulated at 6116.0 ft Held safety meeting Reverse circulated at 7019.0 ft Serviced Mud pumps Reverse circulated at 7144.0 ft Facility M Pt J Pad Progress Report Well MPJ-09 Rig (null) Page Date 2 10 February 99 Date/Time 22 Sep 98 23 Sep 98 24 Sep 98 03:30-04:00 04:00-06:00 06:00-06:15 06:15-17:30 17:30-18:00 18:00-18:15 18:15-19:00 19:00-23:00 23:00-01:15 01:15-02:00 02:00-04:30 04:30-05:00 05:00-06:00 06:00-06:15 06:15-06:45 06:45-07:00 07:00-08:00 08:00-09:00 09:00-12:00 12:00-14:00 14:00-16:00 16:00-16:30 16:30-17:00 17:00-17:30 17:30-18:00 18:00-18:15 18:15-20:30 20:30-21:30 21:30-22:00 22:00-01:30 01:30-02:30 02:30-03:00 03:00-03:15 03:15-04:00 04:00-06:00 06:00-06:30 06:30-07:30 07:30-09:30 09:30-10:00 10:00-11:00 11:00-13:00 13:00-13:30 13:30-15:00 15:00-15:30 15:30-16:30 16:30-17:00 17:00-18:00 18:00-19:00 19:00-21:00 21:00-21:30 21:30-22:00 22:00-00:30 00:30-02:00 02:00-02:30 Duration 1/2 hr 2hr 1/4 hr 11-1/4 hr 1/2 hr 1/4 hr 3/4 hr 4hr 2-1/4 hr 3/4 hr 2-1/2 hr 1/2 hr lhr 1/4 hr 1/2 hr 1/4 hr lhr lhr 3hr 2hr 2hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/4 hr 2-1/4 hr lhr 1/2 hr 3-1/2 hr lhr 1/2 hr 1/4 hr 3/4 hr 2hr 1/2 hr lhr 2hr 1/2 hr lhr 2hr 1/2 hr 1-1/2 hr 1/2 hr lhr 1/2 hr lhr lhr 2hr 1/2 hr 1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr Activity Singled in drill pipe to 7372.0 ft Reverse circulated at 7362.0 ft Held safety meeting Reverse circulated at 7990.0 ft Reverse circulated at 7990.0 ft Held safety meeting Reverse circulated at 8020.0 ft Fill pits with Brine Reverse circulated at 8090.0 ft Flow check Pulled out of hole to 189.0 ft Pulled BHA Removed Bell nipple Held safety meeting Worked on BOP - BOP stack Held safety meeting Rigged up Logging/braided cable equipment Conducted electric cable operations Perforated from 5780.0 ft to 5800.0 ft Perforated from 5680.0 ft to 5700.0 ft Perforated from 5460.0 ft to 5480.0 ft Rigged down Logging/braided cable equipment Worked on BOP - BOP stack Installed Bell nipple Made up BHA no. 2 Held safety meeting R.I.H. to 7970.0 ft Reverse circulated at 8001.0 ft Flow check Laid down 5571.0 ft of 3-1/2in OD drill pipe Pulled out of hole to 201.0 ft Pulled BHA Held safety meeting Rigged up Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations (cont...) Rigged down Logging/braided cable equipment Rig waited: Equipment Made up BHA no. 3 R.I.H. to 2677.0 ft Singled in drill pipe to 3870.0 ft Reverse circulated at 3870.0 ft Singled in drill pipe to 5945.0 ft Reverse circulated at 5945.0 ft Serviced Block line Pulled out of hole to 5470.0 ft Held safety meeting Held safety meeting Pulled out of hole to 214.0 ft Pulled BHA Rigged up Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations Rigged down Logging/braided cable equipment Facility M Pt J Pad Progress Report Well MPJ-09 Page Rig (null) Date 3 10 February 99 Date/Time 25 Sep 98 26 Sep 98 02:30-03:30 03:30-03:45 03:45-04:30 04:30-05:30 05:30-06:00 06:00-06:15 06:15-08:00 08:00-09:15 09:15-09:30 09:30-10:00 10:00-11:30 11:30-12:00 12:00-12:30 12:30-14:00 14:00-14:30 14:30-14:45 14:45-15:00 15:00-16:30 16:30-18:30 18:30-21:30 21:30-00:30 00:30-03:00 03:00-06:00 06:00-06:15 06:15-07:00 07:00-07:30 07:30-08:00 08:00-08:30 08:30-10:30 10:30-11:00 11:00-11:30 11:30-17:30 17:30-18:00 18:00-18:15 18:15-20:00 20:00-22:30 22:30-23:30 23:30-00:30 00:30-01:00 01:00-02:00 02:00-02:30 02:30-02:45 02:45-03:30 03:30-04:00 04:00-05:30 05:30-06:00 06:00-06:45 06:45-07:00 07:00-07:45 07:45-08:30 08:30-12:00 12:00-12:30 12:30-13:00 13:00-13:30 Duration lhr 1/4 hr 3/4 hr lhr 1/2 hr 1/4 hr 1-3/4 hr 1-1/4 hr 1/4 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/4 hr 1/4 hr 1-1/2 hr 2hr 3hr 3hr 2-1/2 hr 3hr 1/4 hr 3/4 hr 1/2 hr 1/2 hr 1/2 hr 2hr 1/2 hr 1/2hr 6hr 1/2 hr 1/4 hr 1-3/4 hr 2-1/2 hr lhr lhr 1/2 hr lhr 1/2 hr 1/4 hr 3/4 hr 1/2 hr 1-1/2 hr 1/2 hr 3/4 hr 1/4 hr 3/4 hr 3/4 hr 3-1/2 hr 1/2 hr 1/2 hr 1/2 hr Activity Rigged up Drillstring handling equipment Made up BHA no. 4 R.I.H. to 2654.0 ft Singled in drill pipe to 3814.0 ft Reamed to 3824.0 ft Held safety meeting Reamed to 3877.0 ft Pulled out of hole to 191.0 ft Pulled BHA Made up BHA no. 5 R.I.H. to 3840.0 ft Singled in drill pipe to 3876.0 ft Reamed to 3876.0 ft Pulled out of hole to 191.0 ft Pulled BHA Removed Bell nipple Worked on BOP - BOP stack Rigged up Logging/braided cable equipment Conducted electric cable operations Set downhole equipment (wireline) Set downhole equipment (wireline) Serviced Setting tools Set downhole equipment (wireline) Held safety meeting Rigged down Logging/braided cable equipment Installed Bell nipple Retrieved Wear bushing Installed BOP test plug assembly Tested All functions Retrieved BOP test plug assembly Installed Wear bushing Installed Other sub-surface equipment Singled in drill pipe to 876.0 ft Held safety meeting Singled in drill pipe to 2333.0 ft Ran Tubing in stands to 5575.0 ft Stung into Permanent packer Set packer at 5308.0 ft with 0.0 psi Held safety meeting Rigged up High pressure lines Tested High pressure lines Injectivity test - 75.800 bbl injected at 2435.0 psi Monitor pressures FRAC job - 205.000 bbl injected at 3465.0 psi Monitor pressures Tested Permanent packer - Via annulus and string Tested Permanent packer - Via annulus and string (cont...) Installed High pressure lines FRAC job - 924.800 bbl injected at 2679.0 psi Reverse circulated at 5745.0 ft Monitor pressures Bleed down well Functioned Retrievable packer Ran Drillpipe in stands to 5757.0 ft Facility M Pt J Pad Progress Report Well MPJ-09 Page 4 Rig (null) Date 10 February 99 Date/Time 27 Sep 98 28 Sep 98 29 Sep 98 30 Sep 98 13:30-13:45 13:45-14:00 14:00-14:30 14:30-14:45 14:45-15:15 15:15-15:30 15:30-15:45 15:45-16:00 16:00-16:15 16:15-16:30 16:30-17:00 17:00-17:30 17:30-19:30 19:30-20:00 20:00-20:45 20:45-21:00 21:00-02:00 02:00-02:30 02:30-03:30 03:30-06:00 06:00-06:15 06:15-06:30 06:30-10:30 10:30-11:30 11:30-12:30 12:30-13:00 13:00-18:00 18:00-18:15 18:15-20:00 20:00-22:30 22:30-23:15 23:15-01:30 01:30-02:00 02:00-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-11:30 11:30-13:30 13:30-14:00 14:00-15:00 15:00-17:00 17:00-20:00 20:00-01:30 01:30-04:30 04:30-06:00 06:00-09:00 09:00-10:00 10:00-12:00 12:00-16:00 16:00-18:00 18:00-02:30 02:30-05:00 Duration 1/4 hr 1/4 hr 1/2 hr 1/4 hr 1/2 hr 1/4 hr 1/4 hr 1/4 hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 2hr 1/2 hr 3/4 hr 1/4 hr 5hr 1/2 hr lhr 2-1/2 hr 1/4hr 1/4 hr 4hr lhr lhr 1/2 hr 5hr 1/4 hr 1-3/4 hr 2-1/2 hr 3/4 hr 2-1/4 hr 1/2 hr lhr 2hr lhr 1/2 hr lhr 4hr 2hr 1/2hr lhr 2hr 3hr 5-1/2 hr 3hr 1-1/2 hr 3hr lhr 2hr 4hr 2hr 8-1/2 hr 2-1/2 hr Activity Functioned Retrievable packer Injectivity test - 15.000 bbl injected at 1000.0 psi Circulated at 5757.0 ft Pulled out of hole to 5694.0 ft Functioned Retrievable packer Reverse circulated at 5694.0 ft Functioned Retrievable packer Functioned Retrievable packer Installed High pressure lines Held safety meeting Tested High pressure lines FRAC job - 276.000 bbl injected at 3380.0 psi Monitor pressures FRAC job - 679.000 bbl injected at 2300.0 psi Reverse circulated at 5646.0 ft Rigged down High pressure lines Monitor pressures Bleed down well Functioned Retrievable packer Pulled Tubing in stands to 627.0 ft Held safety meeting Serviced Drillfloor / Derrick Rigged down sub-surface equipment - Other sub-surface equipment Rigged up Drillstring handling equipment Made up BHA no. 6 Tested Other sub-surface equipment - Via string Singled in drill pipe to 4530.0 ft Held safety meeting Singled in drill pipe to 5575.0 ft Worked toolstring at 5575.0 ft Laid down 344.0 ft of 2-3/8in OD drill pipe Pulled out of hole to 117.0 ft Pulled BHA Made up BHA no. 7 R.I.H. to 5273.0 ft Singled in drill pipe to 5618.0 ft Held safety meeting Singled in drill pipe to 5719.0 ft Circulated at 5719.0 ft Singled in drill pipe to 5807.0 ft Drilled installed equipment - Cement retainer Circulated at 5807.0 ft Singled in drill pipe to 7100.0 ft Circulated at 7100.0 ft Laid down 7100.0 ft of 2-7/8in OD drill pipe Worked on BOP - Lubricator Conducted electric cable operations Installed Permanent packer Worked on BOP - Bell nipple Rigged up sub-surface equipment - Gravel pack tool Ran Tubing to 5487.0 ft (3-1/2in OD) Set packer at 5395.0 ft with 3700.0 psi FRAC job - 1777.000 bbl injected at 2536.0 psi Circulated at 5395.0 ft Facility M Pt J Pad Progress Report Well MPJ-09 Page 5 Rig (null) Date 10 February 99 Date/Time 01 Oct 98 02 Oct 98 03 Oct 98 04 Oct 98 05 Oct 98 05:00-06:00 06:00-06:30 06:30-11:30 11:30-15:00 15:00-18:30 18:30-23:30 23:30-04:30 04:30-06:00 06:00-07:00 07:00-10:30 10:30-12:30 12:30-14:30 14:30-18:00 18:00-21:30 21:30-00:00 00:00-03:30 03:30-05:30 05:30-06:00 06:00-08:00 08:00-10:00 10:00-12:00 12:00-15:00 15:00-18:00 18:00-19:00 19:00-23:00 23:00-00:00 00:00-02:30 02:30-03:30 03:30-06:00 06:00-08:30 08:30-11:30 11:30-17:00 17:00-18:00 18:00-19:00 19:00-21:00 21:00-00:30 00:30-02:00 02:00-05:00 05:00-06:00 06:00-12:00 12:00-16:30 16:30-18:00 18:00-00:30 00:30-02:30 02:30-04:30 04:30-06:00 06:00-07:00 07:00-10:00 Duration lhr 1/2 hr 5hr 3-1/2 hr 3-1/2 hr 5hr 5hr 1-1/2 hr lhr 3-1/2 hr 2hr 2hr 3-1/2 hr 3-1/2 hr 2-1/2 hr 3-1/2 hr 2hr 1/2 hr 2hr 2hr 2hr 3hr 3hr lhr 4hr lhr 2-1/2 hr lhr 2-1/2 hr 2-1/2 hr 3hr 5-1/2 hr lhr lhr 2hr 3-1/2 hr 1-1/2 hr 3hr lhr 6hr 4-1/2 hr 1-1/2 hr 6-1/2 hr 2hr 2hr 1-1/2 hr lhr 3hr Activity Laid down 937.0 ft of Tubing Held safety meeting Laid down 5395.0 ft of Tubing Conducted slickline operations on Slickline equipment - Tool run Ran Drillpipe in stands to 5418.0 ft Worked stuck pipe at 5418.0 ft Pulled out of hole to 0.0 ft Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Ran Drillpipe in stands to 5402.0 ft Reverse circulated at 5448.0 ft Pulled out of hole to 0.0 ft R.I.H. to 5450.0 ft Fished at 5450.0 ft Pulled out of hole to 0.0 ft R.I.H. to 5456.0 ft Worked stuck pipe at 5456.0 ft Pulled out of hole to 5000.0 ft Pulled out of hole to 0.0 ft R.I.H. to 5456.0 ft Worked stuck pipe at 5456.0 ft Pulled out of hole to 0.0 ft R.I.H. to 5459.0 ft Worked stuck pipe at 5459.0 ft Pulled out of hole to 0.0 ft Serviced Other sub-surface equipment R.I.H. to 5459.0 ft Worked toolstring at 5468.0 ft Pulled out of hole to 0.0 fl R.I.H. to 5468.0 ft Jarred stuck pipe at 5468.0 ft Circulated at 5468.0 ft Pulled out of hole to 3668.0 ft Serviced Block line Pulled Drillpipe in stands to 0.0 ft Tested BOP stack Made up BHA no. 8 R.I.H. to 5468.0 ft Milled Gravel pack tool at 5468.0 ft Milled Gravel pack tool at 5470.0 ft Laid down 5470.0 ft of 3-1/2in OD drill pipe Pulled BHA Ran Tubing to 5324.0 ft (3-1/2in OD) Installed Tubing hanger Removed BOP stack Installed Xmas tree Tested Xmas tree Freeze protect well - 75.000 bbl of Diesel MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission David John~-''/~'-~ DATE: 9/25/98 Chairma~ THRU: Blair Wondzell, ~-J FILE NO: .DOC P. I. Supervisor W J ~ FROM: Larry Wade, SUBJECT: Petroleum Inspector BOP Test Nabors 4 ES MPU J-09 PTD 94-101 September 25,1998: I traveled to Milne Pt-to witness a BOP test on Nabors 4ES. Everything went smooth and the hands were experienced. The rig appeared to be in good shape after going through a summer maintenance shutdown. SUMMARY: Witnessed a BOP test on Nabors 4ES, 0 failures,3 hours. Attachments: ak9giyfe.xls cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: X DATE: Nabors Rig No. 4ES PTD# 94-101 Rig Ph.