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197-005
P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Oct 13, 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Roger Mouser ConocoPhillips Well Integrity Field Supervisor Roger Mouser Digitally signed by Roger Mouser Date: 2020.10.13 13:10:42 -08'00' By Samantha Carlisle at 1:21 pm, Oct 13, 2020 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 10/13/20 2K 2M 3K 3O 3Q 3R 3S pad Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 2K-30 50103207580000 2170720 22" 0.3 6" 3/8/2020 2.5 9/29/2020 2K-32 50103207570000 2170420 29" 0.5 6" 3/8/2020 3 9/29/2020 2M-37 50103207450000 2160820 30" 0.4 9" 7/31/2020 2.1 9/29/2020 2M-38 50103207460000 2160830 4" N/A 4" N/A 2.5 9/29/2020 3K-32 50029227630000 1970760 10"Conductor extension 10" 4/27/2019 2.5 9/27/2020 3K-34 50029228790000 1980770 14" Conductor extension 14" 4/27/2019 9 9/27/2020 3O-01A 50029218360000 2151910 62" 0.70 11" 3/8/2020 4.25 9/27/2020 3O-19 50029227530000 1970500 13"Conductor extension 13" 4/27/2019 4.25 9/27/2020 3O-20 50029227500000 1970450 21 5.00 17" 9/27/2020 6 9/27/2020 3Q-22 50029226250000 1951860 20' 3.25 8" 3/8/2020 4.25 9/26/2020 3R-101 50029235740000 2170130 21" 0.40 8" 8/14/2020 1 9/26/2020 3R-102 50029235720000 2161570 54" 1.10 6" 8/14/2020 6 9/26/2020 3R-105 50029236510000 2191340 22" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-106 50029236410000 2190970 36" 0.60 9" 8/14/2020 3.5 9/26/2020 3R-107 50029236600000 2191810 32" 0.60 9.5" 8/14/2020 1 9/26/2020 3R-111 50029236430000 2191050 25" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-112 50029236370000 2190850 36" 0.60 14"8/14/2020 7 9/26/2020 3S-611 50103207740000 2181030 11' 10" 2.50 8"6/30/2019 2.5 9/27/2020 3S-612 50103207770000 2181110 43" 0.75 8" 6/30/2019 3.5 9/27/2020 3S-613 50103207350000 2160200 22" 0.75 8" 6/30/2019 1.7 9/27/2020 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. i ~ q- 0 0~ 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. n Other, No/Type .OVERSIZED Logs of various kinds Other COMMEN'r~: Scanned b ,~Mildred. D~relfla Nathan Lowell TO RE-SCAN Notes: ... -. -...c ,:e _ 'R{ "°@mt?c;^'a# ., .,'•, •vnl3ri; .4CN TM.a'. ?.+ by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 r December 30, 2011 2 � ..m p�. n � A t' /F ¢ t) Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 4 �' 1 333 West 7 Avenue ®� t Y �4 l ks .N Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPE -Pad — 0 0 S Dear Mr. Maunder, f`A f`' 0 E - L k Enclosed please find multiple copies of a spreadsheet with a list of wells from MPE -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPE -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal MPE -02 1851910 50029214170000 3.8 NA 3.8 NA 5.95 8/23/2011 MPE -03 1890170 50029219160000 Tanko conductor NA NA NA NA NA MPE-04 1900050 50029219970000 Tanko conductor NA NA NA NA NA MPE -05 1900810 50029220580000 Sealed conductor NA NA NA NA NA MPE-06 1910480 50029221540000 0.2 NA 0.2 NA 6.8 9/6/2011 MPE -07 1910490 50029221550000 Sealed conductor NA NA NA NA NA MPE -08 1910500 50029221560000 Sealed conductor NA NA NA NA NA MPE-09 1941320 50029225130000 14.0 NA Need top job MPE -10 1941430 50029225210000 0.9 NA 0.9 NA 7.65 8/23/2011 MPE -11 1950010 50029225410000 11.0 NA Need top job MPE -12 2050670 50029232620000 1.0 NA 1.0 NA 4.25 8/23/2011 MPE -13B 2020440 50029225360200 Dust Cover NA NA NA 57.8 9/6/2011 ---3P MPE -14 1970050 50029227340000 0.0 NA 0.0 NA 7.65 10/10/2011 MPE -15 1941530 50029225280000 0.8 NA 0.8 NA 8.5 8/26/2011 MPE -16 1961140 50029226860000 0.6 NA 0.6 NA 5.95 8/26/2011 MPE -17 1961150 50029226870000 12.8 NA Need top job MPE -18 1970420 50029227480000 2.3 NA 2.3 NA 17 8/23/2011 MPE -19 1970370 50029227460000 0.1 NA 0.1 NA 7.65 10/10/2011 MPE -20A 2040540 50029225610100 1.0 NA 1.0 NA 6.8 8/23/2011 MPE -21 1981150 50029228940000 3.0 NA 3.0 NA 10.2 8/23/2011 MPE -22 1950810 50029225670000 0.8 NA 0.8 NA 3.4 8/23/2011 MPE -23 1950940 50029225700000 1.6 NA 1.6 NA 15.3 9/6/2011 MPE -24A 2001860 50029228670100 0.2 NA 0.2 NA 5.1 9/6/2011 MPE -25A 2040450 50029229800100 2.0 NA 2.0 NA 15.3 8/23/2011 MPE -26 2002060 50029229940000 Dust Cover NA NA NA 5.1 9/6/2011 MPE -28 2050550 50029232590000 1.8 NA 1.8 NA 15.3 8/23/2011 MPE -29 2010370 50029230040000 Dust Cover NA NA NA 3.4 9/6/2011 MPE -30A 2010110 50029229030100 0.3 NA 0.3 NA 2.55 8/26/2011 MPE -31 2050720 50029232630000 2.0 NA 2.0 NA 13.6 8/23/2011 MPE -32 2050650 50029232610000 1.5 NA 1.5 NA 13.6 8/23/2011 MPE-33 1981280 50029228980000 4.1 NA 4.1 NA 7.65 8/23/2011 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~1 E~ ~~E C~ ~ 20Q9 WELL COMPLETION OR RECOMPLETION REPORT ommiss 1 a. Well Status: ^ Oil ^ Gas ^ SPLUG ^ Plugged ®Abandoned ^ Suspended zoAACZS.~os 2oAACZS.~io ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completions Zero 1 b. We f Class: ; , , ~ , , ®Developmeht` " ~ ~kkploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., Aband.: 12/13/2009 12. Permit to Drill Number: 197-005 309-362' 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 04/02/1997 13. API Number. 50-029-22734-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached: 04/09/1997 14. Well Name and Number. MPE-14 3590 FSL, 1918 FEL, SEC. 25, T13N, R10E, UM Top of Productive Horizon: 483' FNL, 159' FWL, SEC. 31, T13N, R11 E, UM g. KB (ft above MSL): 57,7' GL (tt above MSL): 24.3' 15. Field /Pool(s): Milne Point Unit / Kuparuk River Total Depth: 693' FNL, 373' FWL, SEC. 31, T13N, R11E, UM 9. Plug Back Depth (MD+TVD): 8950' 6938' Sands 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 569228 y_ 6016128 Zone- ASP4 10. Total Depth (MD+TVD): 9370' 7300' 16. Property Designation: ADL 025518 & 028231 TPI: x- 571344 y- 6012074 Zone- ASP4 Total Depth: x- 571560 Y- 6011866 Zone- ASP4 11. SSSV Depth (MD+TVD): N/A 17. Land Use Permit: 18. Directional Survey: ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore: N/A ft MSL 20. Thickness of Permafrost (TVD): 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): LWD 22. Re-Drill/Lateral Top Window MDlfVD: N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED> 2 1 1# H-4 Urfa 1 2' rf 11 24" 2 0 xArcti e l A r x. - / ~~ ~~ 17 PF ~ 1 7" 2 L- 0 2 ' 7 7' -1/ " 250 x CI ss' 24. Open to production or injection? ^ Yes ®No 25. `TUBING RECORD If Yes, list each interval open (MD+TVD of Top i3< Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD / TVD MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC: _ ,~ +~ ~ ~ ~ DEPTH INTERVAL (MD AMOUNT AND KIND OF MATERIAL USED ~ ~ a 3 %~`~~~ ,~~1 ° 8975' Set CIBP • 8950' Set Whipstock " 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: Production For Test Period OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 28. CORE DATA Conventi onal Core(s) Acqui red? ^ Yes ® No Sidewall Core(s) Acquired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each}, and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None RBDMS DEC 3120 ~,~ Form 10-407 Revised 07/2009 CONTINUED ON REVERSE ~~// Submit Original Only ' ~" -1'~~ ./~~d 29: GEOLOGIC MARKERS (List all formations and ma encountered): 30. RMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Kuparuk 8786' 6799' None KC1 9020' 6998' TKB7 9055' 7028' Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing -s true and correct to the best of my knowledge. Signed: Terrie Hubble Title: Drilling Technologist Date: MPE-14 197-005 309-362 Prepared ey NameMumber. Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. Drilling Engineer: Sean McLaughlin, 564-4387 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. Submit a well schematic diagram with each 10-407 well completion report and 10.404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Rem 13: The API number reported to AOGCC must be 14 diglts (ex: 50-029-20123-00.00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producng intervals for onty the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Rem 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.07E Form 10-407 Revised 07!2009 Submit Original Only • MPE-14, Well History (Pre Rig Sidetrack) Date Summary 10/24/2009 T/I/0=250/200/120 Pre RWO Freeze Protect. Pumped 15 bbls Diesel down tubing. Pumped 2 bbls 60/40 methanol, 3 bbls diesel, and 2 bbls 60/40 methanol down production and test flowlines. Closed lateral valves and Bleed pressure down to 0 psi. Unable to bleed production line down due to leaking valve. FWHP=100/140/40 Master, IA, OA, and SSV open. Swab, wing, and Lateral valves closed. 10/30/2009 T/I/0=320/350/0 Assist S-Line PT Tbg to 2500 psi for 10 min. (PASS) Pumped 6 bbls diesel down Tbg to pressure up. Loss of pressure in previous tests were determined to be from a leaking block valve. Bled down Tbg. DSO notified slb s-line on well upon LRS departure. FWHP's=320/350/0 10/30/2009 WELL S/I ON ARRIVAL. RAN SBHPS, MADE 15 MIN STOP C«~ 8309' MD, AND MADE 3HR STOP C~ 8826' MD. RAN 2.313" CAT VALVE, SD CAB 2823' SLM, UNABLE TO PASS THROUGH. RAN 2.30" GAUGE RING MADE SEVERAL PASSES FROM 2800'-2900' SLM. TAGGED XN NIPPLE C~3 8813' SLM. MADE SEVERAL ATTEMPTS W/CAT VALVE. WORKED THRU SPOT C~1 2823' SLM. SET C~ 8613' MD. LRS P/T TBG TO 2000 PSI. MONITORED PRESSURE. GOOD TEST. PULLED CAT VALVE. PULLED 1" DMY VALVE FROM 8670' MD. POCKET LEFT OPEN. PULLED 1" DPSOV FROM 139' MD. RUN PDS CALIPER AS PER PROGRAM. 10/31/2009 RUN PDS CALIPER AS PER PROGRAM FROM 8820' SLM. SET 1" DGLV C~1 139' MD. ASSISTED SUPPORT TECHS INSTALL BPV. BPV SET. WELL LEFT S/I ON DEPARTURE. Nabors 4ES moved on well to pull ESP completion and run workstring. (11/14/09 - 11/20!09) 11/22/2009 WELL S/I ON ARRIVAL. ASSIST SUPPORT TECHS PULL BPV. UNSUCCESSFUL, APPEARS TO BE ICE, TARP UP TBG HANGER & INSTALLED HEAT. 11/23/2009 ASSIST SUPPORT TECHS W/CRANE & PULLED BPV. PULLED BALL & ROD W/ RHC FROM 8816' MD. RIH W/ 20' X 3.70" WHIPSTOCK DUMMY,TAGGED C~3 8946' SLM. WELL LEFT S/I ON DEPARTURE. 11/25/2009 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 50 / 0 / 0 PSI. BAKER THROUGH-TUBING WHIPSTOCK SET IN 7". TOP OF WHIPSTOCK AT 8950'. ORIENTED AT 0 DEC (HI ~H ID~)~_RA TAGS LOCATED 10' BELOW TOP AT 8960'. ASSISTED WELL SUPPORT IN INSTALLING A BPV. FINAL T/I/O = 0 / 0 / 0 PSI. JOB COMPLETE. Page 1 of 1 • • BP EXPLORATION Page 1 of 6 Operations Summary Report Legal Well Name: MPE-14 Common Well Name: MPE-14 Spud Date: 12/11/2009 Event Name: WORKOVER Start: 11/6/2009 End: ~-' Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To I Hours Task Code NPT Phase Description of Operations ~J,,~2 ~sP 11/14/2009 06:00 - 06:30 0.50 RIGD P PRE PJSM -SCOPE DOWN AND LAY OVER DERRICK. SIT' -AOGCC GIVEN 24-HR. NOTICE OF IMPENDING BOPE TEST. -NOTICE GIVEN AT 16:30-HRS. ON 11/13/2009. 06:30 - 11:30 5.00 RIGD P PRE SCOPE DOWN DERRICK. LAY DERRICK OVER ONTO HEADACHE. 11:30 - 12:30 1.00 MOB P PRE MOVE PITS, PIPE SHED AND SUB OFF WELL. -PICK UP RIG MATS AND HERCULITE AROUND WELLHEAD. 12:30 - 15:00 2.50 MOB P PRE MOVE RIG COMPONENTS FROM MPH-13 TO MPE-14. -LAY HERCULITE BERM AROUND WELLHEAD. -SET RIG MATS AND STOMPER MATS AROUND WELLHEAD. 15:00 - 20:00 5.00 RIGU P PRE SPOT SUB, PITS AND PIPESHED. 20:00 - 22:00 2.00 RIGU P PRE RAISE AND SCOPE DERRICK. -HOOK UP LINES BETWEEN SUB AND PITS. 22:00 - 23:00 1.00 KILL P DECOMP ACCEPTED RIG AT 22:00 HRS. -RU, SPOT TIGER TANK AND HOOK UP LINES. -RU CIRCULATING LINES TO TREE WING VALVE AND IA. -T/I/O = 450 / 400 / 0. -TEST LINES TO 3,500 PSI. -PASS. 23:00 - 00:00 1.00 KILL P DECOMP PU AND RU LUBRICATOR -TEST WITH DIESEL TO 500 PSI. -PASS. -PULL BPV. 11/15/2009 00:00 - 00:30 0.50 KILL P DECOMP LD LUBRICATOR. -T/I/O = 350 / 400 / 0 PSI. 00:30 - 04:30 4.00 KILL P DECOMP CIRCULATE KILLFLUID, 8.45 PPG SEAWATER. -BLEED DOWN TBG AND IA. -PUMP 60 BBLS HEATED SEAWATER DOWN THE TBG. -TAKE RETURNS UP THE IA THROUGH THE CHOKE. -T/I/O = 900 / 125 / 0 -BULL HEAD 20 BBLS HEATED SEAWATER. -T/I/O = 1050 / 125 / 0 PSI. -PUMP 336 BBLS HEATED SEAWATER. -PUMP DOWN THE TBG UP THE IA THROUGH THE CHOKE. -MONITOR WELL -WELL WAS DEAD. -PUMPED A TOTAL OF 416 BBLS. -LOST 132 BBLS TO THE FORMATION. 04:30 - 06:00 1.50 WHSUR P DECOMP -TEST FROM BELOW 3 BPM / 500 PSI. -TEST FROM ABOVE 3500 PSI / 10 CHARTED MINUTES PTSM -CREW CHANGE. -SERVICE RIG. ENVIRO WALK AROUND, DAILY DERRICK INSPECTION & CHECK PVT'S. 06:00 - 08:00 2.00 WHSUR P DECOMP ND PRODUCTION TREE. -I/A HAD 10-PSI ON IT. BLED OFF TO TIGER TANK. -FMC ENSURE HANGER VOID HAD PRESSURE. BLEED HANGER VOID. 08:00 - 12:30 4.50 BOPSU P DECOMP NU BOPE. -RIG UP BOPE TEST EQUIPMENT. 12:30 - 17:30 5.00 BOPSU P DECOMP TEST BOPE PER BP/AOGCC REQUIREMENTS: Printed: 12/30/2009 8:41:00 AM • BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: MPE-14 Common Well Name: MPE-14 Spud Date: 12/11/2009 Event Name: WORKOVER Start: 11/6/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date. ~ From - To Hours ', Task Code NPT Phase ( Description of Operations 11/15/2009 12:30 - 17:30 5.00 BOPSU P DECOMP BOP CONFIGURATION: -13-5/8" HYDRIL GK 5000. -BLIND SHEAR RAMS. -SPACER SPOOL. -2 7/8" X 5" VARIABLE BORE RAMS. -TEST CHOKE MANIFOLD, BLINDS, 2 7/8" X 5" VBR'S, -MANUAL CHOKE, HCR CHOKE, MANUAL KILL, HCR KILL, -FLOOR VALVES. -TEST TO 250 PSI LOW AND 3,500 PSI HIGH PRESSURE. -TESTED 2-7/8" X 5" VBR'S WITH 2-7/8" AND 4 1/2" TEST JOINTS. -TESTED ANNULAR WITH 2-7/8" TEST JOINT. -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -TEST WITNESSED BY WSL & TP. 200 PSI BUILD UP FROM 1600 PSI = 43 SECONDS. -FULL BUILD UP TO 3000 PSI = 178 SECONDS. -4 BOTTLES x 1625 PSI. -.IOHN CRISP WAIVED AOGCC RIGHT TO WITNESS BOPE TESTING AT 21:30-HRS. ON 11/14/2009. -RIG UP ESP CABLE SHEAVE DRAIN HOSE AND ELEPHANT TRUNK WHILE TESTING BOPE. 17:30 - 18:00 0.50 BOPSU P DECOMP RD / LD TEST EQUIPMENT. 18:00 - 19:00 1.00 BOPSU P DECOMP SERVICE RIG. CHECK ALARMS. INSPECT DERRICK. -INSTALL DUTCH RISER. 19:00 - 20:00 1.00 BOPSU P DECOMP PU LUBRICATOR. TEST TO 500 PSI W/DIESEL. -PASS. -PULL TWC. LD SAME. 20:00 - 20:30 0.50 BOPSU P DECOMP RD & LD DUTCH RISER SYSTEM. 20:30 - 21:00 0.50 PULL P DECOMP PULL TBG HANGER. -FMC BACKED OUT LOCK DOWN SCREWS. -PULLED 2-7/8" TUBING HANGER. -PULL OFF SEAT AT 62K WITH 64K PUW. -BREAK OUT LAY DOWN HANGER. 21:00 - 22:30 1.50 PULL P DECOMP CIRCULATED A BOTTOMS UP WITH 8.5 SEAWATER. -REQUIRED 19 BBLS TO FILL. THE HOLE. -PUMPED A TOTAL OF 320 BBLS. -4 BPM AT 1000 PSI. -LOST -40 BBLS TO THE FORMATION. 22:30 - 00:00 1.50 PULL P DECOMP POH W/ 2-7/8" ESP COMPLETION ASSEMBLY & CABLE. -STAND BACK 2-7/8' TBG. 11/16/2009 00:00 - 00:30 0.50 PULL P DECOMP CONTINUE TO POH W/ 2-7/8" ESP COMPLETION ASSEMBLY & CABLE. -STAND BACK 2-7/8' TBG. 00:30 - 01:30 1.00 PULL P DECOMP CHANGE OUT ESP SPOOLS -FIRST 1000' OF CABLE PLACE ON ONE SPOOL. -REMAINDER TO BE PLACED ON EMPTY SPOOL. 01:30 - 09:30 8.00 PULL P DECOMP CONTINUE TO POH W/ 2-7/8" ESP COMPLETION ASSEMBLY & CABLE. -STAND BACK 2-7/8' TBG. Y~ \~ Printed: 12/30/2009 8:41:00 AM BP EXPLORATION Page 3 of 6 Operations Summary Report Legal Well Name: MPE-14 Common Well Name: MPE-14 Spud Date: 12/11/2009 Event Name: WORKOVER Start: 11/6/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task 1 Code NPT Phase Description of Operations 11/16/2009 01:30 - 09:30 8.00 PULL P 09:30 - 10:00 0.50 PULL P 10:00 - 14:30 4.50 PULL P 14:30 - 15:30 1.00 CLEAN P 15:30 - 18:00 2.50 CLEAN P 18:00 - 21:30 3.50 CLEAN P 21:30 - 23:30 2.00 CLEAN P 23:30 - 00:00 0.50 CLEAN P 11/17/2009 00:00 - 01:00 1.00 CLEAN P 01:00 - 05:30 4.50 CLEAN P 05:30 - 06:00 0.50 CLEAN P 06:00 - 07:00 1.00 CLEAN P 07:00 - 09:00 2.00 CLEAN N 09:00 - 09:30 0.50 CLEAN P 09:30 - 16:30 7.00 CLEAN P DECOMP -CULL OUT 24 BAD JTS. IDENTIFIED BY CALIPER RUN. 3 JTS WITH BAD PINS. CRIMPED 2 ADDITIONAL JTS. WHILE POOH. -TOTAL CULLED = 29 JTS. DECOMP PJSM: REVIEWED LAYING DOWN ESP BHA AND RIGGING DOWN ELEPHANT TRUNK PROCEDURES. DECOMP LAY DOWN ESP BHA COMPONENTS DOWN PER CENTRILIFT. -RIG DOWN ELEPHANT TRUNK. -CLEAR AND CLEAN RIG FLOOR. DECOMP BRING SCRAPER BHA COMPONENTS TO RIG FLOOR. P G SCRAPER BH A -6-1/8" BIT - 0.80' -7" SCRAPER - 2.96' -4-3/4" BOOT BASKET - 4.47' -4-3/4" BOOT BASKET - 4.25' -XO - 1.12' e DECOMP RIF7WIT~" SCRAPER BHA. -PICKED UP 9 JTS. TUBING FROM PIPE SHED 1 X 1. RIH FROM DERRICK. DECOMP SERVICE RIG. CHECK ALARMS. INSPECT DERRICK. -CONTINUE TO RIH W/ 2-7/8" TBG FROM DERRCK. DECOMP RECIPROCATE 7" SCRAPER ACROSS PACKER SETTING. -RECIPROCATE ~ 8,750' MD. SINGLE IN AND TAG PACKER TOP @ 8,985' MD. -95 STDS, 1 SINGLE + 25'. DECOMP RU & CIRCULATE. PUMP HI VIS SWEEP. -PUMP 4.7 BPM / 1,000 PSI. CLEAN CONTINUE TO CIRCULATE. PUMP HI VIS SWEEP. -PUMP 4.7 BPM / 1,000 PSI. -PUMP A TOTAL OF 521 BBLS. --2 GAL OF FORMATION SAND AND CARBOLITE BEADS IN RETURNS. CLEAN POH WITH 7" SCRAPER ASSY AND STAND BACK 2-7/8" TBG. -DOUBLE DISPLACE STEEL VOLUME AND TUBING CAPACITY. -LD 2 SINGLES. CLEAN BREAK OUT AND LAY DOWN SCRAPER BHA. BOOT BASKETS WERE EMPTY. CLEAN CLEAR AND CLEAN RIG FLOOR. PREP TO RIH WITH HES CIBP. HMAN CLEAN HES REP DID NOT HAVE ADEQUATE UNDERSTANDING OF HOW HYDRAULIC SETTING TOOL WORKS AND CAUSED UNNECESSARY LOST TIME. CLEAN RESOLVED ISSUE WITH HYDRAULIC RUNNING TOOL AND PICKED UP 7u HES EZ DRIIL PLUG TO RIH. CLEAN RIH W - DERRICK. -95 STANDS, -(100' PER HOUR) AS PER HALLIBURTON Printed: 12/30/2009 8:41:00 AM BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: MPE-14 Common Well Name: MPE-14 Spud Date: 12/11/2009 Event Name: WORKOVER Start: 11/6/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 i Date From - To Haurs Task Code' NPT ! Phase Description of Operations 11/17/2009 16:30 - 19:30 3.00 CLEAN N RREP CLEAN ATTEMPTED TO TEST MUD PUMP -SENSOR WENT BAD THEN POP OFF WENT BAD -C/O POP OFF AND RE TESTED, POPED OFF AT 150 PSI -PICKED UP TWO JOINTS TAGGED 7" HES PACKER AT 8985' MD. ~ ~ _.,~,/ ~~ ~ S -PU 10' T/ 8,975' MD ~''" (J 19:30 - 23:00 3.50 CLEAN P CLEAN ESTABLISHED CIRCULATION AT 1 BPM / 60 P -DROPPED BALL PRESSURED UP TO 2000 PSI AND IN T OL. - P/U 10' AND PRESSURED TEST CASING TO 2000 PSI FOR 30 MIN. GOOD TEST CHARTED FOR 30 MIN ', -BLEED PRESSURE OFF IA , TO ENSURE NO TRAPPED PRESSURE BETWEEN BALL AND TIW VALVE. - PUMPED DOWN TUBING TO SHEAR BALL SEAT , SHEARED AT 4000 PSI. - PUW 47 K ,SOW 35 K , 65 K TO SHEAR. 23:00 - 00:00 1.00 CLEAN P CLEAN POH LAYING DOWN -LD 2 3-12" DP , -BREAK OUT AND LAY DOWN CIRCULATING EQUIPMENT 11/18/2009 00:00 - 06:00 6.00 CLEAN P CLEAN POH , LD 2-7/8" TUBING. -185 JNTS 06:00 - 06:30 0.50 CLEAN P CLEAN PERFORM PRE-TOUR CHECKS. 06:30 - 08:00 1.50 CLEAN P CLEAN M/U SET AND TEST 7" STORM PACKER _ -~ -30' MD -1,000 PSI F/ 10 MIN. -STEAM WELL HEAD. 08:00 - 09:30 1.50 BOPSU P OTHCMP ND BOPE -SECURE TO STUMP. -ND DSA 09:30 - 10:00 0.50 BOPSU P OTHCMP PJSM WITH FMC WELL HEAD TECK ON SPOOL / PACK-OFF CHANGE OUT. 10:00 - 17:00 7.00 WHSUR P OTHCMP FMC REP BLEED OFF ALL PRESSURE -NUTS WERE DIFICAULT TO REMOVE OLD TBG SPOOL. -REMOVE 7-1/16" X 11"TBG SPOOL W/ 8,000 (K) PULL. -PULL OLD PACK-OFF. -INSTALL NEW FMC MANDREL PACK-OFF. -INSTALL NEW 11" 5K X 11"TBG SPOOL. 17:00 - 18:00 1.00 WHSUR P OTHCMP NU DSA AND BOPE -TEST CASING HANGER FLANGE AND PACK OFF SEALS TO 5000 PSI FOR 30 MIN. 18:00 - 20:00 2.00 WHSUR P OTHCMP NU BOPE. -RIG UP BOPE TEST EQUIPMENT. 