# BPX/SSD Rep.: David Oryail MPU J-Og Rig Rep.: Set @ 10840' Location: Sec. Weekly X m. Other Test Pressures TEST:DATA 9/25/98 659-4154 Donny Haberthur R. Meridian 250/5000 MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok PTD On_Location n/a Standing Order Posted BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve (Gen) X Well Sign X Dd. Rig o Hazard Sec. X Quan. Test Press. I 250/3000 1 25O/5OOO 250/5000 f 25O/5OOO 1 25O/5OO0 2 250/50OO f 250,/5000 250/5000 PIF P P P P P P MUD SYSTEM: V'~su al Alarm Tdp Tank X X Pit Level Indicators X X Flow Indicator X X Meth Gas Detector X X H2S Gas Detector X X FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure PtF 250/5000 1 250/5000 P I 250/5000 P I 250/5000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 11 250/5000 P 26 250/5000 P I Functioned 1 Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 1 oo 3,000 1,500 minutes 40 sec. minutes 10 sec. X Remote: X Psig. TEST:RESULTS Number of Failures: ,Test Time: 3.0 Hours. Number of vaNes tested '/6 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I : REMARKS: Distribution: odg-Well File c - Oper./Rig c - Database c - Tdp Rpt File c -Inspector F1-021L (Rev.12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO WaNed By: W"rtnessed By: Akggye Larry Wade STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other Run 27/8" Comp. w/ESP & Heat Trace 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2347' NSL, 2090' EWL, Sec. 28, T13N, R10E, UM At top of productive interval 2592' NSL, 1548' WEL, Sec. 20, T13N, R10E, UM At effective depth 2853' NSL, 1590' WEL, Sec. 20, T13N, R10E, UM At total depth 2912' NSL, 1616' WEL, Sec. 20, T13N, R10E, UM 5. Type of well: Development Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE - 65' 7. Unit or Property Name Milne Point Unit 8. Well Number MPJ-09 9. Permit Number / Approval No. 94-101 10. APl Number 50- 029-22495 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 10860' feet Plugs (measured) 7431' feet 10754' feet Junk (measured) 7344' feet Length Size Ce me nted Structural Conductor 80' 13 3/8" 250 sx Arcticset (approx) Surface 2905' 9 5/8" 572 sx PF 'E', 250 sx 'G' Intermediate Production 10811' 7" 400 sx Class 'G' Liner MD TVD 112' 112' 2936' 2529' 10840' 7479' Perforation depth: measured 10328'-10342', 10355'-10361', 10442'-10462', 10475'-10507' true vertical 7049-7061 7072-7077 7144-7161 7172-7198 Tubing (size, grade, and measured depth) 2 7/8" 6.3# L-80 to 5512' Packers and SSV (type and measured depth) 7" x 3.5" SABL-3 Baker Pkr @ 10019' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: l~oil [] Gas [] Suspended Service Water Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipAIvord ,//~/._(,¢'~ Title Engineering Supervisor Date Prepared By Name/Number: Mary Youngers 564-5242 Form 10-404 Rev. 06/15/88 Submit In Duplicate~ SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING- BPX/ARCO Well Name: MPJ-09 Rig Name: N-4ES AFE# 339043 Accept Date: 04/16/97 Spud Date: . Release Date: 04/20/97 APRIL 17, 1997 RIG ACCEPTED @ 0500 ON 04/16/97. RIG LINES TO COMP TREE & TT TEST LINES 3000# PULL BPV, TBG 500# ANNUL "0" LOAD/FILTER SEAWATER TO PITS. DICPL WELL W/SEAWATER/MONT STATIC INSTALL TWC. ND COMP TREE NU BOP INSTALL 3.5 PIPE RAMS TEST BOP TO SSD POLICY, AOGCC WAIVE WITNESS MU LANDING JT BOLDS ATTEMPT TO PULL TBG, NOT CUT, WORK TBG PULL 140k ATTEMPT TO BREAK CUT BY ROTATE, NO GO. RIG UP SWS W PUMP IN SUB. RIH W/CHEM CUTTER, CUT TBG @ 9893' VERIFY CUT POH RIG DOWN SWS LD HANGER LND JT PUP & XO MON WELL. POH LD 3.5 TBG. APRIL 18, 1997 TEST CSG TO 2000 PSI. MIU BHA #1 RIH W/SAME TO TBG STUB @ 9900' 4ES KB. REV CIRC CSG WASH PER PROGRAM & FOLLOW W/9.0 PPG FILTERED BRINE POOH LD 3 ~ DP. APRIL 19, 1997 POOH LD 3 ~" DP. RIG UP SHOOTING FLG. RIG UP SWS LUB & TEST TO 500 PSI. POH & RIG DOWN CHANGE RAMS TO 2 7/8" & TEST TO 250 LOW & 5000 HIGH. RIG UP TO RUN & INSPECT CENTRALIFT PUMP. MU ESP ASSY. RIH W/ESP ASSY. APRIL 20, 1997 RIH W/ESP COMP ON 2 7/8" TBG & INSTALL HEAT TRACE TAPE SPACE OUT TBG SPLICE ESP INSTALL HEAT TRACE PENETRATOR & ESP LAND TBG RILDS INSTALL BPV. ND BOP & NU COMP TREE & TEST TO 5000 PSI & FINAL TEST ON ESP & HEAT TRACE PENETRATORS OK. FREEZE PROTECT WELL W/DIESEL TO 2000' RIG DOWN CELLAR & SECURE WELL. RIG RELEASED @ 0600 HRS. Page 1 of 1 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPJ-09 Rig Name: N-4ES AFE# 339052 Accept Date: 08/04/97 Spud Date: . Release Date: 08/11/97 AUGUST 04, 1997 ACCEPT RIG @ 0500 HRS. SET TIGER TANK RU HARD LINES PREP TO PULL BPV. AUGUST 05, 1997 PULL BPV W/LUB. RILL RIG PITS W/FILTERED SW. TEST LINES TO 3000 PSI - GOOD. BLEED GAS CIRCULATE WELL W/FILTERED SW. MONITOR WELL DEAD INSTALL TWC ND TREE NU BOPE START BOPE TEST CONTINUE W/BOP TEST PER BP/AOGCC REQUIREMENTS. PIPE RAMS FAILED TO TEST. CHANGE OUT RAMS RETEST, GOOD. FINISH BOP TEST STATE WAIVED RIGHT TO WITNESS TEST (D. AMOS). PULL TWC PU LANDING JT. BOLDS. ATTEMPT TO PULL TBG HANGER TO FLOOR. PUMP IS "SANDED IN" ATTEMPT TO PULL @ 80% NO LUCK. DISCUSS OPTIONS W/TOWN. CLOSE IN TBG & ATTEMPT TO PUMP DOWN ANNULUS NO LUCK. PUMP 1.5 BBLS STOP @ 1500 PSI. BLEED OFF TO 1300 PSI AFTER 5 MIN. CALL OUT "FREE POINT" SERVICES, SWS & FISHERMAN. WO SERVICES. AUGUST 06, 1997 WO FREE POINT SERVICES TO TRAVEL TO SLOPE. RU SWS RIH W/FREE POINT TOOL. LOG WELL PU @ 5432' POOH. DISCUSS RESULTS & OPTIONS W/TOWN. CALL OUT HOWCO SLICK LINE UNIT. RU & RIH W/LIB TO 5450' WLM. RECOVERED "PICTURE" OF FINE SAND. RIH W/PUMP BAILER START BAILING SAND FROM INSIDE TUBING. CLEANED OUT TO 5463' WLM (13') RIH W/LIB POOH NO IMPRESSION. RIH W/HYDRO STATIC BAILER & CONTINUE TO CLEAN OUT AROUND TOP OF PUMP (ROTOR) AUGUST 07, 1997 POOH W/IMPRESSION BLOCK. RIH W/OVERSHOT/LATCH RELEASED. LD 1.5" TOOLS, MU 1 7/8" TOOL RIH W/GS OVERSHOT JAR ON ROTOR POOH RIH W/GS TOOL LATCH ONTO GU/JAR ON ROTOR/POOH. CIRC COND HOLE RIH W/GR & OVERSHOT LATCH ON & JAR ON ROTOR POH GR SHEARED RIH W/GR TOOL POH W/GR TOOL & OVERSHOT. RIH W/GR & OVERSHOT LATCH ONTO ROTOR & JAR TOOL PULLED OF RIH W/GS LATCH ONTO OVERSHOT & ROTOR NO GO POH RIG DOWN WL. MU LANDING JT TO HANGER CIRC WORK TUBING WO WIRELINE. RIG UP SWS RIH W/JET CUTTER CUT TUBING @ 5433'/POH. WORK TUBING PULL FREE @ 120k (70k OVER). RIG DOWN SWS. LD LANDING JT, HANGER & PUP JTS RIG UP FLOOR TO PULL TBG. Page 1 of 2 SUMMARY OF DALLY OPERATIONS AUGUST 08, 1997 LUB RIG POOH W/2 7/8 ESP & HEAT TRACE 170 JTS TBG & 22.50' OF JT #171 LEFT APPROX 32' OF ESP CABLE ABOVE TBG CUT RIG FLOOR TO RUN DP. INSTALL 3.5 PIPE RAMS. TEST SAME TO 5000# PULL TEST PLUG INSTALL WR. LOAD PIPE SHED W/DP STRAP SAME. MU BHA GUIDE CATCHER O/S BOWL TOP EXT. TOP SUB/PO SUB BJ OIL JAR 12 DC ACC JAR. WASH OVER MILL STUMP FISH & ESP CABLE 17' TAG TOP PUMP 5450' CIRC HIGH VIS SWEEP. POH LD FISH BHA RECOVERED APPROX 12' WASH PIPE FULL OF CUT UP ESP CABLE. MU FISH BHA (AS ABOVE) RIH W/SAME. AUGUST 09, 1997 LUB RIG RIH W/FISH TOOL 5413' PU KELLY. ATTEMPT TO DRESS TOP OF FISH, FISH DROPPING CHASED FISH TO 5480' MIX PUMP XANVIS SWEEP MON WELL. TOH W/FISH ASSY. MU BHA #3 TIH TO 5472' CIRC @ 40 SPM, 800# CONT TRIP IN W SINGLES F/PIPE SHED TO 7431' SET DOWN 20k CIRC @ 1800# DROP PUMP SUB DART OPEN W/25003 TOH TO 5000' SPOT 20 BBLS HIGH VIS PILL FOR FLUID LOSS. TOH W/FISH, PUMP ASSY LD SAME. LD FISH (PUMP ASSY) & BHA MU SHOE DP RIH SLIP CUT 42' DRILL LINE. SPACE OUT CSG SCRAPER/RIH FOR CLN OUT/RUN INTO 7400'. AUGUST 10, 1997 TOH W/DP LD TO 5367' MIX REV CIRC CSG WASH 4 BPM DISPLACE W/CLN SEAWATER CLN PITS FILL W/CLN SEAWATER. TOH, LD DP CSG SCRAPER 4 3A DC. PULL WR INSTALL TEST PLUG INSTALL 2 7/8 PIPE RAMS. TEST BOP 5000# PULL TEST PLUG CLR FLOOR RIG TO RUN TBG/ESP MUESP ASSY PIGTAIL TEST LINE MOTOR TIH W/ESP ASSY INSTALL BANDS EVERY 6" ON FIRST JT ABOVE UNIT RIG TO RUN HEAT TRACE EQUIP. TIH W/2 7/8 ESP. AUGUST 11, 1997 RIH W/ESP ASSY SPACE OUT HEAT TRACE ESP CABLE INSTALL TBG HANGER. ATTACH HEAT TRACE TEST PENETRATOR. ATTEMP TO SPLICE HANGER PIGTAIL FOR ES/SPLICE TO SHORT. W/O NEW PIGTAIL F/DEADHORSE, RESPLICE PIGTAIL ATTACH TEST PEN. LAND HANGER RILDS BK OUT LANDING JT. INSTALL TWC. ND BOP NU COMPL TREE. TEST ADAPTER TREE TO 5000# MAKE FINAL TST ON HEAT TRACE ESP PENETRATOR CIRC FREEZE PROT TEST LINES 12 BBLS TBG/68 BBLS ANNULI. RIG RELEASED @ 0600 HRS. Page 2 of 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: THE APPLICATION OF BP ) EXPLORATION (ALASKA) INC. ) for an order granting an exception to ) spacing requirements of Title 20 AAC ) 25.055 to provide for the completion of ) the BP Milne Point Unit MPJ-09 ) oil well in an undefined oil pool. ) Conservation Order No. 396 BP Exploration (Alaska), Inc. MPJ-09 July 16, 1997 IT APPEARING THAT: . BP Exploration (Alaska), Inc. submitted an application dated June 17, 1997 requesting exception to 20 AAC 25.055(a)(3)to allow the completion of the BP Milne Point Unit MPJ-09 oil well in an undefined oil pool within the Ugnu Formation closer than 500 feet to a quarter-section line. . Notice of opportunity for public hearing was published in the Anchorage Daily News on July 1, 1997 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: . The BP MPJ-09 well is a deviated hole drilled from a surface location 2347' from the south line (FSL) and 2090' from the east line (FEL) of Section 28, T13N, R10E, Umiat Meridian (UM) with a proposed Ugnu Formation producing interval from 4298' FSL and 87' FEL of Section 29, T13N, R10E, ~ to 4427' FSL and 151 FEL of Section 29, T13N, R10E, UM. 2. Offset owner, Occidental Petroleum Corporation has been duly notified. . An exception to 20 AAC 25.055(a)(3) is necessary to allow the proposed completion of this well. Conservation Order No. 396 July 16, 1997 Page 2 CONCLUSION: Granting a spacing exception to allow the completion of the BP MPJ-09 well within the Ugnu Formation undefmed oil pool as proposed will not result in waste nor jeopardize correlative rights. NOW, THEREFORE, IT IS ORDERED: BP Exploration (Alaska), Inc.'s application for exception to 20 AAC 25.055 for the purpose of completing the Milne Point Unit MPJ-09 well as proposed is approved. DONE at Anchorage, Alaska and dated July 16, 1997. David W. Johnston, Alaska and Gas Corn Commission Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court nms from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). STATE OF ALASKA ALASK, .)IL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plugback to Re-complete 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development [--I Exploratory [] Stratigraphic [~]Service 4. Location of well at surface 2347' NSL, 2090' EWL, SEC. 28, T13N, R10E At top of productive interval 4522' NSL, 200' WEL, SEC. 29, T13N, R10E At effective depth 2495' NSL, 1523' WEL, SEC. 20, T13N, R10E At total depth 2912' NSL, 1616' WEL, SEC. 20, T13N, R10E 6. Datum Elevation (DF or KB) KBE = 65.06' 7. Unit or Property Name Milne Point Unit 8. Well Number MPJ-09 9. Permit Number 94-101 / 397-074 10. APl Number 50-029-22495 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 10860 feet true vertical 7431 feet Effective depth: measured 10083 feet true vertical 6693 feet Casing Plugs (measured) Junk (measured) Cement plug at 10083' (4/9 0 L Packer fish at 9893' Length Size Cemented MD TVD Structural Conductor 80' 13-3/8" 250 sx Arcticset (Approx.) 112' 112' Surface 2905' 9-5/8" 572 sx PF 'E', 250 sx 'G' 2936' 2529' Intermediate Production 10811' 7" 400 sx Class 'G' 10840' 7479' Liner Perforation depth: measured 10328'-10342',10355'-10361' 10442'-10462' 10475'-10507'(squeez~)~~,~/~.--'~ , , 5460'-5480', 5792'-5802' (open) true vertical 7049'-7061', 7072'-7077', 7144'-7161', 7172'-7198' (squeezed) 3906'-3919', 4122'-4128' (open) ,J UI'4 '1 8 1997 Tubing (size, grade, and measured depth) 2-7/8" 6.3# L-80 tubing at 5512' Packers and SSSV (type and measured depth) 7" X 3-1/2" SABL-3 Baker packer w/K-anchor at 10019' ~rlc'Qo. ragf~ 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 4. Estimated date for commencing operation August 15, 1997 16. If proposal was verbally approved Name of approver Date approved Contact Engineer Name/Number: Bob Laule, 564-5195 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Kathy Campoamor, 564-5122 17. I hereby certify that the foregoing is trt~e and cprrect to the best of my knowledge Signed ~-/,-~ ~-~'-- ~/~'. ~ ' TimSchofie.d' /'~O ~(~ ~-",¢--'~-~A Title SeniorDrillinoj Engineer · - /// - Commission Use Only Conditions of Approval: Notify Commissid~"' so representative may witness Date I Approval No. 397-074 Plug integrity .,,,'" BOP Test ~ Location clearance __ . Mechanical Integrity Test Subsequent form requ. i~l:)- Approved by order of the Commission di'igl~qal Signed By ¢ ~,~,~ ~ 4,.~ ' ,¢, ~ /~ Commissioner Form 10-403 Rev. 06/15/88 i~avia W. johnston Date ~, ~'~-'¢ ./~)..,_ submit In Triplica(%? Scope of work for the MP J-09 workover is to decomplete the well, suspend the Schrader Bluff perforations with an isolation plug, perforate the Ugnu and recomplete with an ESP and 2-7/8" tubing to test the production of the Ugnu. Pre Rig activity Pull the dummy valve from the lower GLM above the ESP and set BPV. MIRU 4ES Pull BPV with lubricator kll well and set TWC. ND tree. NU BOP and test. Pull TWC with lubricator. Pull tubing, ESP and heat trace. RIH with GR/JB. RIH and set bridge plug. (temporary suspension of the Shrader Bluff Perforations) RU wireline and perforate the Ugnu formation. Run ESP with 3 glm's & heattrace to new setting depth. Set TWC. ND bop. Nu and test tree. TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 11, 1997 Bruce Policky Exploitation Manager - Western North Slope BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK. 99519-6612 Subje · ::~vIP~Ugnu Formation __ Production Test Dear Mr. Policky: The Commission received your letter dated May 14, 1997, indicating BP Exploration (Alaska), Inc.'s intention to proceed with a pump test of the high viscosity Ugnu oil zone in the Milne Point Unit. Neither this test nor regular production from the Ugnu formation by itself requires a permit from the AOGCC as long as there are no spacing, regulatory or commingling issues that require a variance. Production from the Ugnu formation should be reported separately to the Ugnu Undefined Pool, pool number 525160 for those months the well is tested. Commingling with Schrader Bluff Pool production will not be allowed until an application has been received and a conservation order issued to allow it. An application to expand the Schrader Bluff Pool to encompass the Ugnu formation is an alternative to commingling and probably a simpler procedure. Pooling the two formations would allow them to be produced together where appropriate and take advantage of viscosity reduction or dilution of the high viscosity Ugnu with lower viscosity oils. We look forward to hearing results of the test. If there are any questions regarding commingling or changing the pool definition, contact Jack Hartz or Bob Crandail at 279- 1433. · Chairman BP EXPLORATION BP Exploration (Alaska.) Inc, PO Box 196612 Anchorage. Alaska 99519-661 TELECOPY COMMUNICATIONS CENTER MESSAGE# TO: Name: , Company: Location: Fax # Confirm # FROM: Name & Ext,: ~,~x~-~h ~ Departmenf, .~ $_~ -- ~)~9/~ Mail Stop: f7~ ,~-~/ NOTES: · PAGES TO FOLLOW ,_~ ._ , (Do Not Include Cover Sheet) -A &', , SECURI~ C~SSIFICATION PRIVATE SECRET CONFIDENTIAL Telecopy # Confirm # For Communications Center Use Only Time In Time Sent Time Confirmed Confirmed By Operator 04:4~PM SHRRED SERVICES DRILLIMG Scope of work MP J-09 abandonment AFB 330301 Pre ,rig Test packoff Establish an, injection rate and pressure. Bullhead 5 bbl fresh water and 15 bbl class G cement with .2% CFR3, .2% Halad 344,,2%'HR5.15.8 ppg, 1.15 yield,5 gal/sk. Thickening time 3 hours + .75 hrs surface time. Fluid loss 100cc's/30 rain, The cement volume is based on setting a plug from 10607 to 10228. (One hundred feet either side of the preforations.) Displace with 5 bbl fresh water and 87,5bbl of sea water. This displacement volume shou, ld place the theoritical cement top 100' above the perforations. NOT, E critical displacement is 53bbl to get cement below minimun tubing cut depth of 6000' Make wireline drift run. Jet cut the tabing immediately above the packer. Circulate in freeze protection and set BPV. A permanent bridge plug will be set immediatelty above the tubing cut. If the cement job does not go as planned an additional cement plug 754. ft will be place obove the bridge plug, ,. scope o~ ~~ ~e~ R~ set Ai'"~R 1 4 199T Oil & Gas Oons, Commis~,' Anohorag~ ~0 R~ 11 'D7 04:4BPM SHARED SERVICES. DRILLIMG P,4×4 .,~ TREE: 3 1/8'-$M UJ-9 Proposed WELLHEAD: 11' 5M ~$ ~'~?" ORIG. KB, ELEV = 63.7' (N 22E) w/ 11" FMC Tubing Hanger, 3,5" NSCT ORIG, GL. ELEV-- 34' (N 22E) ~ift fhrea~, crossover. 3" CIW ~H" BPV RT To ~g, Spool = 28.8' f/RKB profile I~ ~ ~ K-55 8T$ x G~ 100' below tubing hanger KOP ~ 600' Max, hole angle = 59.8' ~ ~08'MD ~ 2-7/8' EUE-Brd 6.5~/~ and 7106'MD, Angle ~ TD = ~.67' ~ ~ L-80 used tubing Min. ID is ~,75' ~ 10,0~' , Initial ~OI dale: 3-~-~5 , Pups to be 2-7/8" L-B0 - 6.S~ EUE-Brd tubing L-80 Btm, /GLM above pump ~ / EsPOP i~ke at approx, 55~6' Stimulation Summ~ Set pump intake exactly 1' -No frac pedermed- ~ = below the lowest N sand peals I ~ ESPCP Kudu 180TP2000 Geothermal motor rated to 380 deg. F. OD = 5.~" ) ~18'I Howoo'ES' Cementer proposed Perfora~on S.a~ma~ ' ' SAND ~Top of Cement - leave at least 2000' SIZE SPF MD ~D. . ." of mthole belo~ the lowest peal. ~-1/2'' 5 5401'-5432' 3804'.38~' N ~I/2" 12 5~'-5813' 4~6'~072' O 6 F{'10~18'~ Baker ';~' Anchor . ~ , 10,019",~ Baker SABL 3.5" x 7" Pecker ~ 3.5" X-Nipplew/2.813" ID ~ ~ 3.5 XN. Nipple w/2.75" ID ~ -. ~ 3.5"NSCTWLEG ~~ '/'' ~114'-10,134' MarkerCsgOt. ~ ... DATE R~V. 8~ ~COMMENT$ , ~ILNE PQ]NT UNIT 2-24-97 TC Proposed Completion Diagram WELL J~.09] '-- ... .. BP EXPLORATION II I i ii STATE OF ALASKA ALASKA ~JiL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plugback to Re-complete 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 4. Location of well at surface 8. 2347' NSL, 2090' EWL, SEC. 28, T13N, R10E 9. At top of productive interval 2592' NSL, 1548' WEL, SEC. 20, T13N, R10E At effective depth 2853' NSL, 1590' WEL, SEC. 20, T13N, R10E At total depth 2912' NSL, 1616' WEL, SEC. 20, T13N, R10E 6. Datum Elevation (DF or KB) KBE: 65.06' 7. Unit or Property Name Milne Point Unit Well Number MPJ-09 Permit Number 94-101 10. APl Number 50-029-22495 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 10860 feet Plugs (measured) 7431 feet 10754 feet Junk (measured) 7344 feet Length Size Cemented Structural Conductor 80' 13-3/8" 250 sx Arcticset (Approx.) Surface 2905' 9-5/8" 572 sx PF 'E', 250 sx 'G' Intermediate Production 10811' 7" 400 sx Class 'G' Liner ORIGINAL MD 112' 2936' 10840' TVD 112' 2529' 7479' Perforation depth: measured true vertical 7049'-7061', 7072'-7077', 7144'-7161', 7172'-7198' 10328'-10342', 10355'-10361', 10442'-10462', 10475'-10507' Tubing (size, grade, and measured depth) 3-1/2" 9.3# L-80 to 10068' Packers and SSSV (type and measured depth) APR 1 I 199 ~ Cjl.& ~as Cons. Baker 'SABL-3' 3.5" X 7" Packer at 10019'. 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation April 14, 1997 16. If proposal was verbally approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water Injection Name of approver Date approved Contact Engineer Name/Number: Bob Laule, 564-5195 Prepared By Name/Number: Kathy Campoamor, 564-5122 17. I hereby certify that the foregoing is tr~e and c~r~'ect to the best of my knowledge Signed ~ ~ } ,4' ~ J Tim Schofield '"-/~(.4¢d"~ ~ ~,.~¢~ Title Senior Drilling Engineer // Commission Use Only Conditions of Approval: Notify Commissidn so representative may witness Plug integrity ~ BOP Test ~ Location clearance__ Mechanical Integri~ Test__ Subsequent form regaled 1~O~ Oov ~ Approved by order of the Commission ' ,-,~ W. Johnston ~~~-- Commissioner Form 10-403 Rev. 06/15/88 IApproval No.,,~;'¢_¢ ~'~ Date ,~¢,..,/~, ~ Submit In Triplicate (iieoiog~'ca J i,~ia~er'i'a'is ~nventor'y PEaHIT DATA T DATA_PLUS 9a,-~101 6257 ~0745.-~9075 CH/SBT/'GE/CCL 9a. --- i 01 6309 ~2946---. i 0860 ADN/' CDN/' DC ~2900- I 0800 9a'-. 'i0i CCi... ~43 ~ i--~L~-600 ~ 2650 ~7490 TVD 9a.---101 ~2900--i0800 ~650--7490 TVD 9a.--.'i0i ~10100 ..... i06i0 ~100~0 .... 10S70 pus Ar"e dr-'y d'itch sampies r'.equ~'r'ed? yes ~And Was 'the we'i'i cor'ed? yes Ar'e we i '1 'Les'ts r"equ~' r'ed? yes Ual 'is -in comp]'¥ance q 4 ,--'i 0 I 9 ~ ..... i 0 'i 9 4 ~ i 0 I CDN/DC C D R / D C CDR/DC PFC/PERF C C, ~4 k~ E N T S I n i' t '¥ a 'i - c~ ~-~ S. C r' i' p t '¥ 0 i"l (~ Rece'¥ y~o ved LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 21 September 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: DESCRIPTION 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF ECC No. Run # 1 6258.04 Run # 1 6472.01 Run # 1 Run # 1 6480.00 Run # 1 6482.