20:00 - 21:00 1.00 WHSUR P OTHCMP SAFETY STAND DOWN WITH JIM WILLINGHAM BP SUPERINTENDENT -DISCUSSIONS AROUND RECENT FATALITY 21:00 - 22:00 1.00 WHSUR P OTHCMP TEST BOPE PER BP/AOGCC REQUIREMENTS: - TEST BODY AND BREAKS 300 PSI LOW 3500 PSI HIGH -TEST PULSATION DAPNER - DRAIN STACK ,BREAK DOWN LINES 22:00 - 23:30 1.50 WHSUR P OTHCMP PU 1 JNT OF 3.5' DP WITH HES RTTS RUNNING TOOL. - RETRIEVE RTTS - FILL HOLE AND MONITOR 23:30 - 00:00 0.50 CLEAN P CLEAN POOH WITH 2-7/8" LAYING DOWN Printed: 12/30/2009 8:41:00 AM a ,. BP EXPLORATION Page 5 of 6 'I Operations Summary Report Legal Well Name: MPE-14 Common Well Name: MPE-14 Event Name: WORKOVER Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task I! Code NPT 11/19/2009 00:00 - 03:00 3.00 WHSUR P 03:00 - 03:30 0.50 WHSUR P 03:30 - 06:00 2.50 WHSUR P 06:00 - 11:00 I 5.00 11:00 - 11:30 0.50 11:30 - 12:30 1.00 12:30 - 14:00 I 1.50 14:00 - 00:00 I 10.00 11/20/2009 00:00 - 04:00 4.00 04:00 - 04:30 I 0.501 RU 04:30 - 06:00 I 1.50 I RU 06:00 - 10:00 I 4.001 RU 10:00 - 11:30 I 1.50 11:30 - 13:00 I 1.50 Spud Date: 12/11 /2009 Start: 11 /6/2009 End: Rig Release: 12/26/2009 Rig Number: N2 Phase Description of Operations OTHCMP POOH WITH 2-7/8" TUBING OTHCMP CLEAN AND CLEAR RIG FLOOR OTHCMP RU TO RUN 4.5" WORK STRING TUBING EQUIPMENT AND TORQUE TURN EQUIPMENT - FINISH LOADING PIPE SHED WITH 4.5" TUBING AND JEWLERY. RUNCMP SAFETY STAND DOWN AT MPU, CONCERNING FATALITY AT NGI-PAD. -CONVERSATION WITH CREW ABOUT THE IMPACTS. RUNCMP RIG SERVICE AND PERFORM PRE-TOUR CHECKS. RUNCMP COMPETE TUBING TALLY -CLEAN THREADS FOR BAKER-LOC. RUNCMP PJSM WITH CASING CREW AND BAKER REP ON P/U WORK STRING. - PU BAKER S3 PACKER AND PBR ASSEMBLY. RUNCMP PU & RUN 4-1/2" TBG WORK STRING FOR CTD OPERATIONS. -WITH BAKER S3 PACKER AND PBR ASSEMBLY. -RUN 72 JNTS OF 4-1/2", 12.6#, L-80, NSCT TUBING. -RUN 146 JNTS OF 4-1/2", 12.6#, L-80, IBT TUBING. -OPTIMUM TORQUE 4,700 FT/LBS. -USING BEST OF LIFE 2000 THREAD COMPOUND ON ALL IBT-M CONNECTIONS --USING JET LUBE SEAL GUARD THREAD COMPOUND ON ALL NSCT CONNECTIONS RUNCMP PU & RUN 4-1/2" TBG WORK STRING FOR CTD -WITH BAKER S3 PACKER AND PBR ASSEMBLY. -RUN 72 JNTS OF 4-1/2", 12.6#, L-80, NSCT TUBING. -RUN 146 JNTS OF 4-1/2", 12.6#, L-80, IBT TUBING. -OPTIMUM TORQUE 4,700 FT/LBS. -USING BEST OF LIFE 2000 THREAD COMPOUND ON ALL IBT-M CONNECTIONS -USING JET LURE SEAL GUARD THREAD COMPOUND ON ALL NSCT CONNECTIONS RUNCMP MAKE UP SPACE OUT PUPS AND HANGER AS PER TUBING TALLY -FMC AND BAKER ON LOCATION RUNCMP SPACE OUT TO _8,890' -LAND TUBING HANGER. PUW- 97K, SOW- 65K. -RUN IN LOCK DOWN SCREWS. TORQUE LOCK DOWN SCREWS TO 450 FT/LBS PER FMC -BACK OUT AND L/D LANDING JOINT. RUNCMP WAITING ON LITTLE RED SERVICES FOR FREEZE PROTECT -TRANSFERING 2-7/8" TUBING W/THREAD PROTECTORS TO MPB-PAD FOR STORAGE. -AND TREE. RUNCMP LITTLE RED SERVICES RU AND TEST LINES TO 2500 PSI -PUMP 70 BBLS OF DIESEL DOWN THE I.A. TAKING RETURNS OUT THE FLOW LINE -RD LRS RUNCMP RU TO ALLOW WELL TO U-TUBE Printed: 12/30/2009 8:41:00 AM • • BP EXPLORATION Page 6 of 6 Opera#ions Summary Report Legal Well Name: MPE-14 Common Well Name: MPE-14 Spud Date: 12/11/2009 Event Name: WORKOVER Start: 11/6/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 i .Date From - To' Hours Task Code NPT Phase Description of Operations 11/20/2009 11:30 - 13:00 1.50 BUNCO RUNCMP -OPENED THE IA TO THE CEMENT LINE TO THE MANIFOLD THROUGH THE KILL LINE TO THE TUBING -WEEKLY CREW CHANGE MEETING ~ 12:30 13:00 - 14:30 1.50 BUNCO RUNCMP DROP BALL AND ROD ,SET AND TEST PACKER. -TESTED PKR TO 3500 PSI FOR 30 CHARTED MIN, TEST GOOD. -TESTED CASING TO 2000 PSI FOR 30 CHARTED MIN, TEST GOOD. 14:30 - 15:00 0.50 WHSUR P RUNCMP SET AND TEST (TWC) -TESTED FROM ABOVE TO 3,500 PSI FOR 10 CHARTED MIN. TEST GOOD. -UNABLE TO TEST FROM BELOW 15:00 - 17:30 2.50 BUNCO P RUNCMP SAFETY STAND DOWN AT MILNE POINT DISCUSSION AROUND THE RECENT SLOPE FATALITY ON NGI-PAD -BOTH RIG CREWS AND LEADERSHIP TEAM ATTENDED -DISCUSSION TO FOLLOW ON IDEAS ON HOW TO AVOID THIS IN OUR WORKPLACE. 17:30 - 19:00 1.50 BOPSU P RUNCMP ND BOPS .REMOVE FLOW RISER AND BREAK OUT KILL AND CHOKE LINES. -SET BACK 19:00 - 22:30 3.50 WHSUR P RUNCMP NU NEW 4-1/8" TREE AND ADAPTER. PER FMC -TEST HANGER VOID AND TREE TO 5,000 PSI FOR 5 CHARTED MIN. 22:30 - 23:30 1.00 WHSUR P RUNCMP SECURE WELL WITH TWC SET IN PLACE PER WELL PLAN. -RD CLEAN UP 23:30 - 00:00 0.50 WHSUR P RUNCMP AFTER ACTION REVIEW WITH CREW ***** RIG RELEASE ~ 24:00 HRS ***** Printed: 12/30/2009 8:41:00 AM ~ ! BP EXPLORATION Page 1 :.Operations. Summary'Report Legal Well Name: MPE-14 Common Well Name: MPE-14 Spud Date: Event Name: REENTER+COMPLETE Start: 12/10/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N2 ~ Task Code NPT Phase Description of Operations Date From - To Hours 12/10/2009 02:00 - 02:05 0.08 MOB P PRE RIG RELEASED FROM W-25A AT 0200 HRS 02:05 - 04:00 1.92 MOB P PRE MOVE RIG FROM W-PAD TO SPINE ROAD. 04:00 - 09:00 5.00 MOB P PRE TURN ON TO SPINE ROAD HEADING WESTWARD TOWARDS MPU. 09:00 - 17:00 8.00 MOB P PRE TURN ON TO MP ROAD HEADING TOWARDS MP E-PAD. 17:00 - 17:30 0.50 MOB P PRE RIG ARRIVES ON MP E-PAD. SPOT RIG. RIG ACCEPT 17:00 HRS 12/10/09. 17:30 - 18:45 1.25 MOB P PRE ENTIRE RIG CREW ATTENDS ATP AT MPU CAMP. 18:45 - 19:00 0.25 RIGU P PRE PJSM FOR NIPPLE UP BOPE. 19:00 - 00:00 5.00 RIGU P PRE LEVEL RIG. SETY HANDY BERM CONTAINMENT. SPOT MISC EQUIP. NIPPLE UP BOPE. CONTINUED ON DIMS REPORT 12/11/09. 12/11/2009 00:00 - 02:30 2.50 RIGU P PRE CONTINUED FROM DIMS REPORT DATED 12/10/09. CONTINUE NU BOPE. 02:30 - 06:00 3.50 RIGU P PRE INSTALL 3" SLIP RAMS IN LOWER CAVITY OF UPPER COMBIS. 06:00 - 12:00 6.00 RIGU P PRE NIPPLE UP MANAGED PRESSURE DEPLOYMENT CIRCULATION LOOP TO WING AND MUD MANIFOLD. FUNCTION TEST BOPE. 12:00 - 14:30 2.50 RIGU P PRE LIQUID PACK STACK AND MANAGED PRESSURE DEPLOYMENT CIRCULATION LOOP WITH WATER. PJSM FOR ROPE TEST (WITNESS WAIVED BY AOGCC REPRESENTATIVE CHUCK SCHEVE). BEGIN TO PRESSURE UP, FIND LEAK ON CHOKE HOSE AT GREYLOCK. REPLACE RING IN GREYLOCK. LOAD PITS WITH GEOVIS. 14:30 - 15:00 0.50 RIGU P PRE PRESSURE TEST LOOP AND BOPE 250/3500 PSI FOR 5 MINUTES (BODY TEST). 15:00 - 18:00 3.00 RIGU P PRE TEST BOPE 250/3500 PSI FOR 5 MINUTES AS PER STATE 18:00 - 18:30 0.50 RIGU P PRE CREW C/O. PJSM FOR CONTINUING BOPE TEST. 18:30 - 22:00 3.50 RIGU P PRE CONTINUE TESTING BOPE. MU 3" TEST JOINT. TEST RAMS, LD TEST JOINT. DRAWDOWN TEST. 22:00 - 22:15 0.25 RIGU P PRE PJSM FOR REPLACING VALVE (BOP #17) WHICH EXPERIENCED ATHROUGH-BORE LEAK. 22:15 - 00:00 1.75 RIGU P PRE REPLACE VALVE (BOP #17). CONTINUED ON DIMS REPORT 12/12/09. 12/12/2009 00:00 - 00:30 0.50 RIGU P PRE CONTINUED FROM DIMS REPORT 12/11/09. PT VALVE BOP #17. 00:30 - 01:00 0.50 RIGU P PRE PJSM PRIOR TO REPLACING BX 154 RING GASKET ON SWACO FLANGE. 01:00 - 02:30 1.50 RIGU P PRE REPLACE RING GASKET ON SWACO FLANGE. PT SAME. 02:30 - 03:15 0.75 RIGU P PRE SPOOL NEW SLICKLINE ONTO WINCH DRUM. TWIST TEST SLICKLINE: 25 TURNS, CLEAN BREAK. GOOD TEST. 03:15 - 03:40 0.42 RIGU P PRE PJSM FOR PICKING UP SLICKLINE LUBRICATOR. 03:40 - 09:45 6.08 RIGU P PRE RIGGING UP SLICKLINE LUBRICATOR. REBUILD STUFFING BOX, ROPE SOCKET. SET BACK LUBRICATOR FILL CT W/ RIG WATER AND CIRC IN BUNG HOLE 09:45 - 12:00 2.25 RIGU P PRE SAFETY MTG W/ MPU VALVE CREW. BRING LUBRICATOR TOOLS TO FLOOR. FILL TREE AND STACK W/ DIESEL. PULL 4" BPV AND FOUND NO PRESSURE ON WELL, IA 23, Printed: 12/21/2009 10:19:08 AM • BP EXPLORATION Page 2 ~~ Operations Summary Report Legal Well Name: MPE-14 Common Well Name: MPE-14 Spud Date: Event Name: REENTER+COMPLETE Start: 12/10/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N2 Date From = To ~ Hours Task Code NPT Phase Description of Operations 12/12/2009 09:45 - 12:00 2.25 RIGU P PRE OA 18 RDMO VALVE CREW 12:00 - 13:00 1.00 RIGU P PRE SAFETY MTG. ND WING VALVE COMPANION BLIND FLANGE W/ 1/2" NPT CHEMICAL INJECTION PORT DUE TO THREADED CONNECTION. NU INTERIM 3650 PSI RATED BLIND FLANGE WHILE SOURCING CORRECT 5K FLANGE 13:00 - 15:00 2.00 BOPSU P PRE SAFETY MTG. PU INJECTOR AND STAB ON. PT BLIND FLANGE, PACKOFF AND INNER REEL VALVE 250/3500. FIX THREE DRIPS 15:00 - 15:30 0.50 STWHIP P WEXIT SAFETY MTG. MU NOZZLE BHA 15:30 - 17:10 1.67 STWHIP P WEXIT RIH W/ 3" NOZZLE CIRC 0.51/200 FW WHILE TAKE DIESEL FP TO TIGER TANK TO 8000' 17:10 - 18:30 1.33 STWHIP P WEXIT POH CIRC 1.63/1800 WHILE CYCLE SWACO CHOKE AND CHECK FOR CORRECT OPERATION W/ BOTH CREWS ', 18:30 - 18:45 0.25 STWHIP P WEXIT PJSM, FLOW CHECK. 18:45 - 19:00 0.25 STWHIP P WEXIT LAY DOWN NOZZLE ASSEMBLY. 19:00 - 20:30 1.50 STWHIP P WEXIT CUT CT UNTIL FIND WIRE (CUT 350' CT). TEST WIRE, REBOOT. MU INJECTOR. PERFORM SLACK MANAGEMENT. 20:30 - 23:30 3.00 STWHIP P WEXIT INSTALL CTC, PULL TEST TO 30K LB. BEHEAD BHI, PT CONNECTOR 4000 PSI. 23:30 - 00:00 0.50 STWHIP P WEXIT PUMP SLACK FORWARD. T/I/O: 0/17/20 PSI. CONTINUNED ON DIMS REPORT 12/13/09. 12/13/2009 00:00 - 02:00 2.00 STWHIP N HMAN WEXIT CONTINUED FROM DIMS REPORT 12/12/09. T/I/O: 0/17/20 PSI. INSTALLED API 5000 BLIND FLANGE ON COMPANION SIDE OF FLOW CROSS (REPLACING ANSI 1500 FLANGE FROM SAME). PT TO 3000 PSI. 02:00 - 03:00 1.00 STWHIP P WEXIT PJSM FOR PRESSURE DEPLOYMENT PRACTICE RUN. 03:00 - 07:00 4.00 STWHIP P WEXIT MU BHI TOOLS. PRACTICE RUN OF PRESSURE DEPLOYMENT. 07:00 - 07:45 0.75 STWHIP P WEXIT SAFETY MTG. LD DUMMY BHA. PT LUBRICATOR TO 2500 PSI. BREAK OFF LUBRICATOR AND FOUND SL HAD PARTED -3' FROM ROPE SOCKET. ASSUME THAT SL WAS NOT TAGGED UP PRIOR TO PT ATTEMPT TO BLOW DOWN CELLAR LINES THRU CHOKE LINE AND FOUND AN OBSTRUCTION 07:45 - 08:45 1.00 STWHIP N HMAN WEXIT RETHREAD SL THRU LUB, REBUILD ROPE SOCKET. STANDBACK LUB ASSY STEAM CHOKE LINE 08:45 - 13:30 4.75 STWHIP N RREP WEXIT CONTINUE TO TROUBLESHOOT RESTRICTION IN CHOKE LINE. DETERMINE LINE IS NOT FROZEN, THEN WORK TO FIND RESTRICTION. FIND OBSTRUCTION ABOUT 10' AND TWO 90'S UPSTREAM FROM GAS BUSTER. ALTERNATE USING AIR, MUD AND SNAKES TO MOVE SOLID GREASE BALL AND CIRC FREELY 13:30 - 13:45 0.25 STWHIP P WEXIT SAFETY MTG PRIOR TO MU BHA 13:45 - 16:30 2.75 STWHIP P WEXIT BLOW DOWN CIRC LOOP, KILL LINE AND CHOKE LINE PULL TEST SL TO MAX -1800# MU MILLING BHA FOLLOWING DEPLOYMENT SCHEDULE BUT WO PRESSURE FIND MU POINT IS 44" FROM NO-GO, TAG UP IS 1.6' 16:30 - 18:10 1.67 STWHIP P WEXIT RIH CIRCULATING THROUGH MILL 0.51/282 Pnntetl: 12/21/2009 10:19:Vt3 AM BP EXPLORATION Page 3 c~ Operations Summary Report Legal Well Name: MPE-14 Common Well Name: MPE-14 Spud Date: Event Name: REENTER+COMPLETE Start: 12/10/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N2 Date From = To Hours Task COde NPT Phase Description of Operations 12/13/2009 18:10 - 19:20 1.17 STWHIP P WEXIT TIE IN AT 8550' - 8850' W/ GR. CORRECTION OF +9.5'. 19:20 - 20:00 0.67 STWHIP P WEXIT MAKE CCL PASS FROM 8500' TO 8900'. 20:00 - 20:20 0.33 STWHIP P WEXIT TAG WHIPSTOCK AT 8956.9 WHILE PUMPING AT MIN RATE. 20:20 - 20:40 0.33 STWHIP P WEXIT BEGIN MILLING WINDOW. 2.17 BPM AT 3480 PSI ~~n FREESPIN. rnap~.~C{~} 20:40 - 22:00 1.33 STWHIP P WEXIT MILLING AHEAD. AT 21:10 HRS, RECEIVE NOTIFICATION FROM TOWER PUSHER THAT THERE HAS BEEN A SEWAGE RELEASE FROM THE RIG CAMP ON MP A-PAD. TOWER PUSHER BEGINS TO TROUBLESHOOT/STOP LEAK, CO. MAN BEGINS MAKING NOTIFICATIONS. NOTIFY MP RADIO, WHO NOTIFIES MP ENVIRONMENTAL, VAC TRUCK DRIVER, AND MP A-PAD OPERATOR. CO. MAN ALSO CALLS DRILLING HSE ADVISOR, CT DRILLING SUPERINTENDENT, AND MP WELLS GROUP. LEAK ISOLATED, APPROX VOLUME OF 20 GALLONS (LATER AMENDED TO APPROX 84 GALLONS). MP ENVIRONMENTAL ON LOCATION. SEWAGE VAC TRUCK ON LOCATION. DRILLING HSE TO ASSIST IN CREATING TRACTION REPORT IN THE AM. 22:00 - 23:15 1.25 STWHIP P WEXIT SWAP TO GEOVIS DOWN COIL THROUGH BIT WITH WATER RETURNS TO PIT 5. DIRTY VAC TYING IN TO PIT 5 TO TAKE WATER RETURNS. PRIOR TO SWAPPING TO GEOVIS, MILLING AHEAD AT 2.18 BPM AT 3700 PSI. SEEING OCCASIONAL MOTOR WORK (STACKING -1500 LB AT SURFACE WITH AN INCREMENTAL -200 PSI MOTOR WORK, MILLS OFF). 23:15 - 00:00 0.75 STWHIP P WEXIT STARTING TO GET GEOVISM/ATER INTERFACE BACK IN PITS. WAIT FOR CLEAN GEOVIS, THEN SWAP TO MUD PIT. CONTINUE CIRCULATING GEOVIS TO PIT 2. CIRC PRESSURE STABLE AT 2960 PSI AT 2.17 BPM, WHP = 70 PSI. PU. UP WEIGHT CLEAN AT 24,000 LB. CIRC PRESSURE 2960 PSI AT 2.17 BPM. INCREASE CIRC RATE. NEW FREESPIN 3310 PSI AT 2.41 BPM WITH 50 PSI WHP (FULL OPEN CHOKE). EQUIVALENT ECD IS 9.79 PPG. BEGIN TO APPLY BACKPRESSURE TO MAINTAIN 11.0 PPG ECD. ABLE TO HOLD 11.0 PPG EMW BY HOLDING 505 PSI ON CHOKE, 3750 PSI CIRC PRESSURE, 2.41 BPM. RBIH AND ENGAGE AT 8958.3'. SEE 200 LBS WOB INCREASE AND 40 PSI MOTOR WORK. MILL AHEAD. IAP STARTING TO INCREASE SLIGHTLY (FROM -15 PSI TO 355 PSI SINCE WE SWAPPED TO WARM GEOVIS). MONITOR IAP FOR CONTINUED THERMAL EXPANSION. T/I/O: 505/355/26 CONTINUED ON DIMS REPORT 12/14/09. 12/14/2009 00:00 - 03:15 3.25 STWHIP P WEXIT CONTINUED FROM DIMS REPORT 12/13/09. T/I/O: 513/344/28 PSI TIME MILLING AT WINDOW. FREESPIN 3750 PSI, 2.41 BPM, 505 PSI WHP. SEE MOTOR WORK AT 8959.0'. STACK 3000 LB WOB AND SEE INCREMENTAL 500 PSI MOTOR WORK. MILLS OFF. CONTINUE TIME DRILLING AHEAD. Printed: 12/21/2009 10:19:08 AM ~` S Proposed ~e: Cameron 2 9/16" 5M ~Ilhead: 11" x 7 1/16" 5M FMC n 5A, w/ 2 7/8" FMC tbg. hng., 3" acme on top and 2 7/8" EUE 8 rd bottom, 2.5" CIW BPV profile 20" 91.1 ppf, H-40 112' 9 5/8", 40 ppf, L-80 Btrc. 5543 Orig. KB Elev. = 57.60' (N 27E) Orig. GL Elev. = 24.T RT To Tbg. Spool = 33.5 (N 27E) 4-1/2" Workstring to be pulled for ESP completion post CTD Stimulation Summary None performed Baker 20' PBR Above Packer @8706` Baker 7" x 4-1/2" S-3 L-80 Packer (To Remain in the Hole post W/O)_ @8745' 4-1/2" TTail with WLEG @ 8,890'- 3-3/16" Solid Liner Shoe @ 9073' 2-3/8" Solid/Cmt'd Liner` PBTD C~ 10.105' Perforation Intervals All shots using 1.56" 6 SPF 1606PJ 9500' - 9560' 9660' - 9900' 9960` - 10050' MPU E-14A le Lateral 67 Sand CTD Sidetrack DATE REV. BY COMMENTS 04-12-97 DS-08-97 MDO MDO 7" Cased hole Completion 27E ESP am letion 4-ES 9-15-97 MDO 2nd ESP Completion 4-ES 7-19-96 MDO ESP Completion/Screen Added 5 S 03-21-00 M. Linder RW04-ES 6-28-08 LH RWO with 3S -XNIP3.813"ID@8680' ,4.5" KB Liner Top Packer @ 8,739' 3.7" Deply Slv on 2-3/8" LNR @ 8,747' --3-3/16" Liner Hanger @ 8,769' -XNIP3.813"ID@8816' maker 4-1/2" x 7" Whipstock @ 8,950'° 7" CIBP @ 8975 ~ ~HES Versatrieve Pkr. 8985' 4.5" 316E 125 Micron 9031' Poroplus screen 11.6# LTC 4.5" HES XN-Nipple (2.750" id 9103' ( W/ Plug ) WLEG 9115' 7" float collar (PBTD) 9260' ~ 7" float shoe 9344' MILNE POINT UNIT Well No : E-14 API : 50-029-22734 BP EXPLORATION (AK) • • ~ ~ ~ ~~' ~ ~ . u ~. ~.~ r, q ~g ~ ~ ~ a ~ ,. ~ ~ ~ [ e ~ ~ d ~ ~ ~ , @ ~ ~ ~ R ~ ~~ ~ ~° ,~~ ~ ~ ~ ~ ; ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~~ ~ ~~ ~~ ~ ~ ~ ~ ~ ~ SEAN PARNELL, GOVERNOR a~~~ t~ ~~ ~~ ~ ~ ~ ~~~ ~ ~ ~ ~ ~~ ~ ~~ ~,_~ ~~,: ~~ ~~. ~~ ~~~ ~ ~ ~~ ~ &~~~ ~. ~~~ ~~ ~ t~asc~S~A ~IL ~~ V[t~a7 ~ 333 W. 7th AVENUE, SUITE 100 COI~TSE~iQATIOr1T COMl-IISSIOI~T ~ ANCHORAGE,ALASKA 99501-3539 PHONE (907) 279-1433 ~ FAX (907) 276-7542 Mr. John Mc Mullen Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 a ~ Anchorage, Alaska 99519-6612 ~ ~ ~ '~ Re: Milne Point Unit, Kuparuk River Sands, MPE-14 Sundry Number: 309-362 ~~~~~~~ ~~?';~ ~; {~.-- 2C-C~' Dear Mr. Mc Mullen: Enclosed is the approv~d Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair n DATED this ?' day of November, 2009 Encl. STATE OF ALASKA ALAS IL AND GAS CONSERYATION COMMt N APPL~ATION FOR SUNDRY QPPR AL 2n aAC 2~.2~0 ~~~sG~ i/ ~~ acT z ~ zoo~ 1. Type of Request: ~$ ~ 6 85 t1tIS. Otil(Ill ~ Abandon ^ Suspend ^ Operational Shutdown ^ PerForate 0~~-~~~ s~~ v~pnchorage ^ Aiter Gasing ^ Repair Welt ^ Plug Perforatio~s ^ Stimulate ~ Qther Sp~cify: ^ Change Approved Program ~ Puii Tubing ^ Perfarate Nevir P~I ^ Time E~ctension Run 4-1J2" Workstring 2. Operator Name: 4. Currertt Well Cfass: 5. Perm~'Fo E}rit! Number BP Exploration (A{aska) Inc. ~ Development ^ Exploratory 197-005 3. Ac~fress: ^ ServiCe ^ StratigraphiC ~- APt Nurnber. P.O. Box 196612, Anchorage, Alaska 99519-6612 50-Q29-22734-00-00 7. If perfarating, elosesE approach in p~l(s) opened by this operatit~ to nearest 8. IAIeR Name anc! Nu-nber. property line where awnership or landownership changes: MPE-14 Spacing Exception Required? ^ ye5 ~ No 9. Property Designation: 10. Field ! Poot(s): ADL 025518 & 028231 Milne Point Unit / Kuparuk River Sands : tt ; PRES~ W~~L ~Dl'EI+€~N S~UMNF~2Y : ~ ~~ ~ ~ , .;: ~ .<t , e _ , .,. ~.~ . _ ~.~~_ ~..:: , ~ ~ - _ Tofal Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft}: EffeCtive Depth ND (ft): Plugs (me3sure~: Junk (measured): 9370' 7300' 9260' 7205' 91 Q3' None C~i Le~n 3ize MQ Nt1 Burst Col Structurai Condudor 1 ' " 1 ' ' 4 SurFace 11' /" ' 4 T 7 Intermediate Production Liner 9 1' 7" ' 7277' 724 1 Perforation Depth MD (ft): Perforation Depth ND (R): Tubing Size: Tubing ~rade: Tubing MD (ft}: 9030' - 9096' 7007' - 7063' 2-7t8", 6.5# L-80 8878' Padcers and SSSV Type: 7" HES Versatrieve Packer, Padcers and SSSV 8985' / 6968' 41/2" 316L 125 Micron Poroplus Screen MD (ft) and TVD (ft): ggg5' - 9115' / 6968 - 7d80' 12. Attachments: 13. WeH Ctaas after proposeei work: ~ Description Summary of Proposal ^ BUP Sketch ~~~~~~~ ~ p~e1a~gnt ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Wetl Status after propo~ed work: Gommencing Operations: November 3, 2009 ^ Oil ^ Gas ^ WDSPL ~ G~TOR ~ Abandoned t6. Vertsal Approval: Date: ^ yry1NJ ~ GINJ ^ WAG ~ Plugged ^ SPlUG Commissian Representative: 17. 1 hereby c~rtify that the tore oing is true and ec~rrect 4a the bes4 of my knowledge. Contact gean McLau hlin 564-4387 e Printed Narne h c en l"~tle Engineering Team leader ~~ae ey w~rx,m~: ~ Signat Phane 564-4711 Date ~ ~? Qf' Yerr~ Hubble, 564-4628 Goen~nissian Eis~i f~n Gond' ns of appraval: Flotify Commissian so that a repr~sen~ative m~y witness ~undry/ Number. 3O (",/'~~~ Pl~g lntegrity LS[3c)P 7est ^ Mechar~ical Integrity 7esf ^ Loc~4ic~n Cleatance ~ 3SOQ ~S~ ,Qb I° ?~s'7~ C c)ther. 1~ 2 J`~Dc~ ~ ` ~r-- k ~ ~r ~S ~' ~ ~ ~ubsequent Fortn Required: ~ ~ ~ ~ ~ ~ APPROV~D BY ~ ~ ~ Z y APproved gy; CQMMFSStONER THE C SSWhi Dat~ Form 10-403 Revise~d b7t2000 ~~ ~~1,~ I(/~/ 5ubmtt tn ~upficsce ~ ~ ~` 4~: °~' ~-"' I ~ ~ i ~ ~ ~... r ~~, ~ ~°r m ~ IOh To: Tom Maunder • • Petroleum Engineer bp Alaska Oil & Gas Conservation Commission From: Sean McLaughlin CTD Engineer Date: October 16, 2008 Re: Milne Point E-14 Sundry Approval Sundry approval is requested to abandon perforations on well MPE-14 in preparation for a CTD sidetrack. MPE-14 is a Kuparuk C/B sand producer that is high water cut (~94%). MPE-14A will be drilled to a more optimum location. The sidetrack, MPE-14A, is scheduled to be drilled by Nordic 2 starting December 1, 2009 using the managed pressure drilling technique. This horizontal lateral will target Kuparuk B sand reserves to capture currently nonrecoverable resources. The perforations in the parent well will be abandoned with a 7" cast iron bridge plug. The "A" sidetrack lateral will exit the parent well at 8,950' md in the D shale and drill a-130' build to a TD of 9,080' md. At this point uncemented 3-3/16" drilling liner will be run to eliminate stability concerns of the D shale. A 3" lateral will then be drilled to 10,615' md. The sidetrack will be completed with a solid, cemented and perforated 2-3/8" liner. The following describes work planned. A schematic diagram of the proposed sidetrack is attached for reference. CTD Sidetrack Summarv Prior to drilling operations a workover rig will lay down the ESP completion and run a 4-1/2" workstring. After the coil drilling unit is rigged down the workover rig will return to pult the kill string and rerun the ESP completion. Nabors 4ES RWO operations: The RWO is slated to beain about November 1, 2009. 