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 or Received by:, _ _ ~,~ Please sign and return ~o: Petrotechnical Data Cente~ BP Exploration (Alaska) InS 9G0 East Benson Boulevard Anchorage, Alaska 9950~ .~.,~.. .... ~ ~ ~,_- - ' ~'~'l STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR FIECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVI(~~ Iniection t .~.~.~ 7. Permit Number 2. Name of Operator BPExploration(Alaska) Inc. ~:~j ~:'; 94-101 3. Address ,~/~H~?~--~'i 8. APl Number P. O. Box196612, Anchorage, Alaska99519-6612l:fir, f:,' : ....... .~- !'~ I, ~,, L. II · i-, e.," 9. Unit or Lease Name 4. Location of well at surface ~ t: 2347' NSL, 2090' EWL, SEC. 28, T13N, RiOE ,.~'.,, ~ Milne Point Unit At Top Producing Intervali/ J ....:iMAR 1~i, "~9(~5 lO. Well Number 2592' iSA, 1548' WEL, SEC. 20, T13N, R'IoE~,;'!U;; ~i .... MPJ-O9 i,.-r,C~_AIaS~ uu & Gas Cons, Commission 11. Field and Pool At Total Depth ..... ' .... ~l(~lora_~~ Mi/ne Point - Kuparuk River 2912' NSL, 1616' WEL, SEC. 20, T13N, RIOE 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 65.05' ADL 25515 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 7/29/94 8/6/94 1/11/95I N/A feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 10860' MD/7431' 10754' MD/7344' YES [] NO [] None feet MD 1800' (Approx.) 22. Type Electric or Other Logs Run GR/RES/NEU, CBL/GR 23. CASING, LINER AND CEMENTING RECORD SETRNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-FI-OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 54.5# K-55 32' 112' 24" 250 sx Arcticset (Approx.) 9-5/8" 40# L-80 31' 2936' 12-1/4' 572 sx PF "E'F250 sx "G" 7" 26# L-80 29' 10840' 8-1/2" 400 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET(MD) PACKER SET(MD) Gun Diameter4" 4 spf 3-1/2", L-80 10068' 10019' MD TVD 10328'-10342' 7049'-7061' 10355'-10361' 7072'-7077' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10442'-10462' 7144'-7161' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10475'-10507' 7172'-7198' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 3/1/95 Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SlZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (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. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE _-,. 30. GEOL~ MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Top C 10263' 6932' Top B 10263' 6932' Top A 10423' 7064' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,½-~ ~'/q,~- ~'~-~-(~¥~"' Title Drilling Engineer Suoervisor Date .~//~ J ?Y' -// - _ / fl INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none".,,~ EgEIVED Form 10-407 MAR 1 4 1995 Alaska 0il & Gas Cons. Commission ~ch0ra" MILNE POINT, ALASKA TO: Hendrix/Stevens FROM: Ketchum Well Name: MPUJ-09 Main Category: Electric-Line Sub Category: Initial Perforation Operation Date: 1/10-11/95 Date: J January 12, 1995 Atlas WL - $18,325.00 AFE # 330062 APC crew -- - $270.00 Total .... $18,595.00 II OBJECTIVE: Complete initial perforations as per program dated 12/29/94, then obtain SBHP. I[wHsIP= 490 psig I IAP=Opsig [OAP= 0 psig II · t~ i · ~1' , i ir , 11 JTIME { OPERATION Operation for 1/1095 and 1/11/95 0900 Atlas on location, waiting on rig equipment to allow access to the wellhead 1030 MIRU Atlas, tailgate, establish radio silence for the pad. 1 100 RIH w/ GR, CCL and 4" hollow carrier Alpha Jet perf. guns (32gms) @ 4SPF to perforate the following intervals: (Four perf. runs will be required.) 10,328'-10,342', 10,355'-10,361' 10,442'-10,462', and 10,475'-10,507'. Observed pressure change of 490 psi at surface. 2300 Perforations completed, MU TS w/ GR, CCL, HP Pressure gauge, and 8221XA Temp. gauge. TS total length: 38'8" 0145 Obtained a stable SBHP of 3502psi @ 10,417' MD (7121'TVD). 0 23 0 RDMO Atlas. RESULTS: Initial perforations created as per program dated 12/29/94, SBHP of 3502psi obtained @ 10,417'MD (7121'TVD). No spills or accidents. Surface pressure 490psi. RECEIVED MAR 1 4 1995 Ataska Oil & Gas Cons. Commission Anch0ra :, MP J-09 07/29/94 670' FINISH MOVING RIG F/MP J-06 TO MP J-09. CHANGE ADAPTER FLANGE ON DIVERTER AND NU SAME. HAD TO ADD 1.2' TO FLOW NIPPLE. LOAD RIG FLOOR WITH BHA, AND FINISH NU PITCHER NIPPLE AND FLOW LINES. PU BHA. CHECK FOR LEAKS AND FUNCTION TEST DIVERTER SYSTEM. SPUD AND DRILL F/112-194'. REPAIR TOP DRIVE. DRILL F/194-670'. 07/30/94 2,950' DRILLING F/670-2033'. CIRC BOTTOMS UP. SHORT TRIP TO JARS. NO PROBLEMS. DRILLING F/2033-2950'. CIRC LO/HI-VIS SWEEP. SHORT TRIP TO HWDP. NO FILL, NO PROBLEMS. CIRC LO/HI-VIS SWEEP. DROP EMS AND POH. RETRIEVE EMS AND LD BHA. RU TO RUN CASING. 07/31/94 2,950' FINISH RU TO ~IN 9 5/8" CASING. RUN 73 JTS 9 5/8" L-80 BTC CASING. SHOE @2936'.'CIRC AND COND MUD. HAD TO WAIT ON VAC TRUCKS CAUGHT BEHIND BIR MOVE. RU HOWCO. TEST LINES. MIX AND PUMP 572 SXS "E", FOLLOWED WITH250 SXS "G". DISPLACE WITH RIG PUMPS. BUMPED PLUG. FLOATS HELD. LD CEMENTING HEAD AND LANDING JT. ND DIVERTER. RU AND PUMP 60 SX PERMAFROST "C" TOP JOB. RD HOWCO AND CASING TOOLS. INSTALL SPEEDHEAD. NU 13 5/8" BOPE. TEST BOPE. 08/01/94 5,006' REPLACE 2 APl RING GASKETS AND FINISH TESTING BOPE. PULL TEST PLUG AND INSTALL LONG WEAR RING. PU BHA #2. ORIENT AND LOAD LWD/MWD. TEST MOTOR. RIG SERVICE. RIH TO F/C. TEST CASING. DRILL F/C,CEMENT, F/S AND 10' NEW FORMATION TO 2960'. RUN LOT W/ 8.9 MUD. BROKE DOWN @ 480 PSI. DRILL F/2960-3963'. SHORT TRIP TO 2917'. REAM TIGHT SPOTS. DRILL F/3963-5006'. 08/02/94 5,644' CIRC BO'I-TOMS UP. DROP EMS. POH SLOW SWABBING. TOOK CORRECT FILL. RETRIEVE EMS. RIH, NO PROBLEMS. REPLACE LEAKING AIR BOOTS ON FLOW LINE. DRILL F/5006-5518'. MOTOR LOCKED UP, PUMP PILL, POH AND DOWN LOAD LWD, LOG WAS NOT READABLE. NO HOLE PROBLEMS ON TRIP. PU NEW BIT, MOTOR AND DENSITY TOOL. MAKE LOGGING TIE-IN PASS F/5489-5518'. DRILLING F/5518-5644'. 08/03/94 6,355' RECEIVED MAR 1 4 i99[i dil & Gas Cons. Commission Anchora · CONTROL DRILL F/5644-5964'. PUMP PILL AND POH. DOWNLOAD SOURCE AND LD MOTOR. MU NEW BIT, TURBINE, MWD. ORIENT AND TEST SAME. RIH WITH NEW BHA. 4' OF FILL ON BOTTOM. DRILL F/5964- 6355'. 08/04/94 9,103' DRILL F/6355-7966'. SHORT Y-~ 21 STANDS. NO PROBLEMS. PU 18 JTS DP, RIH. DRILL F/7966-9103'. 08/05/94 9,746' DRILL F/9103-9676'. HOLE WALKING TO THE LEFT AND COULD NOT TURN BACK TO RIGHT. APPEARS TO BE RUNNING BESIDE THE FAULT LINE. CIRC BOTTOMS UP AND PUMP PILL. POH. DOWNLOAD SOURCE AND LD TURBINE. NO HOLE PROBLEMS. SERVICE WEAR RING. MU NEW BIT, 1.25 PDM MOTOR, LOAD SOURCE, ORIENT AND TEST MWD. SERVICE TOP DRIVE. RIH WITH BHA #5. PU 12 JTS DP. NO HOLE PROBLEMS. MAKE LOGGING TIE-IN PASS F/9625-9676'. DRILL F/9676-9746'. 08/06/94 10,778' DRILL F/9746-10778'. TOP OF "C" SANDS @ +/- 10265', BOTTOM OF "A" SANDS @ +/- 10562'. 08/07/94 10,860' DRILLING F/10778-10860'. PUMP SWEEP AROUND. SHORT TRIP, 25 STANDS. FIRST 3 STANDS TIGHT OFF BOTTOM. WORKED FREE. PUMP SWEEP AROUND. SPOT 200 BBL THERMA-THIN PILL ON BOTTOM. POH. STAND "S" AND "G" DP IN DERRICK. LD "E" DP. NO HOLE PROBLEMS. CHANGE TOP RAMS TO 7". FINISH POH. DOWNLOAD SOURCE AND LD BHA. CLEAN RIG FLOOR, PULL WEAR RING, AND TEST BONNET SEALS. CHANGE BAILS AND RU CASING EQUIPMENT. RUN 7" 26# L-80 NSCC CASING. 08/08/94 10,860' FINISH RUNNING 7" 26# L-80 CASING. SHOE @10840'. CIRC AND COND MUD. RECIPROCATED PIPE UNTIL PIPE STARTED GETTING STICKY AND LOSING WEIGHT. RU HOWCO. TEST LINES. DROP PLUG. DROP TOP PLUG AND DISPLACE WITH RIG PUMP. BUMP PLUG, FLOATS HELD. SHEAR ES CEMENTER. CIRC. RU HOWCO. TEST LINES. DROP PLUG AND DISPLCE WITH RIG PUMP. BUMPED PLUG. FLOATS HELD. RD CEMENT HEAD, LD LANDING JT, CLEAR FLOOR AND CHANGE OUT BAILS. SET PACK OFF AND TEST, OK. CHANGE RAMS TO 3 1/2" AND TEST SEALS. CHANGE TOP DRIVE TO 3 1/2". PU 6" BIT, SCRAPER, 6 DC, 15 RECEIVED MAR 1 4 (J~l & (3as Cons, Commission Anchora HWDP AND 3 1/2" DP AND RIH TO 6017'. DRILLING CEMENTER @6017- 6020'. PU 3 1/2" DP AND RIH. 08/09/94 10,860' PU 3 1/2" DP AND RIH. REPAIR ACTUATOR ON TOP DRIVR IBOP. FINISH PU AND RIH W/3 1/2" DP. TAG LC @10754'. TEST CASING. CLOSE ANNULAR AND REVERSE CIRC, 30 BBL HI-VIS SWEEP, 50 BBLS SAFE KLEEN, 30 BBL HI-VIS SWEEP. REVERSE CIRC AND FILTER SOURCE WATER. POH, LD 3 1/2" DP. FREEZE PROTECT INSIDE 7" CASING WITH 77 BBLS DIESEL. FINISH POH L/D 3 1/2" DP AND BHA. PULL WEAR RING AND CUT DRILL LINE. CHANGE TOP DRIVE TO 5". 08/10/94 10,860' FINISH CHANGING TOP DRIVE TO 5" AND BLOW DOWN MUD LINES. ND BOPE. INSTALL 7" Xl 1" TUBING HANGER AND NU FRAC TREE. TEST SAME. RELEASE RIG @1030 HRS ON 08/09/94. RECEIVED MAR ! 4 1995 Oil & Gas Cons. Commission Anchora · BP/AAI SHARED SERVICE ' DAILY OPERATIONS PAGE: 1 WELL: MP J-09I BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 4ES WO/C RIG: NABORS 4ES 02/11/95 ( 1) TD:10860 PB:10754 STAND-BY STAND-BY W/ CREWS. WO J-PAD GRAVEL HAUL. MW: 0.0 02/12/95 ( 2) TD:10860 PB:10754 02/13/95 (3) TD:10860 PB:10754 02/14/95 ( 4) TD:10860 PB:10754 02/15/95 ( 5) TD:10860 PB:10754 NU BOPE MW: 0.0 STAND-BY. WO J-PAD GRAVEL HAUL TO FINISH. LAY DERRICK OVER. MOVE RIG F/ C-22 TO J-PAD. LAY HERCULITE AND MATS. SPOT SUB, PITS AND PIPE SHED F/ 30' WELL CENTER. RAISE AND SCOPE DERRICK. BERM RIG. TAKE ON 200 BBLS 10.3# BRINE. RU MUD LINES TO PITS. ACCEPTED RIG @ 0300 HRS ON 02/12/95. CHECK ANNULUS. ND DRY HOLE TREE. NU BOPE. PU 3.5" TUBING MW: 0.0 NU ADAPTER FLANGE, BOPE, RISER AND FLOWLINE. RU AND PULL BPV. BOLDS. PULL HANGER. RU AND TEST BOPE, OK. LOAD PIPE SHED. PULL PROTECTORS. SLM. STEAM SNOW OUT OF JTS. MOST WERE PACKED. MU BAKER RET HEAD. RIH DRIFTING 3.5" TBG SINGLES TO 2150' DISPLACE DIESEL CAP W/ 10.3# BRINE TO OUTSIDE TANK. CONTINUE RIH DRIFTING TBG. RUNNING 3.5" COMPLETION MW: 0.0 CONTINUE RIH DRIFTING TBG F/ PIPE SHED. LATCH AND RELEASE BAKER RBP @ 4492' RKB. MONITOR WELL. CIRC THRU CHOKE AND GAS BUSTER. CIRC GAS AND CRUDE TO TIGER TANK ON BOTTOMS UP. CONTINUE CIRC GAS CUT BRINE. CIRC CONVENTIONALLY AND HEAT FLUID. MONITOR WELL, OK. POH. LD RBP. RU TO RUN 3.5" COMPLETION. PU BAKER 'SABL-3' PACKER AND TAIL PIPE ASSEMBLY. RIH ON TBG IN DERRICK. PU AND DRIFT TBG FROM PIPE SHED. NU 3.5" TREE MW: 0.0 FINISH RIH W/ 3.5" COMPLETION. MU HANGER AND LANDING JT. TAKE ON, HEAT AND FILTER BRINE. CIRC THRU CHOKE AND GAS BUSTER. CIRC OUT GAS AND OIL. CIRC CONVENTIONALLY AND CLEAN UP FLUID. LAND HANGER. RILDS. PUMP 40 BBLS DIESEL DOWN ANNULUS. U-TUBE TO TUBING. FREEZE PROTECTION TO 1100' DROP SETTING BALL. SET PACKER AND TEST TBG. LD LANDING JT. SET BPV. ND BOPE. NU ADAPTER FLANGE. TEST HANGER AND FLANGE, OK. START NU 3.5" TREE. RECEIVED MAR 1 4 199,5 ~,~$ka Oil & Gas Cons. Commission Anchora - WELL : MP J-09I OPERATION: RIG : NABORS 4ES PAGE: 2 02/16/95 ( 6) TD:10860 PB:10754 RIG RELEASED MW: 0.0 FINISH M~A3-1/8" 5K TREE. PULL BPV AND SET TWC. TEST TREE TO 5000 PSI F/30 MIN--OK. PULL TWC & SET BPV. RIG RELEASED @ 0800 2/15/95. SIGNATURE: (drilling superintendent) DATE: RECEIVED MAR 1 4 199b Oil & ~as Corls. Comr~issio~ Anchora, WEi. L ~..:.AT:: n~-,'--:In:J,. L-A?