1. MIRU. Test BOPE to 3500 psi. 2. Kill Well 3. Pull 2-7/8" ESP completion 4. Perform a scraper run in the 7" csg to the top of the 7" Versatrieve packer (actually tag packer) 5. Set CIBP at 8975'. Test 7" csg integrity to 1000 psi. 6. Run 4-1/2" workstring with a Baker S-3 pkr and PBR. Ensure TT is at or above 8850' MD. 7. Set packer 8. PT the IA and tbg to 1000-psi surface pressure to ensure the seal assembly is holding and to test the casing/tubing integrity. 9. RDMO to allow Nordic II to sidetrack well Pre-CT Rig Work: The pre CTD work is slated to beQin immediatelv following the RWO. 1. Pull ball and rod 2. Pull RHC sleeve 3. Run dummy WS drift to 8975' 4. Set Baker whipstock at 8,950' 5. Extend pad with an ice apron 6. Bleed, remove, and blind flowlines 7. Drill mousehole extension Rig Sidetrack Operations: (Scheduled to begin on December 1, 2009 using Nordic rig 2) 1. MIRU Nordic Rig 2 2 NU 7-1/16" CT Drillinq BOPE and test 3. Mill 3.8" window in 7" casing from mechanical whipstock set at 8,950'. ~ 4. Drill build section with 4-1/8" bicenter bit, and land well in target B sand. 5. Flow check well and !ay in KW F as needed. 6. Run uncemented 3-3/16" drilling liner across the D shale ~~ 7. Drill lateral section to 10,615' 8. Flow check well and lay in KW F as needed. o?a~ -1~ 8 9. Run and cement a 2-3/8" L-80 liner string. Expect ~5.5 bbl of 15.8 ppg cement 10. Make a cleanout run with mill and motor. ~ 7~- ~~ s ~ 11. Make a logging run with a memo~S GR-CCL logging tool. • 12. Perforate well. 13. Circulate well to KWF brine. FP well to 2000'. 14. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 15. RDM~ Nordic 2. Nabors 4ES RWO operations: The RWO is slated to begin after the sidetrack. 1. MIRU after Nordic II finishes 2. Test BOPE to 3500 psi. 3. Shear PBR and pull 4-1/2" workstring 4. run new ESP on 2-7/8" tubing to above 8700' 5. RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. Sean McLaughlin CTD Engineer CC: Well File Sondra StewmanlTerrie Hubble Tree: Cameron 2 9/16" 5A]I~ Wellhead: 11" x 7 1/16" 5M FMC Gen 5A, w/ 2 7/8" FMC tbg. hng., 3" LH acme on top and 2 7/8" EUE 8 rd on bottom, 2.5" CIW BPV profile 20" 91.1 ppf, H-40 112' KOP @ 900' Max. hole angle = 52 deg. @ 5953 Hole angle thru' perFs => 31 deg. Max. DLS = 4.8 @ 5431' 9 5/8", 40 ppf, L-80 Btrc. 5'4'~' MPU E-14 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, NSCC production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) Stimulation Summarv None performed Perforation Summarv short joints 8852'-8894' Ref log: GR/CCL 04/16/97 Size Spf MD ND u . ' 4.5" 5 9030'-9060' (6998'-7024') K .`B' 4.5" 5 9066'-9096' 7029'-7055') 37 gm. HyperJet II charges (EHD = 0.46", TTP = 34.58") 5 JSPF Q 60 deg. phasing onrE I~v. av I connnne-~rs 9-15-97 Mpp 2nd ESP Completion 4ES 7-19-96 MDO ESP CompletioMScreen Added 5 S 03-21-00 M. Li~er RW04ES &28-08 lH RWO with 3S Orig. K~v. = 57.60' (N 27E) Orig. GL Elev. = 24.T RT To Tbg. Spool = 33.5' (N 27E) Camco 2 7/8" x 1" 139, sidepocket KBMM GLM Camco 2 7/8" x 1" sidepocket KBMM GLM 8670' 2-7/8" XN Nipple ( 2.205" ) 8813' Centrilift 74-P23 ESP, 8829~ PMSXD 1:7 538 Gas Separator ~RSFrw-RHS 8840' Intake ND = 6845` Tandem Seal Section 8845~ 152 hp, 2152 volt, 31 amp PumpMate XTO Sensor w/ 8873. 6 fin centralizer PumpMate ND = 6873' GS83 DB FER HL SSCV H6 SB/SB PFSA Motor Rerated to KMH-A gg59' 7" HES Versatrieve Pkr. 8985' 4.5" 316L 125 Micron g031' Poroplus screen 11.6# LTC 4.5" HES XN-Nipple (2.750" id) g103' ( W/ Plug ) WLEG 9115' 7" float collar (PBTD) 92~' ~ 7" float shoe 9~~ AAILNE POINT UNIT Well No : E-14 API : 50-029-22734 BP EXPLORATION (AK) . . Proposed ; ~gg: Cameron 2 9/16" 5M - Nelihead: 11" x 7 1/16" 5M FMC 3en 5A, w/ 2 7/8" FMC tbg. hng., 3" _H acme on top and 2 7/8" EUE 8 rd ~n bottom, 2.5" CIW BPV profile 20" 91.1 ppf, H-40 112' KOP (a~ 900' Max. hole angle = 52 deg. @ 5953 Hole angle thru' perfs => 31 deg. Max. DLS = 4.8 ~ 5431' 9 5/8", 40 ppf, L-80 Btrc. 5~~ 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, NSCC production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) Camco 2 7/8" x 1" 139' sidepocket KBMM GLM 4-1/2" Workstring to be puiled for ESP completion post CTD Camco 2 7/8" x 1" sidepocket KBMM GLM 8670' 2-7/8" XN Nipple ( 2.205° ) 8813' Centrilift 74-P23 ESP, g829~ PMSXD 1:7 538 Gas Separator~RSFrxARHS 8840' Intake ND = 6845' Tandem Seal Section 8845' GS63 DB FER HL SSCV H6 SB/SB PFSA Stimulation Summarv None performed Baker 20' PBR Above Packer @8730` Baker 7" x 4-1/2" S-3 L-80 Packer (Ta Remain in the Hole post W/O)_ ~-8, 750' 4-1/2" TTail with WLEG cQ 3-3/16" Solid Liner ITD= 2-318" Solid/CmYd Liner DATE REV.BY )4-12-97 M ~~pg_g7 MDO 9-1597 MDO 7-19-96 MDo 03-21-00 M. Linder 6-28-OS LH rPU E-14A Laterai B7 Sand CTD Sidetrack Orig. KB Elev. = 57.60' (N 27E) Orig. Gl Elev. = 24.7' RT To Tbg. Spool = 33.5' (N 27E) COMMENTS 2nd ESP Completion 4-ES ESP CompletionlScreen Added 5 S RWO 4-ES RWO with 3S Motor Rerated to KMH-A gg59' 152 hp, 2152 volt, 31 amp PumpMate XTO Sensor w/ 8873~ 6 fin centralizer Pum~Aate ND = 6873' -Liner top packer -XNIP3.813"ID@8820' Baker 4-1/2" x 7" Whipstock @ 8,950' ~7" CIBP ~ 8975' ~ 7' HES Versatrieve Pkr. 8985' 4.5" 316L 125 Micron 9031' Poroplus screen 11.6# LTC 4.5" HES XN-Nipple (2.750° id 9103' ( W/ PIu9 ) WLEG 9115' 7" float collar (PBTD) 9260' ! 7" float shoe ~~ MILNE POINT UNIT Well No : E-14 API : 50-029-22734 BP EXPLORATION (AK) STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~SION REPORT O'F SUNDRY WELL OPERATIONS ~~~ iii; w 1. Operations Performed: - ^Abandon ®Repair Well ^ Plug Perforations ^ Stimulate 1~ ~%~~i~a(~?~-er ~,~per~ded Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Oth~"~ -~ Change Out E'SP ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 197-005 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22734-00-00 7. KB Elevation (ft): 57.60 9• Well Name and Number: MPE-14 8. Property Designation: 10. Field /Pool(s): ADL 028231 ~ Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 9370 ' feet true vertical 7300 ' feet Plugs (measured) 9103' Effective depth: measured 9260 feet Junk (measured) None true vertical 7205 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1490 470 Surface 5511' 9-5/8" 5543' 4587' 5750 3090 Intermediate Production Liner 9319' 7" 9344' 7277' 7240 5410 5~~tl~l~~ AUG ~ ~ 2008 Perforation Depth MD (ft): 9030' - 9096' Perforation Depth TVD (ft): 7007' - 7063' 2-7/8", 6.5# L-80 8878' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" HES Versatrieve Packer, 8985' 4-1/2" 316E 125 Micron Poroplus Screen 8985' - 9115' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: , ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil' ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact Mackie Derrick, 564-5891 NIA Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: ignatur Phone 5 4-47 0 Form 10-404 Revised 04/2006 ( ~ ~ ~ (.., ~ ~ ~ t Date - -(~ ondra Stewman, 564-4750 ~~ 3 C+ ~~,'~ AUr ~ ~ ~S~bmit Original Only /'~ 7 ~ /P'. a8 • • Tree: Cameron 2 9/16" 5M Wellhead: 11" x 7 1/16" 5M FMC Gen 5A, w/ 2 7/8" FMC tbg. hng., 3" LH acme on top and 2 7/8" EUE 8 rd on bottom, 2.5" CIW BPV profile 20" 91.1 ppf, H-40 112' MPU E-14 KOP @ 900' Max. hole angle = 52 deg. @ 5953 Hole angle thru' perfs = > 31 deg. Max. DLS = 4.8 @ 5431' 9 5/8", 40 ppf, L-80 Btrc. 5543' 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, NSCC production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) Stimulation Summary None performed Perforation Summary Ref log: GR/CCL 04/16/97 Size Spf MD TVD Ku . `C' 4.5" 5 9030'-9060' (6998'-7024') K .`B' 4.5" 5 9066'-9096' 7029'-7055') 37 gm. HyperJet II charges (EHD = 0.46", TTP = 34.58") 5 JSPF @ 60 deg. phasing short joints 8852'-8894' DATE REV. BY COMMENTS )q-12-97 i5-08-97 MDO MDO 7" Cased hole Completion 271 ESP Com letion 4-ES 9-15-97 Mp0 2nd ESP Completion 4-ES 7-19-96 MDO ESP Completion/Screen Added 5 S 03-21-00 M. Linder RW04-ES 6-28-08 LH RWO with 3S Orig. KB Elev. = 57.60' (N 27E) Orig. GL Elev. = 24.7' RT To Tbg. Spool = 33.5' (N 27E) Camco 2 7/8" x 1" 139' sidepocket KBMM GLM Camco 2 7/8" x 1" I sidepocket KBMM GLM 8670' 2-7/8" XN Nipple (2.205") 8813' Centrilift 74-P23 ESP, 8829 PMSXD 1:7 538 GaS Separator GRSFTXARH6 $840' Intake TVD = 6845' Tandem Seal Section 8845' GSB3 DB FER HL SSCV H6 SB/SB PFSA Motor Rerated to KMH-A 8859' 152 hp, 2152 volt, 31 amp PumpMate XTO Sensor w/ 8873' 6 fin centralizer PumpMate TVD = 6873' 7" HES Versatrieve Pkr. 8985' 4.5" 316E 125 Micron 9031' I Poroplus screen 11.6# LTC 4.5" HES XN-Nipple (2.750" id) g103' ( W/ Plug ) WLEG 9115' .E~o .~.,~.,.a,o, o 7" float collar (PBTD) 9260' ~,.~ o ~ 7" float shoe 9344' MILNE POINT UNIT Well No : E-14 API : 50-029-22734 BP EXPLORATION (AK) • • BP EXPLORATION Operations Summary Report Page 1 of 3 Legal Well Name: MPE-14 Common W ell Name: MPE-14 Spud Date: Event Nam e: WORKO VER Start : 6/24/2008 End: Contractor Name: NABOR S ALAS KA DRI LLING I Rig Release: 6/28/2008 Rig Name: NABOR S 3S Rig Number: Date From - To Hours Task I, Code NPT Phase Description of Operations 6/24/2008 12:00 - 13:00 1.00 RIGD P PRE Rig down from MPE-19, blow down steam and water lines, scope down and lay down Derrick on to Carrier. R/D mud pits and pipe shed. 13:00 - 18:00 5.00 MOB P PRE Move Carrier, Pits and Pipe shed from MPE-19 to MPE-14. 18:00 - 22:00 4.00 MOB P PRE Spot carrier over Well, witnessed by BP/1IVSL, Nabors Toolpusher and MP/Pad operator. Lay herculite and spot Pits and Pipe shed. 22:00 - 00:00 2.00 RIGU P PRE Raise and scope up Derrick, R/U lines. 6/25/2008 00:00 - 01:00 1.00 RIGU P PRE Continue rig up lines, hand rails and landings. 01:00 - 06:00 5.00 RIGU P DECOMP Ri acce ted at 01:00 hrs 6/25/2008. PJSM, Install second annulas valve, make up hard lines to Tree and take on hot seawater into Pits. Tested hard line to Tiger Tank to 500 psi. Kill line to Tree to 3,500 psi. Tested good. 06:00 - 06:30 0.50 WHSUR P DECOMP Pre-tour checks and service the Rig. 06:30 - 07:30 1.00 WHSUR P DECOMP RU Lubricator with Well Su ort Techs and ressure test to 500 psi with di el -good. Pull 2-1/2" Type "H" BPV and nnta the WHP's: Tbg = 880 psi . IA = 1150 osi , OA = 0 psi. RD Lubricator. 07:30 - 08:00 0.50 KILL P DECOMP Pre-kill safety meeting with the crew. 08:00 - 08:30 0.50 KILL P DECOMP Vent gas pressure off the IA to the Tiger Tank from 1,090 psi down to 300 psi. 08:30 - 09:00 0.50 KILL P DECOMP Starting Tbg pressure = 550 psi ,starting IA pressure = 480 psi. Break circulation with seawater down the Tubing taking returns through the Choke to the Tiger Tank. Pump at a rate of 3 bpm / 980 psi on the Tubing with 610 psi on the IA. Pump a total of 60 bbls and close the Choke. 09:00 - 09:30 0.50 KILL P DECOMP Bullhead a tubing volume of 50 bbls down the Tubing into the formation at a rate of 3 bpm / 960 psi with 880 psi on the IA. 09:30 - 10:30 1.00 KILL P DECOMP Shut down the um and monitor the well for 1 hour to calculate kill wei ht brine needed. SITP after 1 hour stabilized at 290 psi. Calculate kill weight to be 9.4 ppg brine with a 75 psi overbalance. SICP after 1 hour at 720 psi. Order out 580 bbls of 9.4 ppg brine. 10:30 - 13:00 2.50 KILL P DECOMP Open the well and resume circulation with seawater down the Tubing taking returns to the Tiger Tank. Pumping at a rate of 3 bpm / 750 psi with 650 psi on the IA. Getting thick crude and gas returns to surface. Pumped a total of 336 bbls to get clean returns. Weight of returns = 8.3 ppg. Shut down and shut the well in until kill weight brine arrives on location. 13:00 - 00:00 11.00 KILL N DECOMP Wait on 9.4 ppg brine to arrive on location. Clean and maintain the Rig. RU Sheave and Elephant Trunk while waiting on brine. 6/26/2008 00:00 - 00:30 0.50 KILL N DECOMP Continue to wait on second load of 9.4 ppg brine for Well Kill. Truck broke down twice on the way to location. 00:30 - 06:00 5.50 KILL P DECOMP Circulate 114 bbls of 8.4 PPG seawater at 3 BPM / 640 psi down the tubing taking returns to the Tiger Tank, followed by 60 bbls of heated 9.4 ppg brine at 3 BPM. Close in returns and Bullhead 50 bbls 9.4 ppg heated brine at 2 BPM / 490 psi. WHP after 15 minutes was Tubing = 0, IA = 140 psi. Circulate 290 bbls heated 9.4 ppg brine at 3 BPM / 550 psi the long way until returns are clean with 9.3+ ppg brine on surface. Shut down and monitor the well. Tubing and IA on vac. Blow down Printed: 7/7/2008 11:50:07 AM • BP EXPLORATION Operations Summary Report Legal Well Name: MPE-14 Common Well Name: MPE-14 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 3S Date From - To ,Hours Task Code ~'I NPT i 6/26/2008 06:00 - 07:00 07:00 - 07:30 07:30 - 08:00 08:00 - 10:00 10:00 - 15:30 15:30 - 16:00 16:00 - 22:00 22:00 - 23:00 23:00 - 00:00 6/27/2008 00:00 - 00:30 00:30 - 01:30 01:30 - 03:00 03:00 - 05:00 05:00 - 10:00 10:00 - 11:00 11:00 - 17:00 17:00 - 20:30 20:30 - 22:00 22:00 - 00:00 1.00 KILL P 0.50 WHSUR P 0.50 WHSUR P Start: 6/24/2008 Rig Release: 6/28/2008 Rig Number: Phase DECOMP Pre-tour checks. RD circulating lines. DECOMP PU T-bar and set 2" T e "H" TWC w DECOMP Pressure test the TWC from above to ruins - vn. 2.00 WHSUR P DECOMP ND Tree and Adapter Flange. Check 3" LH Acme Hanger threads with FMC rep -good threads. Screw on XO with 8-1/2 turns. Gravity feed the well with approximately 5 bbls per hour. 5.50 BOPSU P DECOMP PJSM. PU BOPE off of Cradle and NU 13-5/8" 5M BOPE. Continue gravity feeding the IA with 10-15 bbls per hour. 0.50 BOPSU P DECOMP Function test BOPE and get RKB measurements. 6.00 BOPSU P DECOMP Pressure test BOPE to 250 si low and 3 500 si hi h er B AOGCC Regulations. The Rams were tested with 2-7/8" Test Joint. The Annular was tested to 3,500 psi. The test was witnessed by the BP WSLs, Toolpushers and AOGCC Representative Chuck Scheve. 1.00 BOPSU P DECOMP R/D test equipment, drain BOPE and blow down lines. 1.00 WHSUR P DECOMP PJSM P/U Opso Lopso and torque XO, MU and tested lubricator to 500 psi, good test. Well support techs pulled TWC. 0.50 WHSUR P DECOMP R/D lubricator and Opso Lopso. 1.00 PULL P DECOMP M/U landing joint, FMC tech BOLDS and pull hanger free, PUW = 75K. 1.50 PULL P DECOMP Circulate the long way at 3 BPM / 570 psi, pumped 300 bbls 9.4 ppg brine. Lost 48 bbls during circulation. Pumps off losses -10 BPH. 2.00 PULL P DECOMP RU to pull ESP. 5.00 PULL P DECOMP POH with 2-7/8" tubin ESP com letion standing back in Derrick. Maintaining 15 bbls per hour fill rate while POOH. Stop at 10:00 hrs due to Little Red needing to freeze protect MPE-15 for the Milne Point shutdown. 54 stands (108 Joints) out of the hole. Stab TIW valve and continue filling the hole while shut down. 1.00 PULL P DECOMP Clear and clean Rig Floor. Work on oily waste. 6.00 PULL P DECOMP Resume POOH with existing 2-7/8" ESP Completion standing back in the Derrick. Maintain 15 bbl /hour fill rate with 9.4 ppg brine while POOH. 100 stands out at 14:00 hrs. Total = 139 stands (278 joints) in Derrick and 1 joint in pipe shed, 5 bad joints changed out, recovered 149 Lasalle clamps, 5 Protectalizers, 3 Flat guards. 3.50 PULL P DECOMP BOLD ESP pump and motor assembly. Electrical failure. at the 1.50 2.00 6/28/2008 100:00 - 08:30 I 8.50 RUNCMP R/D containment trunk and return to storage box. Run rope for pulling ESP cable through sheave in Derrick. Clean and clear Rig floor, change out spool in spooling unit, Milne point PE's dress GLM's. RUNCMP PU/MU ESP pump and motor assembly, pull ESP cable over sheave, Centrilift techs perform conductivity checks. RUNCMP PJSM with Centrilift. _Run ESP completion on 2-7/8" Arrl Fl iF. 6.5#, L-80 Tubing from Derrick. Check conductivity of ESP cable every 2,000' and flush pump with 10 bbls of 9.4 ppg brine. Using Best-O-Life 2000 pipe dope. Optimum make up torque is 2,300 ft-Ib. Feed wellbore continually with 9.4 ppg brine at -15 BPH with no returns. Flushed pump at a rate of 1 Spud Date: End: Page 2 of 3 ~ Description of Operations Printed: 7/7/2008 11:50:07 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: MPE-14 Common Well Name: MPE-14 Spud Date: Event Name: WORKOVER Start: 6/24/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/28/2008 Rig Name: NABOBS 3S Rig Number: Date I From - To I Hours Task Code NPT 6/28/2008 100:00 - 08:30 8.501 BUNCO 08:30 - 10:30 I 2.001 BUNCO 10:30 - 13:00 I 2.501 RUN 13:00-14:00 ~ 1.OO~WHSUR~P 14:00 - 15:30 1.50 RUN 15:30 - 16:00 0.50 RUN Page3of3~ Phase Description of Operations RUNCMP BPM / 570 psi. Ran 80 stands at 05:30 hrs. Stop with 123 stands in the hole at 08:30 hrs. RUNCMP Perform reel to reel splice with Centrilift reps. Monitor and fill the well with 9.4 ppq brine each hour and obtain s a is oss _ rates of 13 and 10 bbls per hour. Watched all 8 Golden Rules of Safety video with the crew while waiting on completion of the splice. RUNCMP Resume RIH with 2-7/8" ESP Completion from the Derrick. Ran a total of 279 Joints of 2-7/8", 6.5#, L-80, EUE 8rd Tubing. Ran an additional 6' pup joint beneath the Hanger pup joint for anchoring the ESP cable. Ran a total of 147 LaSalle Clamps, 5 Protectolizers and 3 Flat Guards. RUNCMP Pick up and make up Landing Joint with 3" LH Acme XO to the Tubing Hanger and orient the Hanger with FMC rep. Install Penetrator and shipping cap. Fill the Tubing and flush the ESP with 10 bbls of 9.4 ppg brine at a rate of 1 bpm / 700 psi. RUNCMP Cut the ESP Cable and perform field connection splice with Centrilift rep. RUNCMP Obtain final PUW = 70K ,SOW = 45K. Land Hanaer and 16:00 - 17:00 1.00 WHSUR P 17:00 - 19:30 2.50 BOPSU P 19:30 - 21:30 2.00 WHSUR P 21:30-22:30 ~ 1.OO~WHSUR~P 22:30 - 23:00 I 0.501 WHSUR I P RUNCMP RUNCMP Drain BOPE and blow down lines, LOTO accumulator , ND BOPE, riser, second annulus valve, koomey lines and DSA flange. Lay BOP down in shipping cradle. RUNCMP NU Tree and Adapter Flange, FMC Tech tested hanger void to 5,000 psi for 30 minutes. Good test. Test Tree with diesel to 5,000 psi for 10 minutes. Good test. RUNCMP PU lubricator and test to 500 psi, Well Support Techs pulled TWC and installed 2" Type "H" BPV. LD lubricator. RUNCMP Normal-up Tree and secure cellar. Centrifilt rep took final ESP checks: ESP cable phase to phase = 4.0 ohms, ESP cable phase to ground = 716 Mega-ohms, Pressure at intake = 3,285 psi, Motor temp = 152 deg, intake temp = 153 deg, . The Rig Printed: 7/7/2008 11:50:07 AM '~ STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION BOPS Test Report Submit to: Contractor: Nabors Rig No.: 3S Rig Rep.: J. Henson / J. Fritts Rig Phone: 659-4487 Operator: Bp Op. Phone: 659-4485 Rep.: W. Hoffman/D.Rhodes Field/Unit & Well No.: MP E-14 PTD # 197Q050 Operation: Drag: Test: Initial: x Test Pressure: Rams: 250/3500 MISC. INSPECTIONS: Test Result Location Gen.: P Wei Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: DATE: 6/26/2008 Rig Fax: 659-4486 Op. Fax: 659-4628 Workover: x Weekly: Annular.250l3500 Explor.: Bi-Weekly Valves: 250/3500 TEST DATA FLOOR SAFETY VALVES: Test Result Quantity Test Result P Upper Kelly 0 NA P Lower Kelly 0 NA P BaN Type 1 P Inside BOP 1 P Quantity Size Test Result Annular Preventer 1 13 5/8 5000 P Pipe Rams 1 2 7/8 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind P Choke Ln. Valves 1 31/8" 5000 P HCR Valves 2 3 1/8" 5000 P Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 FP Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3050 P Pressure After Closure 1700 P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 30sec P Trip Tank P P Full Pressure Attained 2 min 50 sec P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): 1975 Meth Gas Detector P P H2S Gas Detector P P ' ~ Test Results Number of Failures: ~~ ~ Test Time: 7 Hours Components tested ALL Repair or replacement of equipment wiN be made witiun days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: Remarks: Tested with 2 7/8" test ioint. Manual kill valve leaked. Grease all valves and retest -test actainst Two Wav Check valve (TWC ) 24 HOUR NOTICE YES x NO Date 06/24/08 Time 1945 hrs Test start 1500 hrs Firtish 2200 hrs BOP Test (for rigs) ~UN ~~, ~ 2~~~ BFL 11/14/07 By Witness Fritts/RhodeslSheve Nabors 3s BOP Test MP E-14 6-26-08.x1s THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03, 2 001 P L M A T T H E IA L U N D IS M ARK Et< W C:LoRBMFR'M.DOC . STATE OF ALASKA ALASF._ _ OIL AND GAS CONSERVATION COM,,..,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP ,,, 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 57.60' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3590' NSL, 1918' WEL, SEC. 25, T13N, R10E, UM MPE-14 At top of productive interval 9. Permit Number / Approval No. 197-005 567' SNL, 247' EWL, SEC. 31, T13N, R11E, UM 10. APl Number At effective depth 50-029-22734-00 654' SNL, 334' EWL, SEC. 31, T13N, R11 E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 692' SNL, 373' EWL, SEC. 31, T13N, R11E, UM Sands 12. Present well condition summary Total depth: measured 9370 feet Plugs (measured) true vertical 7300 feet Effective depth: measured 9260 feet Junk (measured) true vertical 7205 feet Casing Length Size Cemented M D TVD Structural Conductor 112' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 5511' 9-5/8" 1750 sx PF 'E', 300 sx 'G', 89 sx PF 'C' 5543' 4587' Intermediate Production 9319' 7" 250 sx Class 'G' 9344' 7277' Liner Perforation depth: measured 9030'- 9060', 9066'- 9096' true vertical 7007'- 7033', 7038'- 7064' MAR 2 4 2000 Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 8874'; .