(N/-S} 0,C,5 !12 i12,00 0 ~. '0::> 0 5 ~'0'-:., 337~ RECEIVED MAR 1 4 1995 Oil & Gas Cons. Commission Anchora '.~ ii2,0{ 0,0 112,00 fi,nn 0,<:<: La : k .-' L,':'=. L;,'?~hTur.z :,i-zr,..-;-'-z; ..;q~ ir. ATi~UTH !0.9/ -:..4 .-,~. r, A i!77,70 i 2'5-'-r',,~ 7 13g.?~,56 9i,4 iOOg,i¥ c., ,, iiC..2,G4 '.:.-'~., 5 I ! 94:3'5 i373:2i !7,ii /,.';'~ 316,41 29,04 '.;', il 3;:;5,15 4:'::., 47 i -:. ,.,,:.'::, ':,,,~. - '"' '= 6i :=.,,-'.'.fi,2;=. 85,77 20,74 306..,22: i=. ~--.. _z r.; 17~I! ._._,.. ,64 ....... 14,~3 2'.~,..-. ','-= =-a £~, _..... '7, A ~,£..:, ..-' , 34. a':-', ...... -30,,4~: 4;;.,.":,~ ':"'~ ~; ,5.2 ,....,. _. ~./,:._, -~c: l'? o/~54 314,4,'-'_, :'5,4,3! -7~ :74 96,-5.'.5 3ii ,&,~ 2,47 2,75 91.~. ........ i546,07 ~47.a~.~, 23,44 3i0~3^. 93,2 1=*~ 9i ...... 42 97,94 .t~u,~ ELi, ........ i%,3e, -i2~,r'"',~ 166,42 132,22 -i59.84 207,89 309,75 !952,t6 2047,37 5'5,2 !959,25 ~: ~a ~A.a~ 313,63 v'q,~ 2032,7~ 4ii,2z ..... '24,~ 2i03,60 467,77 42,A2. . ~,~,~,:~ n: 224,41 -'=': :',..,.,...., ,':'=, = 346,45 3i0,'"'"'o,' '- ' 4.....,_,,.23 3!0~70 2,'5',-',2~. -3:)4.:::'6 ...v= ..:,...? r.,,: -~4.~. ':'"= 4/.: ,24 ..... .,_ :' ="~ -:'" 3~:7 ,,.?7 -445,%,. '=:,A 9 _ _. ,,..,_,~' ,:u: 4,i2 4,55 ?.,32 3,54 E617,67 25S6,77 94,6 2352,07 7z=,~:.~oc 55,23 422,74 -sOO,'?O ~,94 3!0,8.2 ~.~ o:-. -~ ~ 735" c:~O" 526,76 -6!8.,07 ali,O? 3i0,44 ~ -A7¢ "' g';'O,Oi 3i$,?/ -", r. -7 LC:/' ,"., LO %4 4:" 3312 :~ .... 5 '='~':': 17 c.;,~ e= 57,04 .. ~ : !:.:-: __ f'..-,,_' f :: L4~.,i 7-577,63 1 ,"';'~ ;~. s,<=': := .~.,.=-,.,. u,.,.~-u ,' .: ,-: :.-'-'::.:, r,= IOS;-,:'7 =" i,5. ': o I !J ;. -:' £ 7 'h..: 7 ~u,i./,:.'-.'_, '..~." ..)"...'~' '7.--" 6:7 2.¥7-' 9,47 i i6S, :/.; 58 ,?~- 310/7-;_ ?,t'.,}:2729,09 '._5:::;,___,,.., :_,':'"' 55',0{" 3!0:04 1,7'-5 1 ,%: 0,':7.-' - ' ~,3~C ,~/ ~: +~'~ ,~.,~ z~:o,~o 1379,6! =: :~ " .... 95,z 29SO&4 '~'"~ '" 57,01 3!! ......... .._ ......... ~i'~,~2 0,7.2 RECEIVED MAR 1 4 1995 Alaska Oil & Gas Cons. Commission Anchora . !;75 ~: 5.'- i:)30 :":,9 /.. a -=-, ........:~o:,73 2.-:9.:-.. ,i -_, 9=:, -:: 472i ,:?}' 94:5-' 50i 7 _~ i..3 ?5 +7 :i¢: ~-c: 9119 5'-103,10 '.:-14~i 2 '-; =,,''; · :;'~.,_...: ,.,- 5,?,,26 ,:..~ '"-"-' ,?.::"'-' !7'?'g,Sl .... · 'Z.2.'L'7~, _'-! ,,.~ -z:_-, [U i-:"_:.-_,';_,'7! 26:::'5:30 5.71.-q? '-':"-; ~':' ~,911A =' . _ ?:,':_'-3,5_-;(: 56,:...-" .......... :.._-: :. ,,,,: -:-. 975. , ~v:" -i77.:..' - P.'.-.'75,47 2.2.t'.7,6 i 2z. 25..6! 15(.7, :..3 2!:-;;_'..7,,., ,5'.'..'.. 311 3i2,15 2,2,~_ 51.,-'..~ 2, 1,27 .':., i5 4 27'62, _ . -..: ?,;,.,.': -2235,$7 -2270+35 -2305,74 -233~ ~ -23~0,7~ '3N+26 3,.*_-'.5 o.i.._'.~, ,..~.'~,~, l':.'.) 3'..204, ';:4 47,83 3[¥-;, 55 2474.': 33 3274,_ i7 -47.. ,ox 3344,3';: 4&, 2,'.'5,34 ...... 49,1,.0 -- ,"-- =': :.:'A7:q, C:f- - 23S5 ,. 8.7 -9,..4. v !'~ "". ~ ~ ~. -2434 ,.23 r: .4 ~"'7 .' - -'-.5.478 3'.3..':5.9 · '_-;454, !'-: -~'4~ ~,-, 35.?-, ,67 ...... '_-,.543, 2i5~27 315,75 3i6,21 0,5'~ 0,3(:.' i, 7.7 ~'--'~ 09 ?5+0 ~,.,.'..~,=o""" .... .... ~- .."-7 .....- . ~ ,_. .... .654! ,54 93, i 4604 -_'5,:'; 3Z, ?5 ?3,- 4 4,z,~: ~ 25 3635,60 52,~=_ .== ~S,k:.~ ,_ ,_ 3709,78 54,29 ~,z ~ 37 a~ 4-7 55,67 346, i 5 ! 1 1 !, ~";' .. .6717,53 31,'2'}, a.'? - 25'.'.-."4 ,. 5 ! 3117,05 -2516,0P 3Ed ~: 18 -2~.15'.'),:-: .'= 3.::4(:_. ,11 -2665,~,,. <' ..'~.--' + .: ~ i.'. ,',.: '? ~-' 4(:'5C.. ::.'.':: 42'.:_':. 4i.'--'7,1.2 47}.. 4250,1"}' 31!,74 7!% ,57 72~: ~75419C: 7371~57 74,7 _~/,~., /.~c~a yb,c 77 ,-,~.m ?22,80 7',08 2 0,,85. 5574: --:;°.-2--' ~ .' "~ 5??6:5-2 = - . .'t'V'.-.'¢ s D:..:' 04 i"-Z -'2.'7 7 ."0:-2 s / ?373:3:.'- 'f':4:' 0 D ~ Dd c.,': :~ -- ....... 6212:.,".'; ?2,2 6343,43 ?S,'? 6490~62 74,i 6557,i7 ?5,0 6~46~g.7 6962,77 704i,02 ! 0604 + 0;5 ':5, '.:, i :2,< ::;., ! 7 " P3750~36 :.< c ,..._......... - ~:::~ ~ z '~.'~ 4a::::,g,~ 50,73 .232,87 ~:42~21 -3011 ~-~ :. ,~-~ :&/ ,~.::i~-~.' ..- : - ~&~;~'.. - '~ ........ ~2' -~'i~tZ:.'::5' rmr~ 72. ~1A9.O,; ~r r..-, :ar :s 4~OS:7Q -:'l°~ 5':' =~'"" == ~..-:t;.. ~O~Y7 -~'~s~ ........ ' ~+~ 5322,92 51,!2 242,35 44'39,53 -317E~% 5457,37 57:57 .~'~ 53,26 3Sa ~OS ~74 ~:!-O -33!i ,77 5¢?:2,31: 325,a! '; =9~: ~: ...... W:,%~.~;'~ -337A ~ = 6037 4'! ........ · v:_,: .... ., 37. ,_. 3'.22,06 ~:",- =._,':' ,~;..._-.. %517 s,._..'-'= ._.,_._., :31 325,00 is. ?i 62i3,!5 '::--:,¢.::-. X.::,:',,;..==.-,=.,-, ~,:: _-~=.,,.7,~,4 z-:t~ ¢,~ ?;'g.r,r, ; := ~.~. ,..;..~.~_ ~,. -.--.- ;.,0 :os ~_~.. * '-'.-': _;~...-r. ~..~ i ~J-' :i '--'~- -', ~,' '- -- ASA4,A5 .':-.'.9,54 ':q,~. -',: 5205,!]. .... r, =,-, $395,,q4 3%.:',:, 3,7-: .......... ,~.. · ..-.- -,D.)/%: ~_.' 7 .... 6Si6s2O ,:.:.-. ~,7 M.o,S4 ~.':-:%,,4,:, -2%c,, 9; A445,.~; 32t'.,:'/ 2,47 · ~_ .-- ~;; .... . ........ t_~ . - ':':'; =, ~.7 33,3,'.:, :---42,31 ...... ~,:,u_,,4 .- A474,'~5 325,2a .... _.:.,, . ,. bq;J~,~o -~' ' ~'= '-' . .... ..... M;... S451 cc. -3.51Y,., ~ A4~g,74 :~:-7.70 "=.47 _ .,~,~ · - ',- ;,S~t,~,'; 3i6,42 :,~r., ,~-47i,i3 ..... .~,~ 746,53 ~SC~3~20_ _. -3~2,57 ..,~ A~,~.<,., n*,, 324,fi7. _. z~:~ ~: ~,, n:. " -3645,r':' A~.~.I: 32~.,73 ,5575 =: ~ ~ -*' ~' %0~ '-' -:,eS/~r:: ~,',c ~ :,:.~ :: ' 717'.:.: :72g,-',7': ........7;. 397,z? cz=--,. -- ..... :,v ,:,:. ........ :,,._,..' sS: ..,.:,-_ ..... .-..' ;::.r: . :.: :-'-,'- ...... ca? '- 5707 9,t', ,,~. .... - ,.,,.:;. ~., ~'5 0/2+.-"5' --.:: ~/ * ...... 735,5:(~1 ........... :, _.-. ~4.'t 5,5 ~7=~ C: : £.; ,, l : Z'L : .~,, : . ..: .-:.' -~'.' ~ ........... 742::_,~7i ,:.7,: ..... -:~.. ...... -:,o,-_-.---': '.550,23 140!,.0_: -3,f.'?,S 7495,~¢~r' 68i4:74 33,C" 35 i, '-'".: 5~ 44,7:'-'. -3705,4'.:: RECEIVED MAR 1 4 1995 Maska Oil & Gas Cons. Commission Anchora STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISb,~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program x Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development . KBE = 65.05' feet Exploratory __ 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service x Milne Point Unit 4. Location of well at surface 8. Well number 2347' NSL, 2090' EWL, SEC. 28, T13N, RIOE At top of productive interval N/A At effective depth 2854' NSL, 1606' WEL, SEC. 20, T13N, RIOE At total depth 2912' NSL, 1616' WEL, SEC. 20, T13N, RIOE ORI61NAL MPJ~09 9. Permit number 94-101 10. APl number 50- 029-22495 11. Field/Pool Milne Point - Kuparuk River 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 2905' Intermediate Production 10811' Liner Perforation depth: 10860 feet 7431' feet 10754 feet 7344' feet Size Plugs (measured) 7" wireline retrievable bridge plug @ 4500' MD 13-3/8" 9-5/8" Junk (measured) Cemented Measured depth True vertical depth 250 sx AS (Approx.) 112' 112' 572 sx PF "E'F250 sx "G" 2936' 2529' 7' 400 SX Class "G" 10840' 74 78' measured 10328:10342~ 10355~10361~ 10442~10462~ 10475:10462' true vertical 7049'-7061', 7072:7077', 7144'-7161', 7172:7199' Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None RECEIVED /~!as~ .0il & Gas Cons. Commission · , ~ch0rr. ' ' 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 1/30/95 16. If proposal was verbally approved Oil__ Gas __ Name of approver//,., ./ Date approved Service Water Injector 17. I hereby certify~/,~ f~,~g i....strue a~xcorrect to the best of my knowledge. Signed .//'~ k_// ~.,-.,.~.---~'"'"~ '" ~' k.. Title Drilling Engineer Supervisor ~ FOR COMMISSION USE ONLY 15. Status of well classification as: Suspended__ Date Conditions of approval: Notify Commission so representative may witness Plug integrity BOP T,est __ Location clearance Mechanical Integrity Test J Approval No. ~'~-..O ) G Su,~e~gent form rec~uired 10- /"J'O? Approved Copy u~gl~~ ~)~gnea'uy - Approved by order of the Commission Returned Form 10-403 Rev 06/15/88 Davia w. Johnston Date SUBMIT IN TRIPLICATE Milne Point J-09i RWO/Completion _Ob!ective: The objective of workover is to complete the well as a water injector in the Kuparuk sands with 3-1/2" 9.3# L-80 EUE tubing and a permanent latched packer. The water injection from MP C-09i will support producing wells J-06 and J-11. If an acceptable injection rate is not obtained the well will be hydraulically fractured down the 3.5" tubing after release the rig. Backgr, ound: The well was drilled with Nabors 22E and 7" casing run and cemented in July 94. Both CBT and wireline conveyed perforation were recently performed. Currently, the well has diesel freeze protection to 2,000' MD, 10.3ppg NaCIBr brine to TD below the diesel, and a 7" wireline retrivable bridge plug was set at +/-4500'MD. Work Scope: 1. MIRU Nabors 4ES. ND tree and NU BOPs. 2. Retrieve 7" retrievable bridge plug @+/-4500'MD. 3. Run 6" gauge ring and junk basket to +/-10,200'MD , Run 3.5" 9.3# L-80 EUE tubing with a 7" latched permanent packer. Freeze protect well down to 2,000'TVD with diesel. Set packer @ +/- 10,100'MD and test tubing and annulus to 4,500 psi. 5. RDMO Nabors 4ES. . Place well in water injection service. If an acceptable injection rate is not obtained the well will be hydraulically fractured down the 3.5" tubing w/o rig. Timings: Rig Nabors 4ES is expected to move on this well 1/30/95. The workover is expected to take 3 days. RECEIVED dA[4 2 4. 1995 A~sk~ 0il & Gas Cons. Commission Anch0r~ ' D H January 16, 1995 ~ ' MPU J-09i · WKM 11" Thru-bore Wellhead (Old Conoco Style) 13 3/8" 48# K-55 Btrc [-~ ~1 Conductor Casing 95/8" 40# L-80 28L~__] ~~ Surface Casing -. KOP @ 500' 50° to 60° from 2500' to 3 1/2" ThreadedI 1 9200' N-80 Tubing [ 10100' +/- 50' j r 7" ES Cementer @ 5800'md +/- (Ail tubing/packer depths and per[oration data are PROPOSED) : RECEIVED JA[~ 24 1995 A!~ska 0il & 6as Cor~s. Commissior Anchor~ · PERFORATION SUMMARY Atlas 4" Alpha Jet 4spf, 7.0" X 3.5" Baker Packer[ 10100' +/-I X X 90° phasing, 32gm charge iD,~~ _~ ~ ! REF LOG: SBL/GR/CCL 8/16/94 3 1/2" "X" Nipple (2.813" )L ~ J~ SIZE SPF INTERVAL OPEN/SQZ'D 3 112" L-80 NSCT Tailpipe ~,! ~ j~,// \ 4" 4 10328 to 10342 Open 3 1 /2" Nipple (2.75" ID) 4" 4 10355 to 10361 Open / I/ '~ 4" 4 1O442 to10462 Open 3 1/2" WLEG 4" 4 0475 to 10507 Open , ~CURRENT PBTD 10500' J 7.0" 26#, L-80 Butt. Csg 10580' --,~[~,~i · DATE REV. BY COMMENTS MILNE POINT UNIT 12-29-1994 RBF Proposed Tubing Completion WELL J-09i APl NO: 50-029-22495 BP EXPLORATION (AK) [ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISsiON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well Alter casing ~ Repair well Plugging __ Time extension ~ Stimulate __ Change approved program x Pull tubing Variance__ Perforate ~ Other__ 2. Name of Operator BP Exporation (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development __ Exploratory ~ Stratigraphic __ Service x 6. Datum elevation (DF or KB) KBE = 65' feet 7. Unit or Property name MIIne Point Unit 8. Well number MPJ- 13 Permit number 94° 126 10. APl number 50- 029-22508 4. Location of well at surface 2319' NSL, 3179' WEL, SEC. 28, T13N, RIOE At top of Productive interval 9. N/A At effective depth 2376' NSL, 1291' WEL, SEC. 21, T13N, RIOE At total depth 2425' NSL, 1281' WEL, SEC. 21, T13N, RIOE 11. Field/Pool Milne Point - Kuparuk River 12. Present well condition summary Total depth: measured 9750' feet true vertical 7486' feet Effective depth: measured 9647' feet · true vertical 7396' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Plugs (measured) 7" wireline retrievable bridge plug @ 4500' MD Junk(measured) Cemented Measured depth True vertical depth 80' 20" 250 sxArcticset 112' 112' 2805' 9-5/8" 560 sx PF "E"/250 sx "G" 2835' 7469' 9704' 7" 356 SX Class "G" 9731' measured 9206'-9222', 9230'-9238', 9314'-9334', 9346'-9382' (proposed intervals - work in pro.