-'.~JaSk8 0ii & ~r~, L;~n$. %'~ i .~ 4-1/2", 316L 125 Micron Poroplus Screen 11.6# LTC, 8985'- 9115 Packers and SSSV (type and measured depth) 7" HES Versatrieve packer at 8985' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressureORIGINAL 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status'of Well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the fore, going is true and correct to the best of my knowledge Signed TerdeHubble ,,~¢j~~.v~'~- ~ ~ Title TechnicalAssistant III Date 0~' : :~ Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate"' Facility Date/Time 18 Mar 00 19 Mar 00 20 Mar 00 Progress Report M Pt E Pad Well MPE-14 Page 1 Rig Nabors 4ES Date 23 March 00 03:00-06:00 03:00-06:00 06:00 06:00-11:00 06:00-11:00 11:00 11:00-14:00 11:00-14:00 14:00 14:00-17:00 14:00-17:00 17:00 17:00-21:00 17:00-21:00 21:00 21:00-23:00 21:00-23:00 23:00 23:00-00:30 23:00-00:30 00:30 00:30-03:30 00:30-03:30 03:30 03:30-04:30 03:30-04:30 04:30 04:30-06:00 04:30-06:00 06:00 06:00-14:30 06:00-14:30 14:30 14:30-03:00 14:30-15:30 15:30 15:30-21:00 21:00 21:00-00:00 00:00 Duration 3hr 3hr 5hr 5hr 3hr 3 hr 3hr 3hr 4hr 4hr 2hr 2hr 1-1/2 hr 1-1/2 hr 3hr 3hr lhr lhr 1-1/2 hr 1-1/2 hr 8-1/2 hr 8-1/2 hr 12-1/2 hr lhr 5-1/2 hr 3hr Activity Move rig Rig moved 50.00 % Rig off station Move rig (cont...) Rig moved 100.00 % MI & RU & Safe out equipment. At well location - Slot Fluid system Fill pits with Seawater Take o n sea water & wt. up to 8.6+ & rig lines to tiger tank & tree. Completed operations Wellhead work Removed Hanger plug Remove bpv & rig up hard lines to tree & test same to 3000 psi. & hold PJSM. Equipment work completed Well control Circulated closed in well at 8780.0 ft circ. influx from well with 8.6 ppg. sea h20 & shut in & tbg=160 psi. wt. up to 8.9 & kill well. monitor well static. Influx Out of hole Wellhead work Removed Xmas tree set twc & test to 2500 psi. & remove tree. Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi Wellhead work Removed Hanger plug Equipment work completed Wellhead work Retrieved Tubing hanger MU landing it. & pull hanger to floor & rig up to pull completion. Equipment work completed Pull Single completion, 2-7/8in O.D. Pulled Tubing in stands to 8899.0 ft pooh & lay dn esp assy. Completed operations Run Single completion, 2-7/8in O.D. Rigged up Tubing handling equipment Equipment work completed Ran Tubing in stands to 4854.0 ft MU ESP Completion & run in hole with same. Stopped: To splice cable Serviced ESP make mid-line splice Equipment work completed Facility Date/Time Progress Report M Pt E Pad Well MPE- 14 Page 2 Rig Nabors 4ES Date 23 March 00 00:00-03:00 03:00 03:00-06:00 03:00-06:00 06:00 06:00-07:00 06:00-07:00 07:00 07:00-06:00 07:00-08:00 08:00 08:00-09:00 09:00 Duration 3hr 3hr 3hr lhr lhr 23 hr lhr lhr Activity Ran Tubing in stands to 8873.0 ft dh & mu tbg. hanger. & landing jt. Completed run with ESP to 8873.0 ft Wellhead work Installed Tubing hanger MU lower eft connector @ hanger & land same & rilds & set twc & test to 2500 psi. & lay dn landing jr. Equipment work completed Nipple down BOP stack Rigged down BOP stack Equipment work completed Wellhead work Installed Xmas tree Test Tree to 5000 Psi. Equipment work completed Installed Hanger plug Remove TWC & Set Bpv & Secure Tree ARea. & Rig Released for rig move to WOA D-12 Equipment work completed PERMIT DATA T DATA PLUS AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 05/24/99 RD-N RECVD 97-005 7686 ~SCHLUM PDC/SR/CCL 97-OO5 DSR/EW~4-MD ~/300-9~?0 97-005 DG~/O~P/SLD-MD ~/~00-9~70 97-0O5 DG~/C~/S~D-TV~ ~'22~-7~00 97-0O5 DS~/EWR4-TW ~22~-7~00 97-0O5 7696 ~r%~ER~Y SRC/C~/~T/EWR4 ~-oo~ ~ s~ ~~ o-~o ~-oos ~ ~w ~.~s~ ~-~o FIN~KL 04/25/97 FINAL 05/1~/97 1 05/16/97 FINAL 05/21/97 FINAL 05/21/97 FINAL 05/21/97 FINAL 05/21/97 1-2,4 05/21/97 08/29/97 08/29/97 10-407 ~/COMPLETION DATE @ ..~';,~' DAILY WELL ePS R'@ ~/3/ /~['~/ TO /2,~-~/ ~[ Are dry ditch samples required? yes /no~ Amd received? Was the well cored? yes ~ _~nalysis & description received? Are well tests required? yes ~ Received? yes ..... Well is in compliance . Initial COMMENTS @ yes T D BOX -- STATE OF ALASKA ALASKA 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 ESP Replacement 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3590' NSL, 1918' WEL, SEC. 25, T13N, R10E At top of productive interval 577' SNL, 235' EWL, SEC. 31, T13N, R11E At effective depth 654' SNL, 335' EWL, SEC. 31, T13N, R11E At total depth 704' SNL, 359' EWL, SEC. 31, T13N, R11E 5. Type o,.~f welh ~.Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) RTE = 57.7' 7. Unit or Property Name Milne Point Unit 8. Well Number MPE-14 9. Permit Number / Approval No. 97-05 10. APl Number 50- 029-22734 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 9370 feet true vertical 7300 feet Effective depth: measured 9260 feet true vertical 7205 feet Casing Length Size Structural Conductor 87' 20" Surface Intermediate 5518' 9 5/8" Production Liner 9319' 7" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset 1 (Approx) 1750 sx PF 'E', 300 sx Class 'G' 89 sx PF 'C' 250 sx Class 'G' MD TVD 112' 112' 5543' 4588' 9344' 7278' Perforation depth: measured true vertical 9030'-9060',9066'-9096' (Subsea) 6949'-6975',6980'-7006' Tubing (size, grade, and measured depth) 2 7/8" L-80 Rd EUE to 8889' Packers and SSSV (type and measured depth) RECEIVED AUG 19 ~998 Anchorage 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 OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments E~ Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 7. I hereby certify that the foregoing is true amd correct to the best of my knowledge Signed :-. . /_.. ,. __~*./_¢_.~' Title Staff Technical Assistant Date Jeanne L. Haas, 564-5225 Prepared By Name/Number: Facility Date/Time 14 Jul 98 15 Jul 98 16 Jul 98 17 Jul 98 18 Jul 98 19 Jul 98 Progress Report M Pt E Pad Well MPE-14 Page 1 Rig t/?~qj2o£~, ~.o~-_CC' Date 06 August 98 09:00-18:00 18:00-20:00 20:00-06:00 06:00-11:00 11:00-13:00 13:00-13:30 13:30-17:30 17:30-18:00 18:00-18:30 18:30-19:00 19:00-21:00 21:00-00:00 00:00-02:30 02:30-03:30 03:30-06:00 06:00-13:30 13:30-15:00 15:00-18:00 18:00-01:00 01:00-06:00 06:00-06:30 06:30-12:00 12:00-13:00 13:00-15:00 15:00-18:00 18:00-22:00 22:00-23:30 23:30-05:00 05:00-06:00 06:00-09:00 09:00-12:00 12:00-15:00 15:00-18:00 18:00-22:00 22:00-23:00 23:00-02:00 02:00-04:00 04:00-05:00 05:00-06:00 06:00-10:00 Duration 9hr 2hr 10hr 5hr 2hr 1/2 hr 4hr 1/2 hr 1/2 hr 1/2 hr 2hr 3hr 2-1/2 hr lhr 2-1/2 hr 7-1/2 hr 1-1/2 hr 3hr 7 hr 5hr 1/2 hr 5-1/2 hr lhr 2hr 3hr 4hr 1-1/2 hr 5-1/2 hr lhr 3hr 3hr 3hr 3hr 4hr lhr 3hr 2hr lhr lhr 4hr Activity Rigged down Crown block Rigged down Crown block Rig moved 100.00 % Rigged up Draw works Tested High pressure lines Removed Hanger plug Circulated at 8824.0 ft Installed Hanger plug Tested Hanger plug Removed Xmas tree Rigged up All rams Tested All rams Removed Tubing hanger Pulled Tubing in stands to 0.0 ft Pulled Tubing in stands to 1890.0 fl Pulled Tubing in stands to 8832.0 ft Retrieved ESP Conducted slickline operations on Slickline equipment - Tool run Ran Tubing in stands to 9163.0 ft Circulated at 9252.0 ft Reverse circulated at 9252.0 ft Pulled Tubing in stands to 9252.0 ft Ran Tubing to 0.0 fl (2-7/8in OD) Ran Tubing to 0.0 ft (2-7/8in OD) Ran Tubing in stands to 3000.0 ft Ran Tubing in stands to 8984.0 ft Set Production packer at 8984.0 ft with 2500.0 psi Pulled Tubing in stands to 8984.0 ft Rigged up sub-surface equipment - ESP Rigged up sub-surface equipment - ESP Ran Tubing in stands to 4100.0 ft Ran Tubing in stands to 4100.0 ft Ran Tubing in stands to 4800.0 ft Ran Tubing in stands to 8899.0 ft Installed Tubing hanger Installed Tubing hanger Removed BOP stack Installed Xmas tree Tested Xmas tree Installed Hanger plug STATE OF ALASKA ALASKa-, OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [~ Pull Tubing [--~AIterCasing [~] Repair Well []Other ESPExchange 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3590' NSL, 1918' WEL, Sec. 25, T13N, R10E, UM At top of productive interval 568' SNL, 248' EWL, Sec. 36, T13N, R10E, UM At effective depth 654' SNL, 335' EWL, Sec. 36, T13N, R10E, UM At total depth 684' SNL, 365' EWL, Sec. 36, T13N, R10E, UM 5. Type of well: ~Development [] Exploratory [] Stratigraphic [~ Service 16. Datum Elevation (DF or KBE) KBE: 58' 7. Unit or Property Name Milne Point Unit 8. Well Number MPE-14 9. Permit Number / Approval No. 97-05 10. APl Number 50- 029-22734 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 9344' feet true vertical 7277' feet Effective depth: measured 9260' feet true vertical 7205' feet Casing Length Structural Conductor Surface Intermediate Production Liner Size 112' 20" 5511' 9 5/8" 9319' 7" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (approx) 1750 sx PF 'E', 300 sx Class 'G', 89 sx PF 'C' 250 sx Class 'G' MD TVD 112' 112' 5543' 4587' 9344' 7277' Perforation depth: measured 9030'-9060', 9066'-9096' true vertical 7007'-7033',7038'-7064' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 8887' Packers and SSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [~Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip Alvord ~ ~' ~ Title Engineering Supervisor Date Prepared By Name/Number: Mary¥oungerSsubmit564-52421n DuplicaJ.~ Form 10-404 Rev. 06/15/88 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX/ARCO WeLl Name: MPE-14 Rig Name: N-4ES AFE# 339062 Accept Date: 09/13/97 Spud Date: . Release Date: 09/15/97 SEPTEMBER 13, 1997 RIG ACCEPTED @ 0000 HRS. MOVE RIG FROM MPF-33 TO E-14 RIG UP & BERM, LEVEL & SAFE OUT EQUIPMENT. RIG LINES TO TREE SET TIGER TANK PULL BPV - TAKE ON 9.1 PPG BRINE TEST LINES TO 2000 PSI. SEPTEMBER 14, 1997 TUBING 400 PSI ANNULUS 510 PSI DISPLACE WELL BORE FLUIDS W/9.0 PPG BRINE. REPAIR ELECTRIC PROBLEM TO PUMP & REPAIR SAME. CONT TO REPLACE WELL BORE FLUIDS W/9.0 PPG NACL & MONITOR WELL FLOWING TUBING & ANNULUS. RAISE WT TO 9.2 PPG & PUMP BAHA FIBER PILL 15 BBL & SPOT. SET TWC & ND TREE & NU BOP'S. TEST BOP'S 250 LOW & 5000 HIGH (NO RETURN CALL FROM AOGCC) MU LANDING JT. & PULL HANGER TO FLOOR & CHECK LD SAME POOH W/ESP COMPLETION. SEPTEMBER 15, 1997 CONT TO POOH W/ESP COMPLETION & LD SAME (FOUND SCALE ON PUMP & MTR ASSY TUBING FREE OF SCALE) RIG HES & RIH W/SWEDGE & TAG TD @ 9183' (WLM) POOH & RIG DN HES MU ESP ASSY & RIH W/SAME. SPOOL TO SPOOL SPLICE. CONT TO RIH & MU HANGER, SPLICE PIGTAIL & TEST, LAND TUBING & RILDS ND BOP & NU PRODUCTION TREE. SEPTEMBER 16, 1997 NU PROD TREE & TEST TO 5000 PSI. PULL TWC SET BPV RU HARDLINE TO TREE & TEST TO 3000 PSI & FREEZE PROTECT WELL W/DIESEL. RD LINES & FLUSH SYSTEM & CLEAN CELLAR & SECURE WELL. RIG RELEASED @ 1200 HRS 09/15/97. Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well I~] Oil I~1 Gas I~l Suspended I~ Abandoned i--I Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-05 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22734 4. Location of well at surface ~ ...... ~ 9. Unit or Lease Name 3590' NSL, 1918' WEb, SEC. 25, T13N R10E i ,.?(}::i., ?/::.~:..~._.-~!~ Milne Point Unit ' ~, "~ ~[. ~.;.~ At top of productive interval 10. Well Number 577 SNL, 235' EWL, SEC. 31, T13N, R11E : ._<~_?.~ / MPE-14 At total depth / '-~-~,~/F¢~ii f~!i& ~ ~ 11 . Field and Pool 704' SNL, 359' EWL, SEC. 31, T13N, R11E ¢ .~:T~.~_. i Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Le~."~*~-~-~rfa~ion and Serial No Sands RTE = 57.7'I ADb 028231 12. Date Spudded4/2/97 I 13' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °ffsh°re 116' N°' °f c°mpleti°ns4/9/97 5/9/97 M S L I O n e i71 Total Depth (MD+TVD)118. Plug Back Depth (MD+-I-VD)]I 9. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost" 9370' 7300' FTI 9260 7205 FTI [] Yes [] No MD 1800' (Approx.) 22. Type Electric or Other Logs Run LWD 23. CASlNG~ LINER AND CEMENTING RECORD CASING SE'I-rING DEPTH HOLE SIZE WT. PER FT. GRADE TOP Bo'n-OM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 Surface 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 32' 5543' 12-1/4" 1750' sx PF 'E', 300 sx Class 'G', 89 sx PF 'C' , 7" 26# L-80 24.7' 9344' 8-1/2" 250 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) 4.5" at 5 spf 2 7/8" L-80 Rd EUE 8829' MD TVD MD TVD 9030'-9060' 7007'-7033' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9066'-9096' 7038'-7064' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 127. PRODUCTION TEST i Date First Production I Method of Operation (Flowing, gas lift, etc.) 5/26/97 I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBb GAS-MCF WATER-BBb CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing casing Pressure CALCULATED OIL-BBb GAS-MCF WATER-BBb OIL GRAVITY-APl (CORR) [Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent d ~bs~n'~e ~,k~l}gas or water. Submit core chips. None Form 10-407 Rev. 07-01-80 Submit In Duplicate '29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. TKUP 8786' 6799' KC1 9020' 6999' TKB7 9055' 7029' ....... 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .,~..,~ ~ ~ Title Senior Drilling En~lineer Date ....... Chip AIvord MPE-14 97-05 Prepared By Name/Number: Jeanne Haas, 564-5225 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 Performance Enquiry Report Operator BP Exploration Date 00:56, 28 Aug 97 Page 1 The analysis is from - 06:00, 08 Apr 97 - to - 06:00, 08 Apr 97 Programs in Result Table: MPE-14 Drill and Complete Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) MPE-14 Event 06:00, 08 Apr 97 06:00, 08 Apr 97 0 hr 0 min Obtained leak off 13.800 Hole Size MDR 8-1/2 Facility Date/Time 31 Mar 97 01 Apr 97 02 Apr 97 03 Apr 97 04 Apr 97 05 Apr 97 Progress Report M Pt E Pad Well MPE- 14 Rig Nabors 27E Page 1 Date 27 August 97 17:00-20:00 20:00-00:00 00:00-02:00 02:00-06:00 06:00-08:00 08:00-13:00 13:00-19:00 19:00-20:30 20:30-21:00 21:00-22:00 22:00-23:00 23:00-00:30 00:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-18:00 18:00-18:30 18:30-01:00 01:00-01:30 01:30-02:00 02:00-02:30 02:30-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-12:00 12:00-13:00 13:00-13:30 13:30-14:00 14:00-18:00 18:00-18:30 18:30-19:00 19:00-22:00 22:00-23:00 23:00-00:00 00:00-01:30 01:30-03:00 03:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-22:00 22:00-23:00 23:00-01:30 01:30-02:30 02:30-06:00 06:00-06:30 06:30-10:30 10:30-11:00 Duration 3hr 4hr 2hr 4hr 2hr 5hr 6hr 1-1/2 hr 1/2 hr lhr lhr 1-1/2 hr 3-1/2 hr lhr lhr 1/2hr 2-1/2 hr 1/2 hr 8-1/2 hr 1/2 hr 6-1/2 hr 1/2 hr 1/2hr 1/2 hr 3-1/2 hr 1/2 hr lhr lhr 3-1/2 hr lhr 1/2hr 1/2hr 4hr 1/2 hr 1/2 hr 3hr lhr lhr 1-1/2 hr 1-1/2 hr 3hr 1/2 hr 11-1/2 hr 1/2 hr lhr 1/2 hr 2hr lhr 2-1/2 hr lhr 3-1/2 hr 1/2 hr 4hr 1/2 hr Activity Rigged down High pressure lines Rig moved 30.00 % Rig moved 50.00 % Rig moved 65.00 % Rig moved 100.00 % Rigged up Lines / Cables Rigged up Divertor Made up BHA no. 1 Tested Divertor Tested High pressure lines Circulated at 112.00 ft Drilled to 245.00 ft Made up BHA no. 1 Drilled to 330.00 ft Cleared Flowline Held safety meeting Cleared Flowline Repaired Top drive Drilled to 1202.00 ft Held safety meeting Drilled to 2139.00 ft Circulated at 2139.00 ft Pulled out of hole to 936.00 ft R.I.H. to 2139.00 ft Drilled to 2421.00 ft Held safety meeting Drilled to 2710.00 ft Repaired Fluid system Drilled to 3168.00 ft Circulated at 3168.00 ft Pulled out of hole to 1500.00 ft R.I.H. to 3168.00 ft Drilled to 3542.00 ft Held safety meeting Circulated at 3542.00 ft Pulled out of hole to 250.00 ft Downloaded MWD tool Serviced Crown block Made up BHA no. 2 R.I.H. to 2329.00 ft Drilled to 2515.00 ft Held safety meeting Drilled to 3918.00 ft Held safety meeting Drilled to 4012.00 ft Circulated at 4012.00 ft Pulled out of hole to 2033.00 ft R.I.H. to 3542.00 ft Pulled out of hole to 2329.00 ft R.I.H. to 4012.00 ft Drille~ 4293.00 ft Held saf6ty meeting Drilled to 4765.00 ft Circulated at 4765.00 ft Facility Date/Time 06 Apr 97 07 Apr 97 08 Apr 97 09 Apr 97 10 Apr 97 Progress Report M Pt E Pad Well MPE- 14 Rig Nabors 27E Page 2 Date 27 August 97 11:00-13:00 13:00-14:30 14:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-08:30 08:30-09:30 09:30-11:00 11:00-14:00 14:00-15:30 15:30-19:00 19:00-20:00 20:00-01:30 01:30-03:00 03:00-05:00 05:00-06:00 06:00-08:00 08:00-09:00 09:00-10:00 10:00-13:30 13:30-14:00 14:00-17:00 17:00-18:00 18:00-18:30 18:30-20:00 20:00-22:00 22:00-23:30 23:30-02:00 02:00-03:00 03:00-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-22:00 22:00-22:30 22:30-23:30 23:30-00:30 00:30-01:00 01:00-06:00 06:00-06:30 06:30-14:00 14:00-14:30 14:30-15:30 15:30-16:00 16:00-18:00 18:00-18:30 18:30-01:30 01:30-02:30 02:30-04:30 04:30-06:00 06:00-07:00 Duration 2hr 1-1/2 hr 14hr lhr 1/2 hr 1/2 hr 2hr lhr 1-1/2 hr 3hr 1-1/2 hr 3-1/2 hr lhr 5-1/2 hr 1-1/2 hr 2hr lhr 2hr lhr lhr 3-1/2 hr 1/2 hr 3hr lhr 1/2 hr 1-1/2 hr 2hr 1-1/2 hr 2-1/2 hr lhr 2hr 1/2 hr 1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr lhr lhr 1/2 hr 5hr 1/2 hr 7-1/2 hr 1/2 hr lhr 1/2 hr 2hr 1/2 hr 7hr lhr 2hr 1-1/2 hr lhr Activity Pulled out of hole to 1750.00 ft R.I.H. to 4765.00 ft Drilled to 5560.00 ft Circulated at 5560.00 ft Pulled out of hole to 5000.00 ft Held safety meeting Pulled out of hole to 250.00 ft Downloaded MWD tool Made up BHA no. 3 R.I.H. to 5560.00 ft Circulated at 5560.00 ft Pulled out of hole to 0.00 ft Serviced Casing handling equipment Ran Casing to 5543.00 ft (9-5/8in OD) Circulated at 5543.00 ft Mixed and pumped slurry - 274.000 bbl Circulated at 2009.00 ft Mixed and pumped slurry - 465.000 bbl Serviced Handling equipment Rigged down Divertor Rigged up BOP stack Installed BOP test plug assembly Tested BOP stack Installed Wear bushing Held safety meeting Made up BHA no. 4 R.I.H. to 2006.00 ft Drilled installed equipment - DV collar R.I.H. to 5456.00 ft Tested Casing Drilled installed equipment - Float collar Circulated at 5580.00 ft Performed formation integrity test Held safety meeting Drilled to 7225.00 ft Held safety meeting Drilled to 7504.00 ft Circulated at 7504.00 ft Pulled out of hole to 5543.00 ft Serviced Block line R.I.H. to 7504.00 ft Drilled to 8067.00 ft Held safety meeting Drilled to 8727.00 ft Circulated at 8727.00 ft Pulled out of hole to 7500.00 ft R.I.H. to 8727.00 ft Drilled to 8821.00 ft Held safety meeting Drilled to 9370.00 ft Circulated at 9370.00 ft Pulled out of hole to 5543.00 ft Repaired Top drive Repaired Top drive Facility Date/Time 11 Apr 97 M Pt E Pad Progress Report Well MPE- 14 Rig Nabors 27E Page Date Duration Activity 07:00-08:30 08:30-10:30 10:30-18:00 18:00-20:00 20:00-21:00 21:00-21:30 21:30-22:00 22:00-23:00 23:00-06:00 06:00-07:30 07:30-09:00 09:00-10:30 10:30-11:00 11:00-11:30 11:30-14:00 14:00-15:30 15:30-18:00 18:00-22:00 22:00-23:00 23:00-06:00 1-1/2 hr 2hr 7-1/2 hr 2hr lhr 1/2 hr 1/2 hr lhr 7hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2hr 2-1/2 hr 1-1/2 hr 2-1/2 hr 4hr lhr 7hr R.I.H. to 9370.00 ft Circulated at 9370.00 ft Pulled out of hole to 250.00 ft Downloaded MWD tool Installed BOP test plug assembly Serviced Top ram Removed BOP test plug assembly Rigged up Casing handling equipment Ran Casing to 8200.00 ft (7in OD) Ran Casing to 9345.00 ft (7in OD) Circulated at 9345.00 ft Mixed and pumped slurry - 51.000 bbl Tested Casing Tested Fluid system Serviced Casing handling equipment Serviced Top ram Rigged down BOP stack Installed Adapter spool Freeze protect well - 70.000 bbl of Diesel Rigged down Handling equipment 3 27 August 97 PrtJciht3R-R~v 1'3rilllrl~ __ ~'"' ".