~ess) RECEIVED true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 0il & Gas Cons. Commission Anchor~ 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation 2/2/95 16. If proposal was verbally approved Name of approver 17. I hereby certify th¢/~,f)o~nd Signed Date approved 15. Status of well classification as: Oil .__ Gas __ Service Water Injector Suspended __ Date correct to the best of my knowledge. Title Workover Superintendent FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance ~ Mechanical Integrity Test v~ Subse.~u, er~t fqr~ required lO- signed By David W, Johnston Approved by order of the Commission Approval No. ~_.._~""...... ~/' 1 Approved Copy Returned ¢/'; s" uomm~ss~ohCr ' Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Milne Point J-13i RWO/Completion Obiective: The objective of workover is to complete the well as a water injector in the Kuparuk sands with 3-1/2" 9.3# L-80 EUE tubing and a permanent latched packer. The water injection from MP C-13i will support producing wells J-10 and J-12. if an acceptable injection rate is not obtained the well will be hydraulically fractured down the 3.5" tubing after release the rig. Backoround: -- The well was drilled with Nabors 22E and 7" casing run and cemented in September 94. Both CBT and wireline conveyed perforation were recently performed. Currently, the well has diesel freeze protection to 2,000' MD, 10.3ppg NaCIBr brine to TD below the diesel, and a 7" wireline retrivable bridge plug was set at +/-4500'MD. Work Scope: 1. MIRU Nabors 4ES. ND tree and NU BOPs. 2. Retrieve 7" retrievable bridge plug @+/-4500'MD. 3. Run 6" gauge ring and junk basket to +/-9,100'MD . Run 3.5" 9.3# L-80 EUE tubing with a 7" latched permanent packer. Freeze protect well down to 2,000'TVD with diesel. Set packer @ +/- 9,000'MD and test tubing and annulus to 4,500 psi. 5. RDMO Nabors 4ES. 6~ Place well in water injection service. If an acceptable injection rate is not obtained the well will be hydraulically fractured down the 3.5" tubing w/o rig. Timing: Rig Nabors 4ES is expected to move on this well 2/2/95. The workover is expected to take 3 days. REC£1VE · mask~ Oil & Gas Cons. Commission Anchor; D H January 16, 1995 I Ii I I ~ I i i i MPU J-13i 20" 94# K-55 Btrc Conductor Casing Surface Casing KOP @ 500' Max Hole Angle: 50° @ 3200' MD 3 1/2" Threaded N-80Tubing [ 9000'+/- 50' I (All. tubing/packer depths and perforation data are PROPOSED,.) E £ E IV E D jA[-~ 2 4~ 1~95 ~i~,,~k,~ .0il .& Gas Cons. Co.rnmissi .'_Anchor; PERFORATION SUMMARY Atlas 4' Alpha Jet 4spf, 7.0"X 3.5" Baker 3 1/2""X' Nipple (2.813" ID)[ ]~_~iI I REFLOG: SBL/GR/CCL 10/15/94 I ~ SIZE SPF INTERVAL OPEN/SQZ'D 3 1/2" L-80 NSCT Tailpipe /'// \ 4" 4 9206' to 9222' Open 3 1/2" "XN' Nipple (2.75' ID) L..___~ ~''--'"'"------- ,/ i 4' 4 9230' to 9238' Open 3 1/2" WLEG I ..~/ 4" 4 9314' to 9334' Open 4' 4 9346' to 9382' Open 7.o~ 2~#, uso e~tt. c~ DATE REV. BY COMMENTS MILNE POINT UNIT 12-29'1'994 RBF Proposed Tubing Completion WELL J-13i APl NO: 50-029-22508 ,, BP EXPLORATION (AK) I I I i II I II I I I I RECEIVED JAN 23 1995 .~aska Oil & Gas Cons, 6orr~miss.ion Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 18 January 1995 RE: Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL I o/ ~V'-/rD/ ~?~-o9 DESCRIPTION 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 CCL FINAL BL+RF ECC No. Run # 1 6258.01 Run # 1 6258.02 Run # 1 6258.03 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: 500 W. International Airport Road Anchorage, Alaska 99518-1199 (907) 562-7669 Janua~ 9,1995 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the LWD DEPTH CORF[ECTED ~;DI~ 2A~N~~VD for well was sent to: '~ MPJ-09 ,Job # 94383 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Sta Alaska .__Ath~' Larry Grant ~e Drive Anchorage, ~ 3 Bluelines I Film 1 Blueline "% \ -' .... 1 RFolded Sepih ..~ OXY USA, Inc Attn: Erma Galindo P.O. Box 50250 Midland, Texas 79710 1 Blueline 1 RFolded Sepia Sent Certified Mail P 905 127 757 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING O1~ COPY EACH TO: BP EXPLORATION (ALASKA) INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 Schlumberger Courier: Date Delivered: Received By: 500 W. International Airport Road Anchorage, Alaska 99518-1199 (907) 562-7669 October 28, 1994 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the LWD DEPTH CORRECTED CDR & ADN/CDN for well was sent to: MPJ-09, Job# 94283 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 ..¢. Stat/~¢~f Alaska Alaska Oil & Gas Conservation Comm. Attn' Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 OXY USA, Inc Attn: Erma Galindo P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Depth Shift Monitor Plot 3 Bluelines 1 Film Returning CDR, CDN, CDR & CDN ~ TVD Field Film 1 OH LIS~'Fap_e 1 Blueline ' I RFolded Sepia "~ 1 OH LIS Tape 1 Blueline 1 RFolded Sepia Sent Certified Mail P 67'6,541 ,355 PLEASE ACKNOWLEDG,_ ,,ECEIPT BY SIGNING AND RETURNING ONE 6~,~'~.,,E. A : PETROTECHNICAL DATA CENTER, MB3-3 ROAD 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99518-1199 ANCHORAGE, ALASKA 99519-6612 Schlumberger Courier: Date Delivered: Received By: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 29 September 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 MARKED LINE GR TAPE 1 GAMMARAY TAPE LISTER 1 MARKED LINE GR TAPE 1 GAMMARAY TAPE LISTER ECC No. Run # 1 6258.00 Run # 1 Run # 1 6259.00 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 /Q Anchorage, AK 99518 / / Att)~/ Rodney D. Paulson STATE OF ALASKA ALA~r~A OIL AND GAS CONSERVATION COMMISS,~,,,I APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Aban(,~on ~ Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate x Change approved program x Pull tubing __ Variance__ Perforate x Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2347' NSL, 2090' EWL, SEC. 28, T13N, RIOE At top of productive interval N/A At effective depth 2854' NSL, 1606' WEL, SEC. 20, T13N, RIOE At total depth 2912' NSL, 1616' WEL, SEC. 20, T13N, RIOE 5. Type of Well: Development__ Exploratory __ Strat~graphic __ Service x ORIGINAL 6. Datum elevation (DF or KB) KBE = 65.05' 7. Unit or Property name Milne Point Unit 8. Well number MPJ-09 9. Permit number 94-101 10. APInumber 50- 029-22495 11. Field/Pool Milne Point - Kuparuk River feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 2905' Intermediate Production 10811' Liner Perforation depth: measured None 10860 feet 7431' feet 10754 feet 7344' feet Size 13-3/8" 9_5/8, true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Plugs (measured) Junk (measured) Cemented 250 sx AS (Approx.) 572 sx PF "E"/250 sx "G" 400 sx Class "G" Measured depth True vertical depth 112' 2936' 112' 2529' 1O84O' 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation 9/5/94 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service Water Injector Suspended Signed Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify commission so representative may witness Plug integrity ~ BOP Test Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10-/yc~-r Original Signed By Approved by order of tile Commission David W .lnhnston Form 10-403 Rev 06/15/88 Commissioner Approved Copy Returned Date ~//~/~. -rI JApproval No. ~. ~, ,~ -7~ ~ ~ Date SUBMIT IN TRIPLICATE Milne Point J-09i Completion Objective: The objective of the following work is to complete the well as a water injector in the Kuparuk sands. The well was drilled with Nabors 22E and 7" casing run and cemented. The well currently has diesel freeze protection to 2000' MD, and 8.34 PPG Milne Point source water to TD below the diesel. Reservoir pressure is estimated at 3550 psi at 7070 TVDSS. It is planned to complete the well with 3.5" tubing and tubing conveyed perforation guns. The well will then be placed in water injection service. If it is not possible to obtain acceptable injection rates, the Kuparuk sand will be hydraulically fractured down the 3.5" tubing. Work Outline: 1. MIRU Nabors 4ES. , Run 3.5" 9.3# L-80 tubing and tubing conveyed perf guns. Set production packer and test tubing and annulus. 3. RDMO Nabors 4ES. 4. Fire guns to perforate well. , Place well in water injection service. If an acceptable injection rate is not obtained the well will be hydraulically fractured down the 3.5" tubing. August 30, 1994 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: David Johns~Lo~, Chair~ Blair Wondzell, P. I. Supervisor John Spaulding,~. ~''~ Petroleum Inspe~.tbr DATE: Aug. 1, 1994 FIEE NO: AWOLG4BD.doc SUBJECT: BOP Test Nabors 22E BPX / MPU / Well MPJ-09 Milne Point Unit P.T.D. # 94-101 Saturday July 30, 1994; I tra.v~led to BPX's Milne Point Unit well MPJ-09 to witness a BOP test on Nabors-2,?.F. The AOGCC BOP Test Report is attached for reference. Two (2) failures were observ~4n the choke manifold piping in the sub-structure, resulting in an abnormally lo_FrOst time. Although the drill sites at Milne Point are quite small, the rig and adjacent area was well laid out and very clean. Summary: i witnessed the BOP Test on Nabors 22E, BPX Milne Point Unit well M'PJ-09, 2 failures, 8 hour test time. Attachment: AWOL4GBD STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: x Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8" Test: Initial X Workover: Nabors Rig No. 22E PTD # BPX Rep.: MPJ-09 Rig Rep.: Set @ 2936' Location: Sec. Weekly Other DATE: 7/30/94 94-101 Rig Ph.