~ ~-,~' "7 .... F~' .~ Conffa~or= NABORS 4ES phone: 4164 Ibaiiy' cl./mm comp $28,674[~ .. $123.764 ~ ~umm / D~ratlon~t~00:- RDMO . IRl~Jn~nfh 7"26~L80 B~/93~' Rig ~6pt (hr/date}= 2400 HRS-6-6-g7 . I Rig R61e~e :Pump . I I Over Daily N/A ] To~I I,;;;il~ ' [Cum ~uld BHne I N/A Fluid rvve:~b~.: Loss: Doe t.oss: I ........ . . .......... ,,,., ,,~ -,, ' , i ..,ij?, r r Dui: N/A N/A . N/A "~nteciion Data ........ ' ...... .. Source: Volume; . Type Fluid: ,nl0~on ' CC-2A , _ . Well; ,. ' Daily Volume: Ic~Jmmul~tlva ' N/A ~" ' N/A ........ _ ~ VolLJme: ........ ~. .~ei' ~ F~,~ ' IFuo! I~: Wa~o7 ..... Iod. W~tor Ua~: . ~a~ ISouree: BPX Leke - [Ro~d: gal Ju~d: . B~klSource: ' ' ~u~ln~ DOm ...... ' tSt°mge' N/A I em : D~ly: N/A cP~umulatlve:. N/A- CROtn- 'F "F -. ~v~OP Onfn least Fir~ ,.)rd,: k,6/~ ~I ~' ~,o~ .,~: ~,~,~. _ ~t ~ T~.t: ; ~/~T .JL=.t ~O~ 0~,; ~/~7 I~ H2S 0r,, Wei~7 - . . -. ~mo Operell~ Prob Code Hrs. O~ratiorm .. " NO 8~1[L8 Nd 'ACCIDENTS "84.~ DSL~A: ~' ~0:~ 'r~SLB o6o0.o~30 ~CPKn '.5 3ONT'POH W~RBP & RuN TOoL . ~-o7~ NO:~U .5 PULL WEAR RING' . ...... o70o-1~ RUN COMP - ~ RIG U~' FLR .MU.ESP & sHRvi(;I; - ~. ......... ~ ...... ~_ , . ~O-lSOO RUN'CO~P "' 5 RIH WIESP ON-2//8 TBG . . - '~t100 RU~bbM, -2 ' MU OABL~ 8~LICE . . _. ........... ~ . , ,, , , ,, ,,. , ~7~.~o ;~ Ru'~ COMP: ' . : '2.S ' deNT Rill W/bOMP,MU.HNGR LNDG J] . . . . : . · 193~2~5 nuNCoMP~ 3 : MU ~SP PIGTAIE SPLICE, ~0-~ '-NU ND " ~ - .5 LND HNGR RiLD~;~D ~DG J r~il~i' ; _ , = ..,~ ,,- ~24~ NO-Nt) - I ND BOP .. . - . . . . . 24~3~~ ND NU 3 ~U AD~R FLNGE,TR~E,C~"ESP PULL TwO,sET'hPV RIG I-IDIiNI:S -.. " ..... ~ao~'a3o ~m I:S"" BULLHEAD FHEEZE PRO~,TBG"IO .. ~ . --0430~00 ~D'N[)'' " ' . .5 BLOW-DWN LINEs,RD'CE~R.SECU. rll- . __ ....[ ..... ~ELEAsE RiG, 0~°° HRS 5-9-~7;;':;';;;'~;; .... ~.~ ' " '--- " . , . .;, . ,- -- . , = ,= ..... Report 3RN 2 Prlldhn~. IBnv ~rjllinn ..... .. ';~,~:..~ .~ ...... 7 -.~. p_._~?u . AFL ~: ~47094 [ROpo~No: 2 JD~ - .... 5/8/97 IC;m¢oti~ OayCE~t:, 1-~ii: J NEW ~a~or; NABORS 4ES ~one: 4154 ~a~i~" $73,504 ~WO ~o~: $95,0~0 . ~lnte~late (Pr~[J~6n) C~g: 3peration at ~:. TOH W~S/RBP . ~m~n~h 7"26fl~0 B~/9~ 4' · g.A~&pt (hr~dnto): '2~0'HRS 5-6-97, JRIg Releaee'(hr/det~):. . .. NIA ~ , pump No~ I Liner Size: S ~ 10 'pM: N/A ~GPM: ~A ~1: N/A ~$1~ Pump Rate; N/A SI~ Pump psi: N/A Da~ No. 21 kl~er Size:"' ~A ~PM~ ~A GPM: ~A ~1: N/A ~low Pump ~o: ;N/A glow Pump ~: ~A ~uld Brine lover N/A~ Dally .N/A ~ Total N/A-- {Dally ~C~m " Fluid T~e: - ~W.ght: 9.6. is: 28-1 b~,an~:j PV~P; N/ A 3hloHdes:L°s';_' ~A ! BBU ~s~ [Flu~ go~:. N/A amp (pit):~ ]N/A E.S, (DAM):. IC°n';p'WIr:N/A . ~A-- BHA DescdpUon: . ,, , , , , , ,. . . BH~ ' ~A '1aHAbeng~;' ". N/A l°a~sll~p~: N/A' I Hou. OnJars: .N/A -,,, o.¢ ..¢ t o., .. Oue N/A; N/A N/A N/A N/A N/A N/A Injection OO-2A Rate; N/A Or'aura: ~A , , .. r W~l:, , ~pm ..... pti .. ~Ummu~ve - - Dally v~me:- N/A ~BL~ V01umo: N/A = ..... ~ ~ro~e Protffi Flula; N/A ~ ' - . ' IV~Mme= ~A ,, gal F~el & W~te¢ b~te ' ~V; ~A c Chin ~or; -- -10 . 5/8/~ Fire Drill; ~st~t BOPEsplll DHiI: .Te~: 5~/97._2 ~ ~6/07 ~ 5/8/97 Time Operation Prob C~e Hr~ " O~ratl~ns From 0~ to ~ '" NO SPILLS NO ACCIDENTS "~G DSLTA '"102 DSLS ' o~-o700 TEST ~' I ~EST BOP,O~,INS~WEAR RING 07~ PL;PKR . .. 3 ~OAD PiPE SHED W/2 W8 TBG,S~.DRiF~ ..... 1~1a~ - PL-~AR "' 2 MU RBP' R~TRV TOO~RIH W/2'7/8-TBG,TO 21'~b. -- 1~1~o CIRC ....... ~.5 CIRC OUT _..____ _..____~_FR~F~RBTDF:T W~.6 BRINE ' ' - ~14~ PL-pKR 1.5". CONT RIH TO'lO0 - ,-- .. ~1~ d~RO 1 DIRe OUT CRODE TO '~ ~ ,Wi 9.6 BRINE "' 1~-~ "~L-P~ S RIH W/hB~ RETRV TOOL,TO 88~6'" ' ~~' ~RO. "' 2 CIRC HOLE VOLUME ~/9.6 BRINE, t76 BBLS W]~DE TO ~,(4BpM ~7008)"-- 220~22~ Rib .. .5 - RIH TO 89P~' TAG REP,SE ~ OWN 5K~VER,MONT WELL STATIC " . I. . .... ;, . RELEASE-RBP WI5 K OVER,RIH TO 8931 ' ' - ... .~~ . ~[~o 3.5 ~IR~'~ BBPM 11 ~ ~ ,R BEE GAIN ,CLOSE H~D'RL, CONT GIRO TIdRU CHOKE '" R~TURN-SO ~LL~' CRUDE TO ) l ,MONT'ANNULi sLI LOSS.PUMP PILL PER WE~ PLAN,ON B'i ] M ..... P~R 4 LD 6 JTS'~ 7/8,TOH W~S/RBP " ' "' PL ...~ . . . . _ . .. . . ,. , . ~., . 0i P .01 I Jrllllll{.I . IC°mpteti°n - ' '~ ~ ..... ~ 7, ......... ?.; ,;-~'.. ~,;' ~.~, ~.'~ We~ - ' MPU E-14 . 9~4. . 9260 N/A ~1~ ~p ~mm ' Ilnm~omate (Produ~mO ~ra~n mt ~: TEsT BOP I~l?~n~pfh . ' 7"26~ L80/9344 ~i~nlh ..... I Rig Rel~e (hr/d~e): N/A ' -- ' ' ~ ~ (hr~am): 2400 H~ 5-6-97 . prop No. 1 Un~ ~ze: 5'x 10 SPM: - ~A ' ~'M: . N/A psi;. ~A Slow P~"Rnte: N/A Slow Pump psi: . ~ · .', . Oa~ ~. 2~uner O~e: ~A SPM= ... N/A- GOM: ~A ' ~i: .N/A . Sl~ P~ Rate: ' N/A Blow Pump pal: - · N/A · - : ~luid Bdno I~er ' · N/A D~Iy ~A' --:J '~m~l ' ~A' 'l Dally [Gum · BBU Lm~ ' ' I ~st: I~a~ Fluid W'gh~TV~:' ~.~ FiB;28. J~'p:lbalan°': N , 'A Chlo~demL°SS; -, .,. i.., ~..,. ~. p~ ,,,,,: .,. i~... <o.~,: ",~- r- ~A De~: . . .. . .,.. . *m.. . . B" & BitNum, N/A' Size:N/A - """' ' "'* p~:. .,.,...--..~""""' -.,. I'.,¢"*' . ....... I~-.~,-: O~t: N/A N/A N/A N/A N/A N/A N/A i i i _ . i iii _~1 ii , . InlacU~ D,.tj ., W~fl:' opm pbs JOumulaflve · Daily Volume: N/A BaLI Volume: N/A i i i i i.- i ii ~r~o~o Prol~ Fluid: -,, : V0iumo~ flal ,, ,- ,.--EU~I,& Writer ~ta - Fu~ 1~ J Fuel- ' BPX pue~ .. JDd. Wa~r 600 J~d. Water ' ~ke Ua~: ~[.J Rour~: JRa~'d'. gui J~&~; B~L~our~: : JBtorage N/A emp: .,rJWlnU D~IV; N/A .: C~umulatlve: N/A CR~,~. oF "~m-0plll Drift: ~7 ' N ~oium~ (Gal~:): N/A , ,. N/A N/A JSpi!l (Yin)? - ' ~ypa SpilL: ' Re~.'pited9 , , . ... Time Opem~on Pr~ ~e 14r,. O~r~lons From 0~ to ~ 'L · . · , ~ ... NO 0PILLS NO ACCIDENT0 "039 DOLTA "101 DSL8 , . . . i.,, . ,, lg30-24~ MIRU MOVE RIO F/MPU E-18 TO MPU E-14 ~t~ . N~ND 1 ~U TT LINES,Nb FRA~'T~E~ ...... 010~ NO-ND $ NU ADPT FLNG,BOP,PULL BPV. SET TE~'~ PLUG ~0~ -TEST 2 TEST BOP PER SSD POLICY ' ' ' ' . . . -. .. · . ...... I- . -.. , , , _ . . .. . - .. .. ,... , .. . . . ..~ . , I- ,,, . . ....... '"'AOGCC (JOHN SPALDING) WAI~' WITNESS ...., . . ..... .... . ,.L I I II..t~/Ul · IRY-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION MILNE POINT / MPE-14 500292273400 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 040997 MWD SURVEY JOB NUMBER: AK-MM-70089 KELLY BUSHING ELEV. = 57.60 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -57.60 212.69 212.69 155.09 301.11 301.11 243.51 391.27 391.27 333.67 481.08 481.08 423.48 0 5 9 15 20 N .00 E .00 .00N .00E S 41.64 E .04 .12S .liE S 62.84 W .22 .23S .05E S 52.60 W .12 .40S .21W S 45.02 W .11 .71S .55W .00 .16 .23 .26 .37 571.48 571.48 513.88 659.97 659.96 602.36 749.83 749.82 692.22 841.94 841.93 784.33 934.61 934.58 876.98 22 25 27 36 12 S 32.66 W .09 1.15S .90W S 23.04 W .10 1.69S 1.18W S 26.12 W .03 2.32S 1.47W S 32.00 E .58 3.06S 1.37W S 49.99 E .70 4.10S .36W .59 .93 1.35 2.05 3.44 1024.04 1023.97 966.37 1116.67 1116.43 1058.83 1207.63 1206.91 1149.31 1303.52 1302.02 12.44.42 1397.90 1395.43 1337.83 2 12 4 41 6 52 7 45 8 35 S 30.89 E 1.28 6.18S 1.24E S 16.66 E 2.81 11.34S 3.24E S 10.48 E 2.49 20.26S 5.30E S 10.17 E .93 32.27S 7.48E S 10.21 E .88 45.48S 9.86E 6.04 11.53 20.36 31.98 44.75 1489.25 1485.68 1428.08 1582.40 1577.35 1519.75 1677.50 1670.22 1612.62 1772.00 1762.04 1704.44 1868.26 1855.30 1797.70 9 11 11 10 13 36 13 42 14 58 S 3.42 E 1.33 59.48S ll.50E S 1.94 E 2.14 75.94S 12.25E S 3.55 E 2.57 96.31S 13.26E S 6.17 E .66 118.54S 15.15E S 7.45 E 1.36 142.21S 17.99E 57.87 72.73 91.17 111.65 133.87 1961.06 1944.37 1886.77 2053.36 2031.65 1974.05 2150.17 2121.32 2063.72 2246.24 2208.91 2151.31 2335.26 2289.70 2232.10 17 30 20 26 23 46 24 43 24 57 S 7.74 E 2.73 167.94S 21.42E S 6.33 E 3.21 197.72S 25.07E S 5.69 E 3.46 233.96S 28.87E S 5.51 E .98 273.22S 32.72E S 2.26 E 1.56 310.52S 35.25E 158.17 186.15 219.89 256.32 290.40 2428.86 2374.90 2317.29 2521.98 2458.87 2401.27 2616.06 2541.24 2483.64 2708.39 2619.76 2562.16 2802.18 2697.31 2639.71 23 57 27 13 30 31 32 54 35 31 S 2.91 W 2.52 349.23S 35.06E S 4.77 W 3.62 389.36S 32.33E S 6.29 W 3.59 434.57S 27.92E S 6.77 W 2.59 482.79S 22.39E S 4.78 W 3.04 535.26S 17.12E 324.44 358.53 396.31 436.21 479.98 2895.14 2771.61 2714.01 2989.32 2844.30 2786.70 3082.66 2914.32 2856.72 3177.82 2984.85 2927.25 3270.01 3052.42 2994.82 38 19 40 37 42 10 42 9 43 33 S 4.32 W 3.02 590.93S 12.70E S 3.18 W 2.56 650.65S 8.80E S 1.02 W 2.26 712.32S 6.55E S .06 W .68 776.19S 5.95E S .95 E 1.69 838.89S 6.44E 526.97 577.79 631.09 687.12 742.63 S' ~.RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPE-14 500292273400 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 040997 MWD SURVEY JOB NUMBER: AK-MM-70089 KELLY BUSHING ELEV. = 57.60 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3363.99 3119.89 3062.29 3456.74 3185.41 3127.81 3550.34 3251.08 3193.48 3645.59 3318.11 3260.51 3738.70 3383.50 3325.90 44 40 S 1.42 E 1.24 904.30S 7.80E 45 25 S 1.34 E .81 969.92S 9.38E 45 27 S .71 E .48 1036.60S 10.57E 45 5 S 1.20 E .53 1104.26S ll.70E 45 41 S .58 E .80 1170.54S 12.73E 800.94 859.54 918.89 979.07 1037.99 3832.48 3449.09 3391.49 3925.86 3514.54 3456.94 4019.62 3579.89 3522.29 4112.88 3644.14 3586.54 4208.00 3708.83 3651.23 45 32 S .08 E .41 1237.56S 13.11E 45 27 S .22 W .25 1304.17S 13.03E 46 9 S 2.05 E 1.89 1371.37S 14.11E 46 45 S 5.09 E 2.45 1438.82S 18.33E 47 32 S 8.17 E 2.52 1508.06S 26.39E 1097.26 1155.95 1215.71 1277.16 1342.01 4302.22 3772.43 3714.83 4395.76 3835.49 3777.89 4490.15 3898.89 3841.29 4584.13 3961.55 3903.95 4678.35 4024.13 3966.53 47 31 S 10.35 E 1.71 1576.65S 37.57E 47 42 S 10.00 E .33 1644.65S 49.78E 47 54 S 12.32 E 1.83 1713.25S 63.31E 48 27 S 15.56 E 2.63 1781.19S 80.19E 48 18 S 18.48 E 2.32 1848.52S 100.80E 1407.76 1473.47 1540.34 1608.20 1677.29 4773.69 4087.64 4030.04 4868.23 4150.34 4092.74 4961.03 4211.49 4153.89 5054.97 4273.11 4215.51 5148.31 4333.33 4275.73 48 9 S 19.89 E 1.12 1915.68S 124.16E 48 45 S 20.82 E .98 1982.01S 148.77E 48 47 S 23.52 E 2.19 2046.63S 175.11E 49 13 S 27.17 E 2.97 2110.70S 205.46E 50 25 S 30.72 E 3.18 2173.08S 239.99E 1747.52 1817.62 1887.02 1957.83 2029.12 5242.56 4393.56 4335.96 5336.52 4453.99 4396.39 5430.97 4514.94 4457.34 5526.49 4576.33 4518.73 5576.68 4608.37 4550.77 50 8 S 33.29 E 2.12 2234.55S 278.40E 49 47 S 36.13 E 2.34 2293.68S 319.35E 49 52 S 42.03 E 4.77 2349.66S 364.81E 50 9 S 45.07 E 2.46 2402.68S 415.22E 50 29 S 43.33 E 2.75 2430.37S 442.15E 2101.44 2172.89 2243.71 2314.24 2351.36 5672.23 4669.43 4611.83 5766 . 14 4730 . 08 4672 . 48 5860 . 36 4790 . 01 4732 . 41 5952.70 4847. 07 4789.47 6048 . 66 4906 . 41 4848 . 81 50 4 S 44.00 E .70 2483.53S 492.89E 49 28 S 44.80 E .91 2534.76S 543.05E 51 31 S 46.26 E 2.49 2585.67S 594.93E 52 7 S 44.70 E 1.48 2636.57S 646.68E 51 28 S 45.89 E 1.19 2689.62S 700.28E 2422.18 2491.01 2560.38 2629.68 2701.74 6142.28 4964.88 4907.28 6235.68 5023.16 4965.56 6329.05 5081.35 5023.75 6421.$1 5138.93 5081.33 6516.20 5197.54 5139.94 51 13 S 46.87 E .86 2740.06S 753.20E 51 33 S 46.11 E .73 2790.30S 806.13E 51 20 S 46.75 E .59 2840.63S 859.04E 51 54 S 43.82 E 2.55 2891.79S 910.69E 51 19 S 45.39 E 1.44 2944.46S 962.64E 2771.19 2840.47 2909.81 2979.28 3050.24 Si .RY-SUN DRILLING SERVICES ANCHOPJtGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPE-14 500292273400 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 040997 MWD SURVEY JOB NUMBER: AK-MM-70089 KELLY BUSHING ELEV. = 57.60 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6608.73 5255.74 5198.14 50 42 S 45.97 E .83 2994.72S 1014.10E 3118.83 6701.78 5314.24 5256.64 51 22 S 44.16 E 1.68 3045.82S 1065.31E 3188.06 6796.13 5373.43 5315.83 50 54 S 45.86 E 1.49 3097.76S 1117.27E 3258.37 6890.96 5432.62 5375.02 51 50 S 42.86 E 2.66 3150.72S 1169.04E 3329.50 6981.85 5489.14 5431.54 51 15 S 43.73 E 1.00 3202.53S 1217.85E 3398.20 7075.53 5548.02 5490.42 50 52 S 43.83 E .41 3255.14S 1268.26E 3468.38 7169.77 5607.29 5549.69 51 10 S 43.16 E .64 3308.29S 1318.69E 3539.03 7262.86 5666.36 5608.76 50 2 S 42.67 E 1.28 3360.98S 1367.68E 3608.60 7354.61 5725.84 5668.24 49 7 S 43.48 E 1.22 3412.00S 1415.38E 3676.10 7450.67 5789.12 5731.52 48 27 S 43.92 E .77 3464.25S 1465.31E 3745.73 7545.13 5852.43 5794.83 47 22 S 44.41 E 1.22 3514.53S 1514.15E 3813.11 7639.32 5916.87 5859.27 46 17 S 44.42 E 1.15 3563.60S 1562.22E 3879.06 7732.87 5981.64 5924.04 46 4 S 44.26 E .26 3611.88S 1609.40E 3943.89 7825.63 6046.03 5988.43 45 59 S 44.77 E .41 3659.49S 1656.21E 4007.95 7919.73 6111.53 6053.93 45 47 S 44.26 E .44 3707.66S 1703.58E 4072.78 8013.26 6177.80 6120.20 43 57 S 45.13 E 2.07 3754.57S 1749.97E 4136.03 8105.65 6245.14 6187.54 42 28 S 44.51 E 1.67 3799.43S 1794.56E 4196.62 8201.38 6317.17 6259.57 39 54 S 45.45 E 2.75 3844.03S 1839.11E 4256.96 8294.51 6389.51 6331.91 38 9 S 46.57 E 2.04 3884.76S 1881.29E 4312.78 8388.76 6464.93 6407.33 35 32 S 46.26 E 2.78 3923.72S 1922.23E 4366.45 8483.32 6542.86 6485.26 33 25 S 46.41 E 2.24 3960.68S 1960.94E 4417.30 8578.60 6622.71 6565.11 32 42 S 46.15 E .76 3996.60S 1998.51E 4466.71 8671.38 6701.04 6643.44 32 6 S 46.59 E .70 4030.91S 2034.51E 4513.94 8767.80 6782.83 6725.23 31 49 S 45.82 E .51 4066.24S 2071.36E 4562.48 8861.09 6862.22 6804.62 31 32 S 46.76 E .61 4100.10S 2106.77E 4609.05 8954.88 6942.28 6884.68 31 14 S 45.50 E .77 4133.96S 2141.99E 4655.51 9048.36 7022.24 6964.64 31 8 S 45.46 E .10 4167.90S 2176.51E 4701.74 9142.47 7102.95 7045.35 30 45 S 45.51 E .42 4201.84S 2211.03E 4747.95 9236.23 7183.71 7126.11 30 17 S 45.02 E .56 4235.36S 2244.87E 4793.47 9315.66 7252.41 7194.81 29 56 S 45.06 E .45 4263.53S 2273.07E 4831.61 9370.00 7299.50 7241.90 29 56 S 45.06 E .00 4282.69S 2292.27E 4857.56 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4857.56 FEET AT SOUTH 28 DEG. 9 MIN. EAST AT MD = 9370 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 151.84 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 9,370.00' MD S ~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 BP EXPLORATION MILNE POINT / MPE-14 500292273400 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 040997 JOB NUMBER: AK-MM-70089 KELLY BUSHING ELEV. = 57.60 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION .00 .00 -57.60 .00 N .00 E .00 1000.00 999.95 942.35 5.39 S .76 E .05 2000.00 1981.38 1923.78 179.95 S 22.98 E 18.62 3000.00 2852.41 2794.81 657.59 S 8.41 E 147.59 4000.00 3566.30 3508.70 1357.23 S 13.61 E 433.70 .O5 18.57 128.97 286.11 5000.00 4237.12 4179.52 2073.39 S 187.18 E 762.88 6000.00 4876.11 4818.51 2663.11 S 672.94 E 1123.89 7000.00 5500.50 5442.90 3212.76 S 1227.63 E 1499.50 8000.00 6168.26 6110.66 3748.08 S 1743.45 E 1831.74 9000.00 6980.86 6923.26 4150.36 S 2158.68 E 2019.14 329.18 361.01 375.61 332.24 187.40 9370.00 7299.50 7241.90 4282.69 S 2292.27 E 2070.50 51.35 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SI .RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 BP EXPLOR3kTION MILNE POINT / MPE-14 500292273400 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 040997 JOB NUMBER: AK-MM-70089 KELLY BUSHING ELEV. = 57.60 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -57.60 57.60 57.60 .00 157.60 157.60 100.00 257.60 257.60 200.00 357.60 357.60 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .06 S .05 E .00 .00 .18 S .15 E .00 .00 .31 S .09 W .00 .00 457.60 457.60 400.00 557.60 557.60 500.00 657.61 657.60 600.00 757.61 757.60 700.00 857.61 857.60 800.00 .61 S .45 .07 S .85 .68 S 1.18 .37 S 1.50 .20 S 1.28 .00 .00 .01 .01 .01 .00 .00 .00 .00 01 957.63 957.60 900.00 1057.71 1057.60 1000.00 1157.98 1157.60 1100.00 1258.70 1257.60 1200.00 1359.64 1357.60 1300.00 4 7 14 26 39 .41 S .00 .58 S 1.93 .58 S 4.21 .33 S 6.42 .86 S 8.84 .O3 .11 .38 1.10 2.04 02 .07 28 .72 94 1460.80 1457.60 1400.00 1562.27 1557.60 1500.00 1664.52 1657.60 1600.00 1767.43 1757.60 1700.00 1870.64 1857.60 1800.00 54 72 93 117 142 .94 S 11.23 .04 S 12.12 .27 S 13.07 .46 S 15.03 .82 S 18.07 3.20 4.67 6.92 9.83 13.04 1 16 1.47 2 25 2.90 3.22 1974.96 1957.60 1900.00 2081.15 2057.60 2000.00 2189.82 2157.60 2100.00 2299.85 2257.60 2200.00 2409.93 2357.60 2300.00 172 207 249 295 341 .15 S 21.98 .59 S 26.15 .88 S 30.46 .59 S 34.66 .56 S 35.45 17.36 23.55 32.22 42.25 52.33 4.31 6.19 8.67 10.04 10.08 2520.56 2457.60 2400.00 2635.06 2557.60 2500.00 2753.81 2657.60 2600.00 2877.35 2757.60 2700.00 3006.84 2857.60 2800.00 388 444 507 58O 662 .71 S 32.38 .17 S 26.86 .75 S 19.66 .00 S 13.53 .04 S 8.16 62.96 77.46 96.21 119.75 149.24 10.62 14.50 18.75 23.54 29.49 3141.06 2957.60 2900.00 3277.15 3057.60 3000.00 3417.14 3157.60 3100.00 3559.63 3257.60 3200.00 3701.62 3357.60 3300.00 751.51 843.81 941.73 1043.22 1144.00 S 5.98 S 6.53 S 8.72 S 10.66 S 12.46 183.46 219.55 259.54 302.03 344.02 34.22 36.10 39.98 42.50 41.99 S' .RY-SLrN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPE-14 500292273400 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 040997 JOB NUMBER: AK-MM-70089 KELLY BUSHING ELEV. = 57.60 OPEKATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3844.63 3457.60 3400.00 3987.44 3557.60 3500.00 4132.52 3657.60 3600.00 4280.25 3757.60 3700.00 4428.61 3857.60 3800.00 1246.23 S 13.13 1348.18 S 13.28 1453.07 S 19.60 1560.71 S 34.66 1668.58 S 54.00 387.03 43.01 429.84 42.81 474.92 45.09 522.65 47.73 571.01 48.36 4578.17 3957.60 3900.00 4728.65 4057.60 4000.00 4879.24 4157.60 4100.00 5031.25 4257.60 4200.00 5186.39 4357.60 4300.00 1776.90 S 78.99 1884.10 S 112.80 1989.75 S 151.72 2094.66 S 197.42 2198.29 S 255.02 620.57 49.56 671.05 50.48 721.64 50.59 773.65 52.00 828.79 55.15 5342.11 4457.60 4400.00 5497.27 4557.60 4500.00 5653.80 4657.60 4600.00 5808.61 4757.60 4700.00 5969.85 4857.60 4800.00 2297.11 S 321.89 2386.83 S 399.34 2473.37 S 483.07 2557.67 S 565.88 2646.19 S 656.20 884.51 55.72 939.66 55.15 996.19 56.53 1051.01 54.81 1112.25 61.25 6130.66 4957.60 4900.00 6291.03 5057.60 5000.00 6452.07 5157.60 5100.00 6611.66 5257.60 5200.00 6771.02 5357.60 