# 659-6475 Brian Busby Jimmy Pyron 28 T. 13N R. 10E Meddian Umiat MISC. INSPECTIONS: Location Gen· OK Housekeeping: OK (Gen) Reserve Pit N/A Well Sign OK Drl. Rig OK BOP STACK: Quan. Annular Preventer 1 Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves 2 Kill Line Valves Check Valve Test Pressure P/F 250/3000 P 1 250/5000 P 1 250/5000 P 1 250/5000 P 1 250/5000 250/5000 1 250 / 5000 P N/A N/A N/A FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP ' Test Quan. Pressure P/F 1 250 / 5000 P 1 250/5000 P 1 250/5000 P 1 250/5000 P MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Methane Gas Det. OK OK H2S Detectors OK OK CHOKE MANIFOLD: No. Valves 17 I I No. Flanges 316 Manual Chokes . Hydraulic Chokes 2 ACCUMULATOR SYSTEM: Test Pressure P/F 250 / 5000 P 250/5000 F P Functioned Functioned System Pressure 3100 I P Pressure After Closure 1600 I P 200 psi Attained After Closure minutes 37 sec. System Pressure Attained 3 minutes 8 sec. Blind Switch Covers: Master: YES Remote: YES Nitgn. Btl's: 8 (~ 2000 AVERAGE Psig. Number of Failures 2 Test Time 8 Hours Number of valves tested 25 'RePair or Re~lac~en~"of F~iled: Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I REMARKS: Flange leaks on choke manifold repaired and continued testing Distribution: orig-Well File c - Oper./Rig c - Database c - Tdp Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: J~ ~ ~u/(~ F1-021L (Rev. 2/93) AWOLG4BD.XLS ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 27, 1994 Adrian Clark, Drlg Engr Supv BP Exploration (Alaska) lnc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Milne Point Unit MPJ-09 BP Exploration (Alaska) Inc 94-101 2346'NSL, 3191'WEL, Sec 28, T13N, R10E, UM 2765'NSL, 1618'WEL, Sec 20, T13N, R10E, UM Dear Mr Clark: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be Commission given by cont~ petroleum field inspector on the North Slope pager at 659-3607. Chairm~m........~.~ BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl :°-~) printed on recycled paper STATE OF ALASKA ALASKA L,,IL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill Dllb. Type of well. Exploratoryr-i Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenE!I Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator '5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) inc. KBE = 64' feet Milne Point- Kuparuk River 3. Address 6. Property Designation P. O. Box 196612. Anchorage. Alaska 99519-6612 ADL~¢SG¢'6 2_. 4. Location of well at surface 7. Unit or property Name 11. Type Bond(se,, 2o AAc 25.025) 2346'NS1_, 3191' WEL, SEC. 28, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 2599' NSL, 1550' WEL, SEC. 20, T13N, RIOE MPJ-09 2D 100302630-277 At total depth /3'/~J ,,¢,,'~ 9. Approximate spud date Amount 2765'NSL, 1618' WEL, SEC. 20, T~1,4¢¢, RIOE 7/28/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property:15. Proposed depth(MD a,d'rVD) °~t~ line prop L $55017-2765' feet No close approach feet 2560 10637' MD/7404' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (r~e 2o AAC 25.035 (e)(2)) Kickoff depth ~oo feet Maximum hole ansles~.s o Maximum surface 'ZSE'°~sig At total depth (TVD)-~-~4;~O psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 13-3/8" 54.5# K-55 Weld 80' 32' 32' 112' 112' 250 sx Arcticset (Approx.) 12-1/4" 9-5/8" 40# L-80 B TRC 2834' 31' 31' 2865' 2514' 572 sx PF "E"/250 sx "G"/250 sx "C" 8-1/2" 7" 26# L-80 BTRC 10607' 30' 30' 10637' 7404' 250 sx "G"/150 sx "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. R [ C ~ I V C U Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet JUL. ?-71994 EffeCtive depth: measured feet Junk (measured) b,~$~. 0[} & Gas Cons, C0mlili$$[0f~ true vertical feet 'Anch0r~c Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner · Perforation depth' measured true vertical ... 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program ITl Drillin~ fluid program. [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby ~~~ 7/~/~ certify t regoin is true and correct to the best of my knowledge Signed Tit le Drilling Engineer Supervisor Date COmmission Use Only Permit Number IAPI number IApp,..?val date ISee cover letter ,~ ~' _/,,~ / {5 O- o ~I~ -- ~ z. ~z ¢..5'- { /" 4 '~ - ?f-lC Jfor other requirements Conditions of'approval Samples required [] Yes ~ No Mud log requiredI-]'Yes [] No Hydrogen sulfide measures [] Yes J~¢ No Directional survey required [] Yes [] No Required working pressure for BOPE F'I2M; ]~3M; E]5M; []1OM; F"I15M; by order of Other:Approved by Fim,h.,lOriginalw Signed,,, ~, .. ,. + ,. -B Y Commissioner ~ne commission D ate~'//"'z Form 10-401 Rev. f'2:"1'-¢~ Submit in I zte Well Name: ,, , .I MPJ-09 Well Plan Summary [Type of .Well'(producer or injec, tor): I KUparuk' Producer I'AFE Number: 1330064 ~ :Estimated Start Date: I July '28, 1994 1 ITM I'MD: 'l 10637'" I [.Rig: [ Nabors 22E Operfitifi'g days t6 complete: [TVD~ 17404, bkb l [KBE: 64' Formation Markers: ea e ae Target ' 10280, 7094' , ..... Total Depth ' .10637" 7404' Casin ram: -Hole ~ize ~C'sgff Wt)Ft Grade Cohn Length Top " Btm " Tbg O.D. . MD/TVD MD/TVD 24" 13 3/8" 54.5~' K-55 Weld 80 32]32 112/112 12 i/4" 9 5/8" 40# L-80 btrc 2834" '31/31 ' 2865/2514 8 1/2" " 7"" 26# L-80 '" btrc 10607 '30/30 10637/7404 · Intemal yield pressure of the 7" 26~ casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7100 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3550 psi is 2850 psi, well below the intemal yield pressure rating of thc 7" casing. Logging Program: [OPen l~ole.Log.s: . Surfac~ Intermediate Final Cased. iiol'e LogS: ' None Nohe -Dir MWD acros~ the Schrader'Bluff' CGR~esisdvity/Neutron/Density, Possible RFT across Kuparuk. C.L. will be run 6Y prodUction. 'CBL run only if necessary. ,, RECEIVED JUL 2 ? 1994. A~aska Oil & Gas Cons. Commission Anchorag,~ A gamma ray log will be obtained from surface to TD. Mud Logging is not required. Mud Program: I Special design considerations [ None- LSND freshwater mud I Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.6 90 35 15 30 10 15 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 10.2 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, B OPE and drilling fluid system schematics on file with AOGCC. Directional: [KOP: 1600' Maximum Hole Angle: Close Approach Well: I 156'5 degrees I (No Shut Ins) Disposal: Cuttings Handling: CC2A Fluid Handling: All drilling and completion fluids can be annular injected. Otherwise, Haul to CC2A. Annular Injection: The MPJ-09 annulus is permitted for drilling & completion fluid injection. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED VOL (BBLS) (BBLS) Milne Point MPJ-09 0 35,000 5/3/94 thru 2/20/9~ Milne Point MPJ-08 0 35,000 5/3/94 thru 2/20/9~ Milne Point MPJ-06 0 35,000 5/3/94 thru 2/20/9~ FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept Ol by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economi than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practi used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annunlus was injected into to a freezing. RECEIVED JUL 2 7 1994 AiaS~ 0il & Gas Cons. Commission Anchorage I o 2. 3. 4. 5. 6. 7. o . 10. 11. 12. 13. 14. 15. MPJ-09 Proposed Summary of Operations Drill and Set 13-3/8" Conductor. Weld a starting head on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. NU and test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole and run and cement 9-5/8" casing. Run only Dir MWD (No LWD required) ND 20" Diverter, NU and Test 13-5/8" BOPE. RIH w/Insert bit on Low Speed/High Torque Motor, and Directional MWD. Test 9-5/8" casing to 3500 psig, Drill out float equipment and 10 feet of new formation, Perform a LOT. Drill ahead to the base of the Schrader Bluff (West Sack) into the Seabee Shale and POOH. LD the Insert Bit and Motor. Send Scrader Bluff Log Data to town ASAP. MU a R417G PDC bit on a turbine, with Directional/Gamma Ray, Resistivity/Neutron/Density (Triple Combo) MWD/LWD tools to the Dir/GR/Res. RIH. Drill 8.5" hole to TD, POOH, and Run and Cement 7" casing. This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). RIH while PU 3-1/2" drill pipe with 7" 26~ bit and scraper. Drill out ES Cementer, RIH to PBTD, displace the drilling mud out of the hole with source water, while performing a casing wash, filter source water to 2 micron absolute. POOH L/D 3-1/2" drill pipe. Freeze protect the well. ND BOPE, NU and Test the Frac Tree. Set BPV in 7" x 11" tubing hanger. RDMO Nabors 22E drilling rig to drill MPJ-08. Well will be completed with Coil Tubing deployed ESP. RECEIVED JUL 2 7 1994 Oil & Gas Cons. Commission Anchora§e MPJ-09 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 50 deg F at 2500' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE' ADDITIVES: Retarder Type E Permafrost YIELD:2.17 ft3/sx WEIGHT: 12.0 ppg APPROX #SACKS: 572 THICKENING TIME: Greater than 4 hrs at 50° F. MIX WATER: 11.63 gal/sk TAIL CEMENT TYPE: ADDITIVES: 2.0% CaCI2 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS: 100-150 cc Premium G YIELD:1.15 tt3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB (;:EMENT TYPE: Permafrost C ADDITIVES: Retarder WEIGHT: 15.6 ppg APPROX NO SACKS: 250 YIELD: 0.96 cu ft/sk. MIX WATER: 3.7 gal/sk CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 10 joints of casing (10 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Pedorm lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is ngt necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 500' md above the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to sudace with 100% excess. 4. 80'md 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. RECEIVED JUL 2 7 1994 0ii A Gas Cons. Commission Anch0rs~e MPJ-09 7" PRODUCTION CEMENT PROGRAM- CASING HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140° F BHST 170 deg F at 7040' TVDSS. SPACER: 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk APPROX # SACKS: 250 FLUID LOSS: < 50cc/30 min @ 140° F MIX WATER: 5.0 gal/sk THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. :~TAGE II CEMENT JOB ACROSS THE SCHARADER BLUFF ~AND$: CIRC. TEMP: 60°F BHST 80 deg F at 7040' TVDSS. SPACER: 75 bbls fresh water. RECEIVED LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg Type E Permafrost YIELD:2.17 ft3/sx J U L 2 7 '1994 hl~s~.Oii & Gas Cons. Commission ~ ~chor~ MIX WATER: 11.63 gal/sk APPROX #SACKS: NONE THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344, 2.0% CaCI2 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk APPROX # SACKS: 150 FLUID LOSS: 100-150 cc MIX WATER: 5.0 gal/sk THICKENING TIME: 4 hours @ 50 FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4"Straight Blade Rigid Centralizers-- two per joint on the bottom 20 joints of 7" Casing (40total). This will cover 300' above the C Sand. 2. 7" x 8-1/4"Straight Blade Rigid Centralizers-- one per joint from 5800' - 5150' to cover the Schrader Bluffs Sands (12 Total). 3. Run one 7" x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7" x 8-1/4"Straight Blade Rigid Centralizers needed is 53. OTHER CONSIDERATIONS: Pedorm lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 1000' md above the LK1 with 30% excess. 