5300.00 2733.86 S 746.59 2820.28 S 837.42 2908.97 S 927.18 2996.30 S 1015.73 3084.19 S 1103.28 1173.06 60.81 1233.43 60.37 1294.47 61.04 1354.06 59.60 1413.42 59.36 6931.37 5457.60 5400.00 7090.72 5557.60 5500.00 7249.22 5657.60 5600.00 7403.11 5757.60 5700.00 7552.77 5857.60 5800.00 3173.99 S 1190.67 3263.64 S 1276.42 3353.29 S 1360.60 3438.58 S 1440.61 3518.55 S 1518.08 1473.77 60.35 1533.12 59.34 1591.62 58.51 1645.51 53.88 1695.17 49.66 7698.22 5957.60 5900.00 7842.28 6057.60 6000.00 7985.20 6157.60 6100.00 8122.48 6257.60 6200.00 8253.88 6357.60 6300.00 3594.00 S 1591.98 3667.99 S 1664.64 374-0.83 S 1736.17 3807.48 S 1802.50 3867.44 S 1863.04 1740.62 45.45 1784.68 44.06 1827.60 42.92 1864.88 37.28 1896.27 31.40 8379.74 6457.60 6400.00 8500.98 6557.60 6500.00 8620.07 6657.60 6600.00 8738.10 6757.60 6700.00 8855.67 6857.60 6800.00 3920.08 S 1918.43 3967.38 S 1967.99 4012.13 S 2014.67 4055.33 S 2060.12 4098.16 S 2104.71 1922.14 25.87 1943.38 21.24 1962.47 19.09 1980.50 18.04 1998.07 17.57 St RY-SUN DRILLING SERVICES ANCHOR3kGE ALASKA PAGE BP EXPLOR3kTION MILNE POINT / MPE-14 500292273400 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 040997 JOB NUMBER: AK-MM-70089 KELLY BUSHING ELEV. = 57.60 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8972.80 6957.60 6900.00 4140.47 S 2148.62 E 2015.20 17.13 9089.67 7057.60 7000.00 4182.88 S 2191.73 E 2032.06 16.87 9205.99 7157.60 7100.00 4224.58 S 2234.07 E 2048.39 16.33 9321.64 7257.60 7200.00 4265.64 S 2275.18 E 2064.04 15.65 9360.00 7290.84 7233.24 4279.16 S 2288.73 E 2069.16 5.12 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SHARED SERVICES DRILLING MILNE POINT / MPE-14 500292273400 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 ALAS= DATE OF SURVEY: 041197 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70100 KELLY BUSHING ELEV. = 57.30 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 5526.49 4576.53 4519.2 5592.94 4619.05 4561.7 5687.12 4679.22 4621.9 5781.13 4739.78 4682.4 5873.70 4799.36 4742.0 3 50 9 S 45.07 E .00 2402.81S 415.25E 5 50 16 S 44.71 E .45 2438.98S 451.29E 2 50 19 S 45.01 E .25 2490.34S 502.40E 8 49 27 S 45.39 E .97 2541.00S 553.42E 6 50 25 S 46.49 E 1.38 2590.26S 604.33E 2322.28 2371.02 2440.21 2508.72 2575.95 5968.65 4859.04 4801.7 6063.48 4917.93 4860.6 6156.37 4976.01 4918.7 6249.53 5034.39 4977.0 6342.91 5092.80 5035.5 4 51 41 S 45.50 E 1.57 2641.57S 657.43E 3 51 30 S 45.76 E .29 2693.55S 710.56E 1 51 5 S 46.02 E .51 2744.01S 762.61E 9 51 18 S 46.39 E .39 2794.25S 815.02E 0 51 15 S 45.85 E .45 2844.74S 867.53E 2646.00 2716.66 2785.48 2854.26 2923.33 6436.82 5151.38 5094.0 6530.41 5209.90 5152.6 6623.20 5268.55 5211.2 6716.05 5327.22 5269.9 6810.46 5386.82 5329.5 8 51 33 S 44.99 E .79 2896.26S 919.81E 0 51 2 S 44.84 E .57 2947.98S 971.38E 5 50 33 S 45.07 E .56 2998.87S 1022.19E 2 51 3 S 43.68 E 1.28 3050.30S 1072.51E 2 50 39 S 44.44 E .76 3102.92S 1123.43E 2993.19 3062.90 3131.52 3200.40 3270.60 6903.98 5445.49 5388.1 6997.70 5504.05 5446.7 7091.30 5563.18 5505.8 7185.10 5622.46 5565.1 7278.04 5681.68 5624.3 9 51 37 S 42.59 E 1.86 3155.72S 1173.56E 5 51 2 S 42.63 E .63 3209.57S 1223.10E 8 50 35 S 42.73 E .47 3262.91S 1272.28E 6 51 1 S 41.41 E 1.17 3316.88S 1320.98E 8 49 48 S 42.44 E 1.55 3370.17S 1368.83E 3340.61 3411.27 3481.31 3551.69 3621.07 7371.10 5742.25 5684.9 7466.31 5805.14 5747.8 7559.12 5867.53 5810.2 7653.02 5931.91 5874.6 7746.98 5997.02 5939.7 5 48 58 S 42.45 E .91 3422.30S 1416.51E 4 48 19 S 43.52 E 1.08 3474.59S 1465.23E 3 47 12 S 43.71 E 1.23 3524.34S 1512.63E 1 46 13 S 44.21 E 1.11 3573.54S 1560.07E 2 46 2 S 43.94 E .28 3622.21S 1607.19E 3689.35 3758.25 3824.28 3889.85 3954.80 7839.93 6061.59 6004.2 7933.89 6127.09 6069.7 8028.35 6194.17 6136.8 8123.32 6263.51 6206.2 8216.65 6333.77 6276.4 9 45 56 S 43.96 E .11 3670.34S 1653.59E 9 45 40 S 43.83 E .29 3718.89S 1700.30E 7 43 48 S 44.75 E 2.10 3766.48S 1746.72E 1 42 23 S 44.83 E 1.49 3812.53S 1792.43E 7 39 55 S 44.88 E 2.65 3856.07S 1835.74E 4018.93 4083.59 4147.26 4209.23 4267.86 8310.63 6406.76 6349.4 8405.08 6482.35 6425.0 8499.50 6560.22 6502.9 8593.90 6639.41 6582.1 8688.65 6719.46 6662.1 6 38 8 S 45.57 E 1.94 3897.75S 1877.74E 5 35 31 S 45.32 E 2.78 3937.47S 1918.09E 2 33 20 S 45.35 E 2.32 3974.99S 1956.05E 1 32 36 S 45.14 E .78 4011.16S 1992.53E 6 32 5 S 46.72 E 1.04 4046.42S 2028.95E 4324.25 4378.13 4428.95 4477.90 4526.01 ORIGINAL S~ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING MILNE POINT / MPE-14 500292273400 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN DATE OF SURVEY: 041197 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70100 KELLY BUSHING ELEV. = 57.30 FT. OPERATOR: BP EXPLORATION COURSE DLS DIRECTION DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 8 8 /8 9 781.64 6798.37 6741.07 31 45 S 46 875.35 6878.22 6820.92 31 21 S 45 968.72 6958.02 6900.72 31 11 S 45 062.83 7038.55 6981.25 31 9 S 44 156.38 7118.81 7061.51 30 39 S 44 .15 E .72 E .29 E .54 E .86 E 49 4080.32S 2064.59E 4572.55 49 4114.43S 2099.83E 4619.09 30 4148.40S 2134.41E 4665.21 41 4182.89S 2168.80E 4711.70 56 4217.05S 2202.60E 4757.62 9236.38 7187.79 7130.49 30 11 S 43.84 E .87 9370.00 7303.28 7245.98 30 11 S 43.84 E .00 4246.02S 2230.92E 4796.41 4294.50S 2277.47E 4860.92 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4861.03 FEET AT SOUTH 27 DEG. 56 MIN. EAST AT MD = 9370 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 152.44 DEG. TIE-IN SURVEY AT 5,526.49' MD PROJECTED SURVEY AT 9,370.00' MD -C-mERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING MILNE POINT / MPE-14 500292273400 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 DATE OF SURVEY: 041197 JOB NUMBER: AK-EI-70100 KELLY BUSHING ELEV. = 57.30 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 5526.49 4576.53 4519.23 2402.81 S 415.25 E 6526.49 5207.44 5150.14 2945.82 S 969.23 E 7526.49 5845.36 5788.06 3507.03 S 1496.08 E 8526.49 6582.77 6525.47 3985.41 S 1966.60 E 9370.00 7303.28 7245.98 4294.50 S 2277.47 E 949.96 1319.06 369.09 1681.13 362.08 1943.72 262.59 2066.72 123.00 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S=ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING MILNE POINT / MPE-14 500292273400 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 DATE OF SURVEY: 041197 JOB NUMBER: AK-EI-70100 KELLY BUSHING ELEV. = 57.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 5526.49 4576.53 4519.23 2402.81 S 415.25 E 949.96 5652.79 4657.30 4600.00 2471.67 S 483.72 E 995.49 45.53 5808.08 4757.30 4700.00 2555.38 S 567.99 E 1050.78 55.28 5965.85 4857.30 4800.00 2640.03 S 655.87 E 1108.55 57.77 6126.58 4957.30 4900.00 2727.91 S 745.93 E 1169.28 60.74 6286.18 5057.30 5000.00 2813.97 S 835.73 E 1228.88 59.59 6446.34 5157.30 5100.00 2901.53 S 925.08 E 1289.04 60.16 6605.50 5257.30 5200.00 2989.21 S 1012.51 E 1348.20 59.16 6763.88 5357.30 5300.00 3077.18 S 1098.21 E 1406.58 58.39 6923.01 5457.30 5400.00 3166.71 S 1183.65 E 1465.71 59.12 7082.03 5557.30 5500.00 3257.65 S 1267.42 E 1524.73 59.03 7240.22 5657.30 5600.00 3348.81 S 1349.34 E 1582.92 58.19 7394.03 5757.30 5700.00 3435.07 S 1428.18 E 1636.73 53.81 7544.07 5857.30 5800.00 3516.35 S 1505.00 E 1686.77 50.04 7689.72 5957.30 5900.00 3592.53 S 1578.54 E 1732.42 45.65 7833.75 6057.30 6000.00 3667.15 S 1650.51 E 1776.45 44.04 7977.04 6157.30 6100.00 3741.09 S 1721.66 E 1819.74 43.28 8114.91 6257.30 6200.00 3808.51 S 1788.43 E 1857.61 37.87 8247.33 6357.30 6300.00 3870.01 S 1849.63 E 1890.03 32.42 8374.12 6457.30 6400.00 3924.69 S 1905.14 E 1916.82 26.79 8496.01 6557.30 6500.00 3973.64 S 1954.68 E 1938.71 21.89 8615.13 6657.30 6600.00 4019.23 S 2000.64 E 1957.83 19.12 8733.31 6757.30 6700.00 4062.69 S 2046.20 E 1976.01 18.18 8850.85 6857.30 6800.00 4105.52 S 2090.70 E 1993.55 17.54 8967.87 6957.30 6900.00 4148.09 S 2134.10 E 2010.57 17.03 9084.75 7057.30 7000.00 4190.98 S 2176.75 E 2027.45 16.87 9201.09 7157.30 7100.00 4233.22 S 2218.60 E 2043.79 16.34 9316.80 7257.30 7200.00 4275.20 S 2258.94 E 2059.50 15.71 9370.00 7303.28 7245.98 4294.50 S 2277.47 E 2066.72 7.22 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS El I:1 I I--I-- I [MOi S E I::IU'I r' E S WEI,I, LOG TRANSMITTAL To: State of Alaska May 21, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPE- 14,' AK-MM-70089 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted LIS Tape with verification listing. API#: 50-029-22734-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I~! I i_1_ I I~1G WELL LOG TRANSMIlWAL To: State of Alaska May 21, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPE-14, AK-MM-70089 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention off Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 Do,..< MPE-14: 2"x 5" MD Resistivity and Gamma Ray Logs: 50-029-22734-00 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22734-00 2"x 5" MD Neutron and Density Logs: 50-029-22734-00 2" x 5" TVD Neutron and Density Logs: 50-029-22734-00 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 563! Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) ,562-7669 (Bus.) (907) 563-3309 (Fax) May 12, 1997 TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. ~_~"..'- ~.O'd .-.. Anchorage, Alaska 99519-6612 ~_~ ' ,-, The following data of the PDC GR for wells MPU E-14 & MPU E-19, Job # 97'182 & 97181, was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 1 CH LIS Tape each 1 Film each 3 Bluelines each State of Alaska Alaska Oil & Gas Conservation Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1 CH LIS Tape each 1 Blueiine each 1 RFolded Sepia each OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 1 CH LIS Tape each 1 Blueline each 1 RFolded Sepia each Sent Certified Mail Z 777 937 571 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 995i-9~661-2"-~':- .... :~ '- Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10967 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 4/24/97 Well Job # Log Description Date BL RF Sepia LIS Tape MPU Eo14 PERFORATION RECORD 9 7041 6 1 1 .... M PU Eol 8 PERFORATION RECORD 9 7041 5 I 1 ,,, MPU E-19 PERFORATION RECORD 9 7041 4 I 1 MPU F-701 UL.~ r.L.. CHEMICALCU'I-rER 970320 I 1 ,., MPU F-73 GR/CCL 97031 3 I 1 MPU F-73 PERFORATING RECORD 9 7031 3 1 1 MPU J-09 t.J~, ~ CHEMICAL CUTTER RECORD 9 7041 7 I 1 MPU J-09 ~. CBL 97041 8 I 1 MPU J-09 PERF RECORD 97041 8 I 1 K-21 PERF RECORD W/GR 97031 6 1 1 MPK-21 CBL 97031 6 I 1 MPK-43A H.P.G. GUNS SHOOTING RECORD 97031 9 I 1 MPK-43A STATIC PRESSURE SURVEY W/CPLT 9 7031 9 I 1 MPK-43A CEIL 97031 9 I 1 MPK-43A H.P.G. GUNS PERFORATION RECORD 9 70321 1 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618o1199 Received b~..~~~'i:/'~~,~'~ ~~ TONY K~/OWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Marc~27, 1997 Tim Schofield Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Milne Point Unit MPE-14 BP Exploration (Alaska) Inc. Permit No. 97-05 Sur Loc 3590'NSL, 19tS'WEL, Sec. 25. T13N, R10E. UM Btmhole Loc 4601'NSL, 4898'WEL, Sec. 31, T13N, R11E, UM Dear Schofield: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated January 15, 1997 are in effect for this revision. Sincerely, Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL REVISED 03/21/97 20 AAC 25.005 ~la. Type of work [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] 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. Plan RTE = 57.3' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028231 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3590' NSL, 1918' WEL, SEC. 25, T13N, R10E Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 4714' NSL, 5010' WEL, SEC. 31, T13N, R11E MPE-14 Attotal depth 9. Approximate spud date Amount $200,000.00 4601' NSL, 4898' WEL, SEC. 31, T13N, R11E 03/31/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025518, 360'I No Close Approach 2560 9358' MD / 7278' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 900' Maximum Hole Angle 66.66° Maximum surface 3325 psig, At total depth (TVD) 7045' / 4030 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 5579' 31' 31' 5610' 4620' 1463' sx PF 'E', 271 sx Class 'G', 89 sx PF 'C' 8-1/2" 7" 26# L-80 Btrc 9328' 30' 30' 9358' 7278' 241 sx Class 'G' ............ i19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner 2 199'/ Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Lance Spencer, 564-5042 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the ~regoing is tr~e and corr~ect to the best of my knowledge Signed -'./~'~ ~/ .~' /~! Tirn Schofieid / t.,,~') '-,""~¢ - // -' Commission Use Only Permit Number 1 APl Number I Approval Date I See cover letter 97-05 I 50-029-22734 I 01/14/97I for other requirements Conditions of Approval: Samples Required [] Yes ~ ~o Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures ~Yes~ No Directional Survey Required ~ Yes [] No Required Working Pressure for DOPE [] 2M; []3M; J~i~L5M; [] 10M; [] 15M Other: by order of Approved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: Lance Spencer 5 6 4-5 042 I Well Name: Well I Type of Well (producer or injector): IMP E-14 I Plan Summary I Kuparuk Producer ISurface Location: Schrader Bluff Target Location Kuparuk Target Location: Bottom Hole Location' 3590' NSL, 1918' WEL, Sec. 25, T13N R10E UM., AK 1598' NSL, 1793' WEL, Sec. 25, T13N R10E UM., AK 4714' NSL, 5010' WEL, Sec. 31, T13N, R11E, UM., AK 4601' NSL, 4898' WEL, Sec. 31, T13N, RllE, UM., AK IAFE Number: 1337054 I I Rig: INabors 27-E Estimated Start Date: I 31 Mar 97I IMD' 19,358' I ITVD' I Operatin~l days to complete: 17,278' Bkb I IKBE: 110 157.3 Well Design (conventional, slimhole, etc.): IMilne Point Ultra Slimhole Longstring 9- 5/8", 40# Surface X 7", 26# Longstring Formation Markers: Formation Tops MD TVD (bkb) Base Permafrost 1 8 1 8 1 8 0 7 8.3 ppg, 780 psi Schrader Target 4 8 5 4 41 3 2 8.4 ppg, 1805 psi NA 5057 4282 8.4 ppg, 1870 psi O~ 5 3 0 7 4 43 2 8.4 ppg, 1936 psi CB, 5 41 1 4 497 8.4 ppg, 1964 psi BaseOB 5460 4527 8.4 ppg, 1977 psi Top HRZ 8 3 3 3 6 3 91 8.6 ppg, 2858 psi Base HRZ 85 0 8 65 41 8.6 ppg, 2925 psi TKLB 8 6 0 6 6 6 2 6 9.6 ppg, 3308 psi TKUP/UD 8785 6781 9.6 ppg, 3385 psi TKUC 8 97 0 6 9 41 11.0 ppg, 3970 psi TKUC1/TARGET 9039 7001 11.0 ppg, 4005 psi TKUB/B8 9085 7041 11.0 ppg, 4028 psi TKB7 91 0 8 7 0 61 11.0 ppg, 4039 psi Total Depth 9358+ 7278+ 11.0 ppg, 4146 psi uas~ng/~uo~ng Fro,( ram: Hole Csg! Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1 # H-40 Weld 80 32/32 11 2/1 I 2 12 1/4" 9-5/8" 40# L-80 btrc 5579 31/31 5610/4620 8- 1/2" 7" 2 6 # L-80 btrc 9328 30/30 9358/7278 The internal yield pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKC1 at + 7045 TVDSS In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of +7045 TVDSS. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 4030 psi is 3325 psi using a 0.1 psi/ft gas gradient, well below the internal yield pressure rating of the 7" casing. MP E-18 (O) Drilling Permit I 3/21/97 Note 1: If the drilling mud weights of 10.5 ppg or higher are required to control gas hydrates immediately contact the Drilling Superintendent before proceeding and drilling ahead through the Schrader Bluff to the planned deep set casing point. Note 2: If necessary due excessive hydrates, the deep set surface casing setting depth will be aborted and casing will be set above the Schrader Bluff. Note 3: In the event that shallow set casing is necessary due to excessive hydrates, the casing program will be modified and an intermediate casing string will be run above the Kuparuk. A Sundry Premit will be requested should this occur. Logging Program: Open Hole Logs: Surface Intermediate Final Cased Hole Logs: Mud Logging MWD Directional from surface to TD. LWD (GR/EWR4/ROP) from surface to TD of surface hole. Real Time N/A MWD Directional from 9-5/8 shoe and LWD 'GR/EWR4/CNP/SLD/ROP) from surface shoe to TD. Real Time N/A Mud Loggers and samples are NOT required. MWD Directional: GR: EWR4: CNP: SLD: ROP: Inclination and Azimuth Gamma Ray Electromagnetic Wave Resistivity 4 (Four Depths of Investigation) Compensated Neutron Porosity Stabilized Litho Density Rate of penetration Mud Program: Special design considerations Special attention should be given to gravel, clay, hydrate, and coal intervals in the surface hole. Running gravel, sticky clays below the permafrost, gas gut mud due to hydrate formation, excessive fill on connections, tight coal sections and stuck pipe have been encountered in previous surface holes on E-Pad. Prior to spudding a complete review of the E-Pad drilling hazards is required. Preventative measures such as more frequent short trips, viscosity and mud weight control, iow mud temperatures, controlled drilling rates, and lower flow rates should be employed to mitigate problems and lost time in the surface hole. HYDRATES Hydrates are present on E-Pad and must be managed safely. It is necessary to be knowledgable of the safeguards and measures required to safely handle the hydrates that will be encountered while drilling on E-Pad. MP E-18 (O) Drilling Permit 2 3/21/97 Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 100 15 8 10 9 8 to to to to to to to 10.2 or 50 35 15 30 10 15 less Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 40 1 0 3 7 8.5 6 - 8 to to to to to to to 1 1.5 50 1 5 1 0 20 9.5 4- 5 Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: KOP: 900' Maximum Hole Angle: 51.94° Close Approach Well: (No Shut In Wells) All wells may remain flowing while drilling E-14. Disposal: No "Drilling Wastes" will be injected or disposed into E-18 while drilling this well. Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A or other approved site for disposal. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (5 6 4- 4305) with request. Fluids Handling: All drilling wastes will be hauled off and disposed of in accordance with Pertinent rules and regulations. GENERAL DISCUSSION Well Objective: MPE-14 is planned as a Kuparuk River C1 and B7 Sand producer with the Schrader Bluff target as a potential secondary objective. The S-shaped well profile will intersect both target objectives. The surface casing will be deep set below the Schrader Bluff at 5,610'md (4620' bkb) to isolate this interval from the Kuparuk interval which could be abnormally pressured by area injection. The surface casing will be deep set below the Schrader Bluff at 5,610'md (4620' bkb) to isolate. M PE-1 4 will be drilled to a TD of 9,358' md with a horizontal displacement of 4,840' Geology E-14 (M) is the first Kuparuk well to penetrate this particular fault block. Displacement along the eastern fault is large enough that cross-fault communication is not expected. Offset along the large northern fault juxtaposes Cl and B7 sands, increasing the odds of communication with E-7, but the graben separating E-7 and.E-14 should hinder communication. The Kuparuk Cabd B sands should be 100% oil bearing. The OWC in the MPE-14, (O) fault block is expected at 7045' TVDss which is in the Kuparuk B shale. In the Kuparuk, E-14 is located 1980' from WAG injector E-7 and is within the Kuparuk PA and MPU. It is possible the E-14 could communicate with the E-7/E-6/B-21 fault block and overpressure the formation. MP E-18 (O) Drilling Permit 3 3/21/97 DRILLING HAZARDS AND RISKS SUMMARY: Hydrates are likely to be encountered while drilling E-14. Hydrates are since most often seen when drilling southeasterly and could to be a factor while drilling this well. Formation pressures are expected to be above normal in the Kuparuk due to injection in the E-7/E-6/B-21 fault block. The deep set surface casing design is recommended to alleviate potential problems due to nearby WAG injection. The well profile has been designed to avoid close approaches and no wells will be shut in while drilling this. Lost circulation and stuck pipe have occurred but not recently and are not expected. GAS HYDRATES Hydrate sections may be encountered on E-Pad while drilling the surface hole. Mud treatments with Lecithin have minimized the adverse effects of hydrates but it's use is still not proven so its use should be carefully monitored. In spite of the apparent success's of the Lecithin treatments extreme caution is still advised. Severely gas cut mud, excessive connection gas, flow on connections and other problems can occur while during the surface hole on E-Pad and are directly attributed to gas hydrates. In addition problems can develop as a result of measures designed to lessen to effects gas. It is important to recognize what problems might develop while fighting gas hydrates and have plans in place to minimize them. Plans should be made in advance prior to spudding the surface hole to mitigate to potential risks and minimize the nonproductive time involved in managing hydrates. Some measures which are necessary to lessen to effects of gas hydrates include: 1. Increased mud weights; 2. Low drilling fluid temperatures; 3. Reduced ROP's for control drill rates; 4. Controlled circulating and drilling fluid rates; 5. Utilization of Lecithin Note: If necessary, the surface casing setting depth will be adjusted and will be set above the Schrader Bluff if gas hydrates are severe. If the drilling mud weights of 10.5 ppg or higher are required to control gas hydrates immediately contact the Drilling Superintendent before drilling ahead into the Schrader Bluff. Close Approaches There are no close approaches associated with the drilling of MP E-14, however, tolerance lines should be carefully monitored and deviations from the proposed wellpath minimized. Water, Gas and WAG Injection In the Kuparuk, E-14 is located 1980' from WAG injector E-7. It is possible that E-14 could communicate with the E-7/E-6/B-21 fault block and the fault block could be overpressured the Kuparuk formation. Formation pressures are expected to be above normal at a 11.0 ppg pore pressure in the Kuparuk due to injection in the E-7/E-6/B-21 fault block. The deep set surface casing design is recommended to alleviate potential problems due to nearby WAG injection and eliminate the possibility of breaking down the Ugnu or Schrader Bluff formations with the mud weights necessary to drill the Kuparuk interval. Annular Injection Currently annular injection is not permitted on E-Pad. Lost Circulation: Lost circulation has been most prevalent while running casing and cementing in the surface as well as production hole. Losses are extremely probable while cementing the long string in wells with shallow set surface casing. Losses have been experienced while drilling the 12-1/4" surface and while circulating to condition mud before, while and after running surface casing. Major losses have also occured while cementing the production casing. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. The losses normally occur in the Ugnu and Schrader Bluff with the shallow set surface casing design especially while cementing the 7" csg. MP E-18 (O) Drilling Permit 4 3/21/97 ~"'"~ OJi; ~''~ .... ¢~''~,~, '"" ~' ' Stuck Pipe Potential: Running gravels, sticky clays, tight coal sections, packing off, bridging, and stuck pipe have occured while drilling the 12 1-4' surface holes on E-Pad. Excessive amounts of reaming have been required to condition the hole to run surface casing after drilling the surface hole. While running 9-5/8" casing the following problems were experienced: hole packing off; tight hole and bridging, and the 9 - 5 / 8" casing has been stuck. While drilling the surface hole additional time has beeen spent reaming and conditioning the hole prior to cementing because of tight hole. These problems in some instances were greatly exaggerated because of measures taken to manage the gas hydrate problems. While drilling the production section increased torque and drag have been experienced after drilling into Kuparuk. This is a common occurance has often causes difficulties, so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Attention should be given to The Ugnu and Schrader Bluff formations to reduce the chances of differential sticking in these formations with higher muds weights needed to keep the HRZ and Kuparuk formations in balance. Differential sticking is most likely while running the production string. Formation Pressure: KUPARUK SAND 7044' TVDss 3600 PSI 9.8 PPG EMW The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKB7 at _+ 7045 TVDSS. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of +7045 TVDSS. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 4030 psi is 3325 psi. The maximum expected pore pressure for this well is 11.0 ppg EMW (4,030 psi @ 7,045' TVDss). There has been injection in this region, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point E-Pad Data Sheet prepared by Pete Van Dusen for information on E pad and review recent wells drilled on E Pad. MP E-18 (O) Drilling Permit 5 3/21/97 MP E-14 Kuparuk Producer Proposed Summary of Operations Review Pre-Spud Checklist RP-Surface Hole VI.0 pages 1-3. prior to spud. , Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5A Wellhead on conductor as well as a nipple to aid in performing potential wellhead stability cement job. 2. Prepare location for rig move. 3. MIRU Nabors 27E drilling rig. . NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisor. Build Spud Mud. . Drill a 12-1/4" surface hole as per directional plan. Advise Rig Team to proceed with Extreme Caution prior to and while drilling the hydrate interval. Run Directional MWD from surface to 12-1/4" TD. 6. Run 9-5/8" casing. Space out ES Type H Cementer to 1300'. . Perform Two Stage cement. Complete the surface casing cementing check list. 8. ND 20" Diverter, NU and Test 13-5/8" BOP . MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/EWR4/CNP/SDL). RIH, Drill out Float Equipment and 20' of new formation. Perform Leak Off Test as per Revised Recommended Practices Manual. Record pressure versus cumulative volume for LOT test for the well file. 10. Drill 8.5" hole to TD as per directional plan. Make sure sufficient footage is drilled to provide 150' of production rat hole between the base of the Kuparuk B sand and PBTD before running the 7" casing. 11. Run and Cement 7" Casing. Insure that a short joint is run in the 7" casing approximately three joints above the top of the Kuparuk. Displace cement with 8.4 ppg source water and enough diesel to cover from the base of permafrost to surface (+- 2 1 0 0' MD). 1 2. Test casing to 4000 psig. 13. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. 1 4. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. MP E-18 (O) Drilling Permit 6 3/21/97 MP E-14 (Kup) 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON Casing Size: 9-5/8" 40# L-80 Circ. Temp 60 deg F at 2840' TVDSS. TWO STAGE CEMENT PROGRAM: Refer to the Two Stage Cementing Procedure The objective of the Surface Cement is to insure that cement is circulated to surface. Second stage lead cement shall be pumped until such time as cement is circulated to surface before swiching to second stage tail. Arrangements should be made to insure that sufficient cement is available so that continuous cementing can occur uninterrupted until cement is circulated to surface. This volume will likely exceed the annular capacity and the 250% estimated excess. Note: 1. The ES Cementer is located at 2025' md (2000 TVDbkb). 2. RECIPROCATION of the CASING STRING is required WHILE CEMENTING. 3. Lead and Tail slurries are pumped in the first stage. 4. Lead and Tail slurries are also pumped in the second stage. 5. Dye shall be introduced into the weighted spacer before the first stage and into the water before the second stage in order to obtain an estimate of annular capacity to that additional cement can supplied if required and adequate excess has been pumped. 6. Once an adequate volume of cement has been circulated to surface immediately begin displacement. 7. The WELLHEAD STABILITY CEMENT will be pumped only if the cement top falls below surface after the pumps are shut down. 8. Utilize large flow area float shoe. 9. Use weighted spacer before firet stage lead slurry:(1 ppg higher than current mud weight). 1 0. Add dye in the spacer to assist in determining the annular volume. 1 1.Incorporate "Celloflakes" into ONLY the First Stage cement lead and tail slurries. Caution: 1. MAKE SURE THAT THE SECOND STAGE LEAD CEMENT IS CIRCULATED TO SURFACE BEFORE PUMPING SECND STAGE TAIL. 2. Do not incorporate FLOCELE "Cello-Flakes" in the Second stage cement slurries. 3. Make preparations to handle cement to surface on the first stage circulation. 4. Make preparations to handle cement to surface on the second stage circulation. MP E-18 (O) Drilling Permit 7 3/21/97 First Stage: SPACER: 70 bbls NSCI weight 1 ppg higher than current mud weight. 1st LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: 0.25#/sk Flocele WEIGHT: 12.0 ppg APPROX NO SACKS: 545 YIELD:2.17 ft3/sx MIX WATER: 11.55 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. 1st TAIL CEMENT TYPE: Premium G ADDITIVES: 2.0% CaCI2 +.15#/sk Flocele WEIGHT: APPROX NO. SACKS: 271 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FLUID LOSS: 100-150 cc FREEWATER: 0 Second Stage. SPACER: 75 bbls Water 2nd LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: None WEIGHT: APPROX NO SACKS: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.55 gal/sk 9 1 8 THICKENING TIME: Greater than 4 hrs at 50° F. 2nd TAIL CEMENT TYPE: Permafrost C SPACER: 75 bbls Water ADDITIVES: None WEIGHT: APPROX NO SACKS: 15.6 ppg YIELD: 0.95 ft3/sx MIX WATER: 3.68 gal/sk 8 9 THICKENING TIME: Greater than 4 hrs at 50° F. Wellhead Stability Cement CEMENT TYPE: Permafrost E ADDITIVES: None WEIGHT: 12.0 ppg APPROX NO SACKS: 150 MP E-18 (O) Drilling Permit YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 3/21/97 Centralizer Placement: 1. Install one(l) Straight Blade Rigid Centralizers per joint of 9-5/8" casing on bottom 10 joints of casing (required). 2. Install one(l) Straight Blade Rigid Centralizers per joint of 9-5/8" casing on from 2200-2700 feet joints of casing (required).Place all centralizers in middle of joints using stop collars. Surface Cement Volumes: 1. First Stage Lead Cement Volume - Interval 2025-4930' md The estimated first stage lead cement volume is equivalent to the annular volume calculated from the ES Cementer @ 2025' md to 4930' md which is 100' TVD above the Schrader NA Top at 5077' md+ 30% EXCESS. 2. First StageTail Cement Volume - Interval 4930-5610' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from 5610 which is 100' TVD above the Schrader NA Top @ 5077' md to surface TD at 5610' md plus 30% Excess + the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md 9-5/8",40#casing for float joints. 3. Second Stage Lead Cement Volume = Interval 0-1818' md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the Base of the Permafrost located @ 1818' MD (1807' tvd) to the surface plus 250% excess. 4. Second Stage Tail Cement Volume - Interval 1818 - 2025' md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer @2025' MD (2000' tvd) to the Base of the Permafrost located @ 1818' md plus 250% excess. 5. The estimated Wellhead stability Cement Volume is 150 sacks. It will be pumped if necessary to provide support to the wellhead. Other Considerations: 1. Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 1 2 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. 2. After MPK-25 was suspended following problems with the surface casing job. The importance of getting a sucessful cement job on the suface job cannot be stressed enough. There are changes to the spacer, cement volumes and centralizer program on this well. If the cement falls back, do a wellhead stability cement job. MP E-18 (O) Drilling Permit 9 3/21/97 MP E-14 Kuparuk Producer 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON Cement Program for Kuparuk Production Interval, Casing Size' 7" 26# L-80 CIRC. TEMP: 140°F BHST 170° F at 7040' TVDSS. SINGLE STAGE CEMENT JOB: Cement from TD to 1000' above KUPARUK TKUP/UD. SPACERs: 20 bbls fresh water and 70 bbls NSCI mixed per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX # SACKS: FLUID LOSS: 0.2% CFR-3, 0.1% HR-5, 0.45% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk 24I THICKENING TIME' 3 1/2 - 4 1/2 hrs @ 140° F < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: . . 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the from 120' below to 1 20' above any potential hydrocarbon bearing sands. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. CEMENT VOLUME' Interval 7,785-9,358' md , Single stage cement volume is calculated to cover 1000 FT MD above the highest potential KUPARUK(TKUPD) production sand + 30% excess. OTHER CONSIDERATIONS: . Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary, MP E-18 (©) Drilling Permit 10 3/21/97 Anadri~i Schlumkerger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-1622 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : MPE-14 (P15) Field ........ : Milne Point, E-Pad Computasion~.: Minimum Curvature Units ........ : FEET Surface Lat..: 70.45441997 N Surface Long.: 149.43507237 W Legal Description Surface ...... : 3590 FSL i918 FEL Kuparuk Tgt..: 4714 FSL 5010 FEL schrader Tgt.: 1598 FSL 1793 FEL BHL .......... : 4601 ~'SL 4898 FEL LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord S25 T13N R10EUM 569228.18 .6016128.05 S31 T13N R11E UM 571435.00 6011993.00 S25 T13N R10E UM 569372.00 6014138.00 S31 T13N R11E UM 571548.52 6011880.78 PROPOSED WELL PROFILE STATION MEASURED iNCLN IDENTIFICATION DEPTH ANGLE ICB 0.00 0.00 KOP / 1/100 BUILD 900.00 0.00 1000.00 1.00 BUILD 1.5/100 1075.00 1.75 1100.00 2.13 DIRECTION VERTICAL-DEPTHS SECTION AZIMUTH TVD SUB-SEA DEPART ~=mm~mmm mmmmmmm= 0.00 0.00 -57.30 0.00 179.06 900.00 842.70 -0.00 179.06 999.99 942.69 0.78 179.06 1074.97 1017.67 2.39 179.06 1099.96 1042.66 3.14 Prepared ..... : 19 Mar 1997 Vert sect az.: 152.44 KB elevation.: S7.30 ft Magnetic Dcln: +28.163 (E) Scale Factor.: 0.99990544 Convergence,.: +0.53237598 ANADRILL AKA-DPC APPROV'. D FOR PER. M, iTTiNG ONhY PLAN COORDINATES-FROM ALASKA Zone 4 TOOL DL/ WELLHEAD X Y FACE 100 ======mmmm mmm------==== : 0.00 N 0.00 E 569228.18 6016128.05 179R 0.00 0.00 N 0.00 E 569228.18 6016128.05 179R 0.00 0.87 S 0.01 E 569228.20 6016127.18 179R 1.00 2.67 S 0.04 E 569228.25 6016125.38 179R 1.00 3.52 S 0.06 E 569228.27 6016124.53 179R 1.50 1200.00 3.63 BUILD 2/100 1275.00 4.75 1300.00 5.25 1400.00 7.25 BUILD 2.5/100 1500.00 9.25 179.06 1199.83 1142.53 7.63 8.53 S 0.14 E 569228.40 6016119.52 179R 1.50 179.06 1274.63 1217.33 12.53 14.01 S 0.23 E 569228.54 6016114.05 179R 1.50 179,06 1299.53 1242.23 14.47 16.19 S 0.27 E 569228.60 6016111.87 MS 2.00 179.06 1398.93 1341.63 24.21 27.07 S 0.44 E 569228.88 6016100.99 HS 2.00 179.06 1497.89 1440.59 37.03 41.42 S 0.68 E 569229.25 6016086.64 HS 2.00 1600.00 11.75 179.06 1596.21 1538.91 53.33 59.64 S 0.98 E 569229.71 6016068.43 HS 2.50 (Anadrill (c)97 MPE14P15 3.0C 2:48 PM P) ~0 0 0 STATION IDENTIFICATION END 2.5/100 BUILD BASE PERMAFROST CURVE 2.5/100 END 2.5/100 CURVE CURVE 2.5/100 END 2.5/100 CURVE MEASURED INCLN DEPTH ANGLE 1700.00 14.25 1771.13 16.03 1817.95 16.03 1833.56 16,03 1900.00 17.69 2000.00 20219 2100.00 22.69 2200.00 25,19 2300.00 27.69 2400.00 30.19 2500.00 32.69 2600.00 35.19 2700.00 37.69 2800,00 40.19 2900.00 42.69 2962.40 44.25 4085.20 44.25 4100.00 44,25 4200.00 44.38 4300.00 44.61 4400.00 44.95 4500.00 45.40 4600.00 45.96 4500.00 46.61 4754.11 47.00 SC"HRA2DER BLUFF TGT 4854.11 47.00 START CURVE 3.0/100 4854.11 47.00 4900.00 47.23 (~nadrill (c)97 MPE14P15 3.0C 2:48 PM P) PROPOSED WELL PROFILE DIRECTION VERTICAL-DEPTHS AZI~K/TH TVD SUB-SEA ======== ~m~ 179.06 1693.64 1636,34 179.06 1762.30 1705.00 179.06 1807.30 1750.00 179.06 1822.30 1765.00 179.21 1885.88 1828.58 179.40 1980.46 1923.16 179.55 2073,54 2016.24 179.67 2164.93 2107.63 179.77 2254.47 2197.17 179.85 2341.97 2284.67 179.92 2427.29 2369.99 179.99 2510.25 2452.95 180.04 2590.70 2533.40 180.09 2668.48 2611.18 180.14 2743.44 2686,14 SECTION DEPART 73.44 90.04 101.60 105.45 122.67 151,62 184,17 220.26 259.83 302.80 349.08 398.59 451.23 506.91 565.51 180.16 2788.73 2731.43 603.51 180.16 3593.06 3535,76 1297.02 179.63 3603.66 3546,36 1306.18 176.06 3675.22 3617.92 1369.27 172.51 3746.57 3689.27 1434.30 168.99 3817.56 3760.26 1501.16 165.52 3888.06 3830.76 1569.71 162.12 3957.94 3900.64 1639.83 158.78 4027.06 3969.76 1711.38 157.00 4064,10 4006.80 1750.65 19 Mar 1997 COORDINATES-FROM ALASKA Zone 4 TOOL DL/ WELLHEAD X Y FACE 100 ...... ; mmmm =::: 82.13 S 1.35 E 569230.29 6016045.95 HS 2.50 100.70 S 1.65 E 569230.77 6016027.38 RS 2.50 113.63 S 1.87 E 569231.10 6016014.46 RS 0.00 117.94 S 1.94 E 569231.21 6016010.15 2R 0.00 137.20 S 2.23 E 569231.68 6015990.89 1R 2.50 169.65 S 2.62 E 569232.37 6015958.4'5 IR 2,50 206.20 S 2.95 E 569233.04 6015921,91 iR 2.50 246.77 S 3,22 E 569233.70 6015881.35 1R 2.50 291.28 S 3.44 E 569234.33 6015836.84 1R 2.50 339.66 S 3.60 E 569234.93 6015788.47 1R 2.50 391.81 S 3.70 E 569235.52 6015736.33 1R 2,50 447.63 S 3.74 E 569236.08 6015680.51 1R 2.50 507.02 S 3.73 E 569236.62 6015621.13 1R 2,50 569.86 S 3.65 E 569237.13 6015558.30 1R 2.50 636.03 S 3.52 E 569237.61 6015492.14 1R 2.50 678.96 S 3.40 E 569237.B9 6015449.22 HS 2.50 1462.37 S 1,17 E 569242.94 6014665.90 89L 0.00 1472,69 S 1.19 E 569243.05 6014655.57 88L 2.50 1542.48 S 3.82 E 569246.33 6014585.82 86L 2.50 1612.19 S 10.80 E 569253.96 6014516.18 83L 2.50 1681.69 S 22.13 E 569265.93 6014446.79 81L 2.50 1750.85 S 37.77 E 569282.22 6014377.79 78L 2.50 1819.54 S 57.71 E 569302.79 6014309.30 76L 2.50 1887.62 S 81.91 E 569327.61 6014241.45 74L 2,50 1924.17 S 96.$6 E 569342.80 6014205,05 MS 2.50 157.00 4132.30 40?$.00 1B23.56 1991.49 S 157.00 4132.30 4075.00 1823.56 1991.49 S 155.15 4163.53 4106.23 1857.11 2022.22 S 125.34 E 569372.00 6014138.00 81L 0.00 125.34 E 569372.00 6014138.00 81L 0.00 138.97 E 56938.s.._~_2._~_p.zi_%qT.:.