2. Stage 2 cement volume is calcualted to cover from the OG base to the to 500' above the NA Top with 30% excess. Marker Ioenti¢icmtion MD N/$ B) KOP BUILO 2.5/~0D 600 0 C) END OF 2,5/100 BUiLO 2~60 - 660 D) 9-5/8" CA$1NG - 2265 663 E) ~TA~T 2/~00 ~U~VE - ~m~ ~50 F) E~JD OF 2/JO0 CURVE ......5~6g .......2~B4 6) START 2/~00 D~OP 8924 4738 H) END OF 2/~00 DROP 10080 5442 II --- TARGET --- 10280 5534 J] VD 10637 . ~700 E/H 787 79O 1728 227~ 3325 3653 37~ MPJ-09 (PO6) PLAN VZEW CLOSURE ..... : 6807 feet at Azimuth 326.86 DECLINATION.: 28.969 E SCALE · ~ ~ncn = 1000 feet DRAWN ....... : 07/26/94 __ . -- AnadnJll Schlumberger __ _ ' I RECEIVED i ' " JUL. 2 7 1994 ' · '; i'~,Gas uorrs. Commi,, -",,' '- - ~-~-~'~ ~ ; -' . ....... , ., .~ . 6500 6000 5500 5000 4509 ~000 3500 3000 2500 2900 :500 ~OOO 500 0 500 <- ~¢EST ' EAST -> ~nadr~ll {c;~ MPJO~-F'6 B~.52 ~2: 3ti p~4 : · . PRUOHOE'-- BAY DR ILL I N6 GROUP IIIll .__ I ! MPJ-09 (PO6) VERIICAL SECTION VIEW i __ Sl. Section at: 337.58 TVD Scale.' J inch = ~200 feet <KB> Oep Sca]e· ~ ~nch = ~200 feet , ', iBpown ..... : 07/26/94 __ I ~oJ ..... ~ ...... t. .i ........ __ ~0~- ..... ' ' , ' 1' "1 A) K8 0 0 0 9.OU 9~o~ ~[r - ~ 8) KOP BUILD 2,5/JO0 600 600 0 0 .'00 _- _ i -....._.~i C) END OF 2.5/~90 BUILO 2860 ~5~1 9~0 56.50 ~0-~ .... ~ ~7 B) 9-5/8" CASING 28~5 25~4 9~4 56.50 ~ E) START 2/]00 CURVE 4334 3385 ~999 56.50 ~ F) Ergs OF B,/]OU CURVE 5469 3988 ~8B5 53. ! G) STA~T 8/~00 DROP 8924 6o6~ 5648 53, ~ H) END OF 2/~00 DROP ~0080 692o 5409 30,00 . 0 I ~ i) --- TARGE1 --- :0280 7094 6509 30,03 ~._~ lI J~ T~ ~o63~ ~4o4 s~s ~o.oo O-~ s~:,s ~so~ , '" ' ; ~ " , '": ..... ~'s~s- 7 ~ .... 7 ..........................~ ~ .... i~ .... ~ O- ~[~~-~ .... ~ ...... ~- ~ ........ , ~ ~ ..~ ........... ; : ,, , >~" .......~ ' ~ ..... -'i ' ' ...... ~ ..... '~' ' ' ' ' ~" -~-"" ;-- ==- "' 'T~'~7~.C '~;~ ~ ~ ~ .... T' - .... , , ' i JUL ~f ~, ~ , ~ ,, ~. il & Gas ions. Co mission " ~ .- I ,. .! . .. 4 . , i .- i B 4800 5400- 6000 r,6Oo- 7200 ?800- 8400 9000- 9600 60o t200 . 1Bo~ 2400 BO00 %00 4200 4800 5490 6000 6600 7200 7aoo Section Departure (~r-i~) (c)~ ~J09.~6 8J.§2 -'2:38 P~ .~] '. · : :.-.; : i.'....' ~..- · i .- .: .; . ! . .: ,. .. . ': o . · WELL PERMIT CHECKLIST ~N~ c~ss ~~ /- · WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev~ redrll [] aery [] ON/OFF SHORE ~J ADMINISTRATION 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 drlg unit boundary. . I.Y 6. Well located proper distance from other wells ..... ~ Y 7. Sufficient acreage available in drilling unit. ~ Y 8. If deviated, is wellbore plat included ......... Y 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 ....... 'tY/ APPR DATE 14. Conductor string provided ............... Y~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg. . N 17. CMT vol adequate to tie-in long string to surf csg . . . Y ~ 18. CMT will cover all known productive horizons ...... .~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~X~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... Y~ N 26. BOPE press rating adequate; test to ~O~ psig'~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ N 28. Work will occur without operation shutdown ....... ~Y~ N 29. Is presence of N2S gas probable ............. Y ~ GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/_ 31. Data presented on potential overpressure zones ..... Y /N 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ ./Y N 34. Contact name/phone for weekly progress reports .... /. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: ~o~ <3~7/~7 ~ 7/27 Comments/Instructions: 'W/io. A:tFORMS~heklist rev 03/94 Well History File APPENDIX InformatiOn of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. MPJ - 09 9 ¥~*e r MILNE POINT Run 1: 16 - AUG - 1994 GR/SBT/CCL Cased Hole 9O75 O745 Er&l/ HICROFILME I~ ATLAS a, uas .vv.:cnne Services Tape Subfile ,2 is type: LIS TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPJ - 09 500292249500 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 23-SEP-94 6258.00 K. RICHARDS D. ROBERTSON 28 13N 10E 2346 3191 46.60 17.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) lST STRING 2ND STRING 13.375 112.0 3RD STRING 9.625 2936.0 PRODUCTION STRING 7.000 10840.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH GRCH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH SBT/GR/CCL Cased Hole. 40.00 26.00 *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 WAS NOT DEPTH SHIFTED SINCE PASS 1 IS THE DEPTH REFERENCE FOR THIS WELL. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY MPU TOOL CODE START DEPTH STOP DEPTH GRCH 9080.0 10715 o 0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS MPU CURVE CODE: PASS NUMBER: BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS). NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPJ - 09 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB 4 4 66 264 36 0 4 4 66 264 36 0 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 40 Tape File Start Depth = 10720.000000 Tape File End Depth = 9075.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9874 datums Tape Subfile: 2 126 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY MPU TOOL CODE GRCH $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS MPU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH 10444.0 STOP DEPTH 10715.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 10448.5 10449.5 10449.5 10450.5 10450.0 10451.5 10456.5 10458.0 10457.5 10458.5 10458.0 10459.0 10458.5 10460.0 10460.0 10461.5 10461.0 10462.0 10469.5 10470.5 10470.0 10472.0 10470.5 10472.5 10471.5 10473.0 10472.5 10473.5 10475.5 10476.5 10476.0 10477.5 10479.0 10480.5 10480.0 10481.0 10489.5 10490.5 10490.0 10491.5 10497.5 10499.0 10498.5 10499.5 10506.5 10507.5 10507.5 10508.0 10509.5 10510.0 10513.5 10515.0 10529.0 10530.5 10531.0 10534.5 10535.5 10539.0 10536.5 10539.5 10541.0 10544.5 10543.5 10545.0 10566.5 10568.0 10567.5 10568.5 10574.5 10575.5 10575.5 10576.0 10581.0 10581.5 10582.0 10582.0 in separate files. EQUIVALENT UNSHIFTED DEPTH 10582'.5 10589.5 10590.0 10596.0 10600.5 10601.0 10604.5 10605.0 10606.0 10611.5 10612.5 10623.5 10624.5 10640.0 10650.0 10651.5 10653.0 10664.5 10665.5 10676.0 10676.5 10677.0 10697.5 10701.5 10705.5 10706.5 10708.0 10708.5 10709.0 10710.0 10710.5 $ REMARKS: PASS 2 10583.0 10590.0 10591.0 10597.0 10601.0 10601.5 10605.5 10606.0 10607.5 10613.0 10613.5 10624.5 10625.0 10640.5 10650.0 10651.5 10653.5 10665.0 10665.5 10676.0 10676.5 10677.0 10697.5 10703.0 10707.0 10707.5 10708.0 10709.0 10709.5 10710.0 10710.5 (MAIN PASS). / ? ?MATCH2A. OUT $ CN : BP EXPLORATION WN : MPJ - 09 FN : MILNE POINT COLIN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units GRCH GR 68 1 GAPI TENS GR 68 1 LB Size 4 4 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 66 264 36 0 4 66 264 36 0 * DATA RECORD (TYPE# 0) Total Data Records: 1014 BYTES * Tape File Start Depth = 10720.000000 Tape File End Depth = 10440.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1684 datums Tape Subfile: 3 107 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9078.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 10730.0 16-AUG-94 FSYS REV. J001 VER. 1.1 1559 16-AUG-94 10754.0 10752.0 9075.0 10745.0 1500.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACOM SBT VDL $ CASING COLLAR LOC. GAMMA RAY ACOUSTIC COMMON SEGMENTED BOND VDL SUB TOOL NUMBER 2346XA 1309XA 1633EA 1424XA 1424PA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 10840.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): DIESEL & WATER .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP'NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 1 (MAIN PASS) . $ CN : BP EXPLORATION WN : MPJ - 09 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TTEN GR 68 5 TEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 1 LB 4 4 21 990 60 6 4 26 165 19 6 4 76 115 41 1 4 10 579 41 1 4 10 579 41 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 158 Tape File Start Depth = 10730.000000 Tape File End Depth = 9078.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 49529 datums Tape Subfile: 4 233 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10443.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL CASING COLLAR LOC. GR GAMMA RAY ACOM ACOUSTIC COMMON SBT SEGMENTED BOND VDL VDL SUB $ STOP DEPTH 10730.0 16-AUG-94 FSYS REV. J001 VER. 1.1 1400 16-AUG-94 10754.0 10752.0 9075.0 10745.0 1500.0 YES TOOL NUMBER 2346XA 1309XA 1633EA 1424XA 1424PA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 10840.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): DIESEL & WATER .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP'NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 PASS 2 (REPEAT PASS). $ CN : BP EXPLORATION WN : MPJ - 09 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TTEN GR 68 5 TEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 1 LB 4 4 21 990 60 6 4 26 165 19 6 4 76 115 41 1 4 10 579 41 1 4 10 579 41 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 28 Tape File Start Depth = 10730.000000 Tape File End Depth = 10443.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 8579 datums Tape Subfile: 5 103 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS 94/ 9/14 01 **** REEL TRAILER **** 94/ 9/14 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 14 SEP 94 1:53p Elapsed execution time = 5.00 seconds. SYSTEM RETURN CODE = 0 PAGg! FTLF' all hit runs i'oerqe'"~. IS Tare L,,"?] t':icOt,?,:?n [ i.~t''ic, PAOE: 29~,6,0 5520. C, 552n, 0 596~. 2o,%6.0 S520. O 552o. 0 5e6~,. 0 5961 ,{} 9676.0 9676.0 i. 0753,0 PAGE: [ b ,E: i',~ C U O £ ( d E X ) t 4 68 aO00oOoo00 RAG~: 1.1~1 -999.25o -ogq.25Q -~9~ 2S" 1.675 0,047 14.963 1.9.827 -999.250 -999,250 -999,250 -999,250 1,574 2,026 !4.1~3 -999,250 ~.:eader d,ata t ;i! ~': 3 7'. O, files. PAGe: (l:®): 2 q .3 <',. 0 74.0 78.0 PAGE~ 10 R O ~:3 r::. 1, ::., ! -~99.250 -999.~50 -999.250 -999.250 -999.250 -999,250 -999,250 -999.250 .~'~, % ';t 0 ':7) files, PAGe: 11 !. 5 5,0 2,7 a 0 2 , 6 5 74,0 78.0 12 13 -99~. 25(: -999. 250 -999.250 -999.250 -999.250 -999.250 -999,250 L 0 fi]es. 14 1 55. 74.0 15 ** [;; A i? A *; DEPT. PSP. L.~ 3 T A g. !..,~ 3 -999.25 -999.250 -999,250 -999.250 IS Ta?e 7erification [,istir:,:2 16 TAF. L,', 3 -?.:99.25<, -999.2~o T~iP~i. ut,:'3 -99g.2~0 GR.L~3 -999.250 -999.250 -999.250 8gaV.[C~; : ¥ f a S i P '~ D~TF : o4/!0/26 h,~X },,~'"C SJZE : F~LF TYPE : 8KRv.'i Cg : ?bIC yERSI0?i : DATT : 94,/1 qi26 FILE ~" ~' P b: : b~ST FILE ~urves and lo9 !",eerier ,~ata i~r e~ch bit 108bO.O files, IS Tave Veriiicat~on I ;~sti,~,q chlurf:ber~.r Al. as<a Co~ ottLi~n Center 2b-fiCT-!gq4 i.~ :!.2 PAGg~ 17 45. 74.0 78.0 8~ ;)9 ~m, ,.m~ mmm ~mm mmm ~tmm~ mmm ~mm ~m~ mm ~m~ ~m- ~ ~m~ mm, 0 O-Si 6 ~- g g-6 g 0 "' 0 O~g'666- O~Z'666- 0~g'666- 0q~'666-