~3_ .. Ao_p..L- o_~o ..... ANADRILL AKA-DPC APPROV£D FOR PERMITTING ONLY DI A kl ~ 0 0 ',4 , 0 MFE- '4 :--15 NA STATION MEASURED INCLN IDENTIFICATION DEPTH ANGLE 5000.00 47.85 5076.78 48.41 5100.00 48.60 5200.00 49.47 5300.00 50.47 0A 530?.40 50.55 5400.00 51.58 OB 5410.95 51.71 END 3.0/100 5430.31 51.94 OB BlUE 5459.56 51.94 9-5/8" CASING POINT DROP 2,5/100 5609.56 51,94 7561,44 51.94 7600.00 50.97 7700.00 48.47 7800.00 45,97 7900.00 43.47 8000.00 40.97 8100.00 38.47 8200.00 35.97 8300.00 33.47 TOP HRZ 8333.10 32.65 8400.00 39.97 END 2.5/100 DROP 8438.91 30.00 BASE HRZ 8507.75 30.00 TKLB 8605.90 30.00 TKUP 8784.88 30.00 TKUC 8969.63 30.00 KUPARUK TARGET 9038.91 30.00 (Anadrill (c)97 MPE14P15 3.0C 2:48 PM P) PROPOSED WELL PROFILE ========= ============m==== ====: -_ DIRECTION VERTICAL-DEPTHS SECTION AZIMUTH TVD SUB-SEA DEPART 151.17 4231.05 4173.75 1930.85 148.17 4282.30 4225,00 1987.94 147.27 4297.69 4248,39 2005.28 143.47 4363.26 4305.96 2080.18 139.78 4427.59 4370.29 2155.'36 139.51 4432.30 4375.00 2160,94 136,19 4490,50 ~433,20 2230.62 135.81 4497.30 4440.00 2238,85 135.13 4509.27 4451.97 2253.41 135.13 4527.30 4470.00 2275.39 135.13 4619.78 4562,48 2388.14 135.13 5823.17 5765.87 3855.28 135.13 5847.20 5789.90 3884.07 135.13 5911.84 5854.54 3956,90 135.13 5979,75 5922.45 4026.97 135,13 6050.80 5993.50 4094.15 135.13 6124.84 6067.54 4158.30 135.13 6201.75 6144.45 4219.30 135,13 6281.38 6224,08 4277.05 135.13 6363.56 6306.26 4331,43 135.13 639i.30 6334.00 4348.66 135.13 6448.15 6390.85 4382,33 135.13 6481.68 6424.38 4401.17 135,13 6541.30 6484.00 4434.03 135.13 6626.30 6569.00 4480.88 135.13 6781.30 6724.00 4566.32 135.13 6941.30 6884.00 4654.51 135.13 7001.30 6944.00 4687.58 COORDINATES-FROM WELLHEAD 2088,02 S 172..28 2137.35 S 201.15 2152.05 S 210.44 2214.16 s 253~34 2274.16 s 300.88 ;~LASKA Zone 4 ' TOOL X Y FACE DL/ 100 569419,84 6014041.92 77L 3.00 569449.16 6013992.86 ?SL 3.00 569458.58 6013978~25 74L 3,00 569502.06 6013916.55 72L 3,00 569550.14 6013857.00 69L 3.00 2278.51 S 304.58 E 569553.88 6013852.69 69L 3.00 233i,88 S 352.91 E 569602.70 6013799.77 67L 3.00 2338.06 S 358.87 E 569608.73 6013793.64 67L 3.00 2348.9L S 369.55 E 569619.50 6013782.89 HS 3.00 2365.23 S 385.79 E 569635.89 6013766.73 HS 0.00 2448.93 S 469.11 E 569719.98 6013683.82 3538,'O6 S 1553.31 E 570814.14 6012604.91 3559.43 S 1574,59 E 570835.62 6012583,74 3613.50 S i628.41 E 570889,93'6'012530.18 3665.51 S 1680.19 E 570942.19 6012478.65 HS 0.00 LS 0.00 LS 2,50 LS 2.50 LS 2.50 3715,3S S 1729.83 E 570992.29 6012429.25 LS 2.50 3?63.00 S 1777.23 E 571040.13 6012382.08 LS 2.50 3808.29 S 1822,32 E 571085.63 6012337.22 LS 2.50 3851.16 S 1864.99 E 591128.69 6012294.75 LS 2.50 3891.52 S 1905.17 E 571169.24 6012254.76 LS 2.50 3904.32 S 1917.91 E 571182.10 6012242.09 LS 2.50 3929,31 S 1942,79 E 571207.20 6012217.33 LS 2.50 3943.30 S 1956.71 E 571221.26 6012203.47 HS 2.50 3967.69 S 1981.00 E 571245,77 6012179.31 HS 0.00 4002.47 S 2015.62 E 571280.71 6012144.85 ~S 0.00 4065.89 S 2078.75 E 571344.42 6012082.03 HS 0.00 4131.36 S 2143,93 E 571410.19 6012017.17 HS 0.00 4155.91 S 2168.36 E 571434,86 6011992.86 HS 0,00 ANADRILL ....... AKA-DPC~ APPROVED FOR PERMITTING ONLY n~ · ~, ~ I~-. , PROPOSED WELL PROFILE STATION MEASURED INCLN DIRECTION IDENTIFICATION DEPTH ANGLE AZIMUTH TKC1 9038.91 30.00' 135.13 TKUB 9085,10 30.00 135.13 TKB7 9108.19 30.00 135.13 TKB6 9137.06 30.00 135.13 EST. OWC 9155.54 30.00 135.13 TKB5 9155.54 30.00 TKB4 9195.95 3.0.00 TKB3 9224.82 30.00 TKB2 9253.69 30.00 TKB1 9282.55 30.00 17 Mar 1997 Pa~e 4 TKUA 9317.20 30.00 7" CASING POINT 9358.19 30.00 TD 9358.19 30.00 7001.30 7041.30 7061.30 7086.30 7102.30 VERTICAL-DEPTHS SECTION COORDINATES-FROM ALASKA Zone 4 TOOL DL/ TVD SUB-SEA DEPART WELLHEAD X Y FACE 100 6944.00 4687.58 4155.91 S 2168.36 E 571434.86 6011992.86 HS 0.00 6984.'00 4709.63 4172.28 S 2184.66 E .571451.30 '6011976.64 HS 0.00 7004.00 4720.65 4180.46 S 2192.80 E 571459.52 6011968.53 HS 0.00 7029.00 4734.43 4190.69 S 2202.99 E 571469.80 6011958.40 HS 0.00 7045.00 4743.25 4197.24 $ 2209.50 E 571476.37 6011951.92 HS 0.00 135.13 135.13 135.13 135.13 135.13 7102.30 7045.00 4743.25 4197.24 S 2209.50 E 571476.37 6011951.92 HS O.00 7137.30 7080.00 4762.54 4211.56 S 2223.76 E 571490.76 6011937.73 HS 0.00 7162.30 7105.00 4776.32 4221.79 S 2233.94 E 571501.04 6011927.60 HS 0.00 7187.30 7130.00 4790.10 4232.O2 S 22A4.'13 E 571511.31 6011917.46 HS 0.00 7212.30 7155.00 4803.88 4242.25 S 2254.31 E 571521.59 6011907.33 HS O.O0 135.13 135.13 135.13 7242.30 7185.00 4820.42 4254.52 S 2266.53 E 571533.92 6011895.17 HS 0.00 7277.81 7220.51 4839.99 42~9.05 S 2280.99 E 571548.52 6011880.78 0.00 7277.81' 7220.51 4839.99 4269.0~ S 2280.99 E 571548.52 6011880.78 0.00 ANADRILL AKA:DPC"I 0 0 (Anadrill (c)97 MPE14P15 3.0C 2:48 PM P} Mar-lg-g7 02:50P AnadF~-~1l DPC 907 .... 44 2160 P.06 SHARED SERVICES DRILLING MPE- APPROVED VERTICAL SECTION VIEW FOA PERMiTTiNG Section at: :~5~.44 ONLY ~VD s~.~. · ~ ~nc,: ~00o ~ ~ ~ ~, Ce~ Scale.' ~ inch: ~000 feet I ~1~ .~ Drawn · lg Nar ~997 ; ~nadrJ ] ] Schlumberger B ~arker Identification MO BKB SEC~N INCLN .... C - - . A) KB 0 0 0 0.00 O __ ~ B) KOP / ~/tO0 BUILD 900 900 -0 0.00 · C) BUILD 1.5/~00 ~075 ~075 2 ~ . 75 ....... E- .... ~ ..... .0) BUILD 2/100 ~275 1275 13 4.75 E) BUILD 2.5/~00 ~500 1498 37 9.25 .... ~' ~~r'~¢ F) END 2.5/100 BUILD ~77~ 1762 90 16.03 . 6) CURVE 2.5/~00 ~834 182~ ~05 ~6.03 ' i - H) END 2.5/100 CURVE 2962 2789 604 44.25 i I) CURVE 2.5/~00 ~085 3593 1297 4~.25 J) ENO 2.5/100 CURVE 4754 4064 175~ 47.00 .................. K) SCHRADER BLUFF TGT 4854 4~32 1824 47.00 L) START CURVE 3.0/100 4854 4132 1824 47.00 ' ~ ~ ' -M) ENO 3.0/100 5430 4509 2253 51.94 H~ N) '9-5/8' CASING POINT 56~0 4620 2388 5].94 , O) OROP 2.5/~00 7561 5823 3855 5~.94 P) END 2.5/100 DROP 8439 6482 440] 30.00 O) KUPARUK TARGET 9039 700~ 4688 30.00 ..................... R) 7' CASING POINT 9358 7278 4840 30.00 S) ~D 9358 7278 4840 30. O0 , - Schrader Tgt (R~us ~00 feet ) ~~: ~r r~: - - - ' - ........ : ~r~[ r .... _ ........................... :' .. ,. i ~ ............ ~.. .~.. , .......... . ,. 'P-~- ~c ,.-'" ' .... . ....... ...... 0 500 tO00 1500 2000 2500 3000 3500 .4000 Sect ion Departure [Anadrill (c)97 I,IPEt4Pi5 3.0C 2:~0 PN' P) 4500 5000 5500 6000 6500 Marr19-97 02:51P Anadr-'~l DPC .907 '- ¢4 2160 P.07 SHARED S.E, RV'ICES DRILL,lNG i · ' I , MPE-14 (P15) ~oo ~ I ' VERTICAL SECTION VIEW 6~]]°oi --~"--': ................. ! .................. ]~-'--~ ~-'---~-~i! SectTVD Scale.'~°n at: ' !152'~nch44 = 100 feet ' ~ Dep Scale.' ~ inch = ~00 feet 66 O. , _ 6700 , Marker Identification HO BKB SECTN INCLN A) KUPARUK TARGET §039 700~ 46BB 30.00 : B) 7 · CASING POINT 9358 7278 4840 30.00 C) TD 9358 7278 4840 30 O0 6750~ ................ , ANADRILL AKA-DPC '.~tu¢. mc,, ...... ' " APPROVED 6800-- , . F ONLY 6goo6"S° .......... I ~5o- :~-~: .............. ~. . k. . ............ .... ; x, · ' i ,ooo. _,,~_,~.. ......... - i:~::}i}::i]~.} 'i!( ' ,I 7o5o-'~K~-'.-~ .......... ' ..... ' .......... -~r - -~ - ro~ ............. 7~00' '~f~ ~w~"~ no"~ ....... · "r~'~' ' 7t50- -. ................. - 'm~ - I "1'1~' - ~'~83 i 7200 , -~. - ~ .................................... L ......... i ..... j ~5o-:~ur...-..r~ ..... - - - ~ ............... : 7300 . B - J , 73~0 ...... 4400 4450 4500 4550 4600 4650 4700 4750 4800 4850 4900 4950 5000 5050 5~00 Section DepartUre M~,-r~,-19-97 02:51P Anadm4.11 DPC 90 7- ~44 2160 P.08 SHARED SERVICES Marker Identification A) KB B) KOP / 1/100 BUILD C) BUILD 1.5/100 D) BUILD 2/100 E) BUILD 2.5/100 F) END 2.5/100 BUILD G) CURVE 2.5/100 H) END 2.5/100 CURVE I) CURVE 2.5/100 J) END 2.5/100 CURVE K) SCHRADER BLUFF 'TGT L). START CURVE'3.0/JOo M) END 3.0/100 ' N) 9-5/8' CASING POINl O) DROP 2.5/100 P) END 2.5/100 DROP POINT ' 0 ON 900 0 N t075 3 S 1275 14 S 1500 41S 1771 tO1S 1834 118 S 2962 679 S 4085 1462 S 4754 t924 S 4854 1991S 4854 1991S 5430 2349 S 56J0 2449 S 7561 3538 S 8439 3943 S E/W 1E 2E 2E 3E 1E 97 E 125E 125E 370 E 469 E 1553 E 1957 E ~ E DRILI_'i'NG i i ! i MPE-14 (P15) PLAN VIEW CLOSURE · 4840 feet, at Azimuth 151.88 DECLINATION.' +28.~63 (E) SCALE · ~ inch : 800 feet DRAWN · ~9 Mar 1997 AnadrJ ]] Schlumberger i 2800 2400 2000 {Anad¢i]l (c)g7 I,~o~14P~5 3.OC 2:53 PH 1600 1200 800 400 0 400 <- WEST' EAST -> 800 1200 1600 2000 2400 2800 TONY KNOWLES, GOVERNOR ALASI~& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Januar)' 15, 1997 Tim Schoficld Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milnc Point Unit MP~-I4 BP Exploration (Alaska) Inc. Permit No.: 97-05 Sur. Loc.: 3590'NSL. 1918'WEL. Scc. 25. TI3N. RIOE. UM Btmholc Loc: 5074'NSL, 3833'WEL, Sec. 36. TI3N, RIOE. UM Dear Mr. Schoficld: Enclosed is the approved application for permit to drill thc above rcfercnccd v¥cll. The permit to drill docs not exempt you from obtaining additional pcrrnits rcquired by law from other governmental agcncics; and docs not authorize conducting drilling operations until all other required permitting dctcnninations are made. Bloxvout prcvcntion cquipmcnt (BOPE) must be tcstcd in accordancc with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of thc BOPE test performed bcforc drilling below the surf'acc casing shoe must be givcn so that a rcprcscntativc of thc Commission mav witness the test. Noticc may bc given by contacting thc Commission pctrolcum ficld inspcctor on thc North Slope pager at 659-3607. :hli2a~~- ~MISSION dltTenclosures cc: Department of Fish & Game. I [abitat Section w/o cncl. Department of F.m-inomrncnt (?tmscm'amm w o cncl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil .la. Typeofwork []Re-Entry []Deepenl nService []Development Gas []Single Zone []Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 53.8' Milne Point Unit / Schrader Bluff 3. Address i6. Property Designation ------ " ' P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025518 4. Location of well at surface 17. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3590' NSL, 1918' WEL, SEC. 25, T13N, R10E Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 48' NSL, 3705' WEL, SEC. 25, T13N, R10E MPE-14 At total depth 9. Approximate spud date Amount $200,000.00 5074' NSL, 3833' WEL, SEC. 36, T13N, R10E 04/15/97 112. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TV•) ADL 028231, 3833'I No Close Approach 2560 6651' MD / 4500' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' Maximum Hole Angle 66.66° Maximum surface 1419 psig, Attotal depth (TV•) 4157' / 1835 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.4# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 8-1/2" 7" 26# L-80 NSCC 6620' 31' 31' 6651' 4500' 699 sx PF 'E', 97 SX 'G', 33 SX PF 'C', 150 SX PF 'E' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production ~J'"~ Liner Perforation depth: measured A~8,0~l &GasCOtlS, 60fllm~'$~fi true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Tim Schofie/d, 564-5242 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing is true and c¢)r, rect to the best of my knowledge Tim Schofield "~__~ __~_ . ~/~ f~. Title Senior Drilling Engineer Date i (',~ . /' ' Commission Use Only / Permit Number I APINumber I ApprovalDate I Seecoverletter ¢,,~ ~ 50-0 7_-- ¢ ---- .2.. 2_ ~ ,~ ~ / --'- /~- ~' ? for other requirements Conditions of Approval: Samples Required [] Yes ,~,y~NObs Mud Log Required [] Yes '~ No Hydrogen Sulfide Measures [] No Directional Survey Required ,,~Yes [] No Required Working Pre,s,surefof B~PE ~2M; []3M; [] 5M; [] 10M; [] 15M Other: U,]~,FIS.,~;~, ,..'.~, SJgP, eo .~.~ by order of Approved By D,~.~LI W. J0hnstor; Commissioner the commission Date Form 10-401 Rev. 12-01-85 Subrrj cate I Well Name: I MPE- 14 Well Plan Summary Type of Well (producer or injector): I Schrader Bluff Producer Surface Location: 3590' FSL 1918' FEL Sec 25 T13N R10E UM., Ak. Target Location: 48' FSL 3705' FEL Sec 25 T13N R10E UM., Ak. Bottom Hole Location: 5074' FSL 3833' FEL Sec 36 T13N R10E UM., Ak. I AFENumber: 1337054 I [Rig: I Nabors 22E I Estimated Start Date: [4/15/97 [ ]Operating days to complete: I 5 I MD: 16651' I I TVD: IKBE: I57' l Well Design (conventional, slimhole, etc.): Q~ 7" Uni-Ca.~S~rader Bluff ESP Producer Formation Markers: Formation Tops MD TVD (BKB) Formation Pressure Data KOP 300 300 - Base Permafrost 1956 1852 Top NA Sand 6209 4161 EMW 8.0 ppg Target 6209 4161 EMW 8.0 ppg Top NB Sand 6239 4184 EMW 8.0 ppg Top dA Sand 6409 4314 EMW 8.0 ppg Top OB Sand 6501 4385 EMW 8.0 ppg TD 6651 4500 7" Casing Point Casing/Tubing Program: Hole ~ize iEsg/- Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.4# H-40 Weld 80' 32/32" 1127112' 8 1/2" 7" 26# L-80 NSCC 6620' 31 '/31' 6651 '/4500 Internal yield pressure of the 7" 26# L-80 casing is 7240 psi. Worst case surface pressure would occur with a full column of gas on top of plugged perfs (no packer) at the reservoir at 4157' tvd. Maximum anticipated surface casing pressure assuming virgin pressure of 1835 psi at 4157' tvd is 1419 psi, which is well below the burst pressure rating of the 7" casing. Logging Program: Open Hole Logs: ]Cased Hole Logs: LWD (GR/Res/Density/Neutron) Wireline: Sidewall cores and RFTs in hydrocarbon bearing Schrader Bluff and Ugnu reservoirs may be run. GR/CCL (w/out rig on well) .~i,n:-~:.i. 21.~ i llt~ Well Plan Summary Page 1 Mud Program: Special design considerations [ Add Lecithin for hydrate control ABOVE PERMAFROST <2000' MD: 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 9.0 90 35 15 30 10 15 PERMAFROST TO TD: I Density Marsh Yield 10 sec 10 min 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: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Line. Completion Rig (Nabors 4ES) 5000 psi W.P. pipe ram, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: IKOP: I 300', S-Shaped [ Maximum Hole Angle: I 66.66° Close Approach Well: NONE Disposal: Cuttings Handling: Cuttings will be hauled to CC2. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas at 564-4305. Fluid Handling: All drilling and completion fluids will be hauled to CC2 for injection. Well Plan Summary Page 2 GENERAL DISCUSSION Objective The well is planned as a Schrader Bluff unibore producer and will penetrate the top of the reservoir 4525' southwest of E Pad. The well will test for hydrocarbons and reservoir quality in a previously untested fault block. Drilling Hazards and Risks: 1. Hydrates There is a possibility of finding hydrates on E-Pad, although the hydrate zone tends to be further to the east than the path of E-14. The two most recent wells, E-16i and E-17i, saw virtually no traces of hydrates. If hydrates are encountered, mud weights will be increased to 10.2ppg or heavier if required. The cement program will include an ES cementer at 2143'MD (2000'TVD) with a Permafrost C tail on the second stage. ~q4ffis tall~lurry ensures a high quality cement seal above the hydrate zones. Weighted spacers will be used instead of fresh water so that there will be no loss of hydrostatic, which could increase movement of hydrates into the well. 2. Close Approaches There are no close approaches associated with the drilling of E-14. 3. Lost Circulation Lost circulation is not expected to be a problem in this well, unless the presence of hydrates result in much higher than expected mud weights. Recent experience on E Pad and K Pad has shown that the use of Lecithin and other methods to manage the impact of hydrates can be be very effective and serious problems are not expected. However, if mud weights needed to control the hydrates exceed 10.5ppg, casing will be set above the Schrader Bluff and the well will be completed in 6" hole. 4. Stuck Pipe Potential There have not been any major surface hole problems on E-Pad, although E-22 did see some tight hole due to poor hole cleaning. Any indications of gravel should be countered by an increase in fluid viscosity. 5. Formation Pressure Schrader Bluff Target 4100' TVD SS 1835 psi 8.6 ppg The expected pore pressure for this well is based on the gradient of 0.4476 psi/ft which has been established for the Tract 14 area. 6. Others This will be one of the few wells drilled on the Slope with an 8 1/2" surface hole and there may be a learning process before the usual levels of efficiency are achieved. Even though there may be an temporary impact on drilling rates, it is unlikely that any of the identified hazards will be exacerbated by the hole size change. The connection on the 7" casing must be NSCC, in order to withstand the permafrost thaw effects. This requirement was determined in a study by Stress Engineering Services Inc. The study was commissioned in August 1996. Well Plan Summary Page 3 MPE-14 Well , o . o o . . 11. 12. 13. 14. 15. Operations Summary Drill and set 20" conductor. Weld starting head and top job nipple on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. NOTE: NOT[FY AOGCC OF UPCOMING DIVERTER TEST N/U and function test 20" Diverter system. Directionally drill 8 1/2" hole to 6651' MD/4500' TVD. Run sidewall cores and RFTs if required. Wiper Trip Run and cement 7", 26#, L-80, NSCC casing to surface. Cement job will be done in 2 stages with an ES cementer at 2143'MD. "CELLO FLAKES" are to be incorporated into the stagel tail slurry as well as the stage1 lead slurry. Reciprocate pipe. No "CELLO FLAKES" are to be incorporated into the stage 2 cement. After opening ES cementer, circulate for a minimum of 2hrs before pumping stage 2 N/D Diverter and N/U wellhead and tree. RDMO Nabors 22E. MIRU Nabors 4ES.~' N/U B OPE and test. Drill out ES cementer and clean out well. Perforate and frac pack the "N" sand followed by the "O" sands. Complete well with 2-7/8", 6.5#, L-80 EUEtbg with Electric Submersible Pump (ESP). Set BPV. N/D BOP Stack and N/U x-mas tree. RDMO with Nabors 4ES Well Plan Summary Page 4 CASING SIZE: 7" SPACER: 75 bbls spacer weighted to mudweight in the hole. STAGE 1 LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder + CELLO FLAKES (1/4 lb/sk) WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx APPROX # SACKS: 299 TAIL CEMENT TYPE: MPE-14 7" PRODUCTION CASING CEMENT PROGRAM - HALLIBURTON CIRC. TEMP: 75° F at 4500' TVDss MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50°F Premium G ADDITIVES: 0.2% CFR-3 + 0.2% HALAD-344 + CELLO FLAKES (1/4 lb/sk) WEIGHT: 15.8 PPG APPROX # SACKS: 97 FLUID LOSS: 100 - 150cc STAGE 2 LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX # SACKS: 400 YIELD: 1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50°F FREE WATER: 0 Type E Permafrost YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50°F Note: Lead cement will be pumped until it reaches surface. TAIL CEMENT TYPE: WEIGHT: 15.6 PPG APPROX # SACKS: 33 Type C Permafrost YIELD: 0.92 ft3/sx MIX WATER: 3.36 gal/sk THICKENING TIME: Greater than 4 hrs at 50°F WELLHEAD STABILITY JOB: (If Needed) ADDITIVES: Retarder WEIGHT: 12.0 PPG APPROX NO. SACKS: 150 YIELD: 2.17 ft3/sk Permafrost E MIX WATER: 11.63 gal/sk Well Plan Summary Page 5 CENTRALIZER PLACEMENT: 1. Straight Blade Turbulators -- two per joint on the bottom 19 jts of 7" Casing (34 Total). This will cover 300' above the top of the "N" sands. 2. Run one 7-1/8" x 8-1/4" Straight Blade Turbulator inside of the 20" casing. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirements. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1st Stage 1. The Tail Slurry Volume is calculated to cover to 100' TVD above the top of the upper "N" sands (6079'MD) with 30% excess plus the shoe track volume. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to the ES cementer at 2141' md with 30% excess. 3.80' of 7", 26# capacity for float joints. 2nd Stage 1. The Tail Slurry Volume is calculated to cover from the ES cementer to the base of the permafrost (1956' MD) with 30% excess. This cement is intended to provide an effective seal above the potential hydrate zones. 2. The Lead Slurry volume is that required to bring cement to surface. 3. Top Job Cement Volume will be 150 sx, if necessary. Well Plan Summary Page 6 Anadrill Schlum~er{er .Alaska District 1111 East BOth Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : MPSB97(P1) Field ........ : MILNE POINT, EPAD Computation..: Minimum Curvature Units ........ : FEET Surface Lat..: 70.45'441997 N Surface Long.: 149.43507237 W LOCATIONS - ALASKA ZOne: 4 X-.Coord Y-Coord 569228.18 6016128.05 567475.00 6012570.00 569349.32 6012314.93 Legal Description Surface ...... : 3590 FSL i918 FEL S25 T13N R10E UM TARGET ....... : 48 FSL 3705 FEL S25 T13N R10E UM BHL .......... : 5074 FSL 3833 FEL S36 T13N R10E UM Prepared ..... :. 02 Dec 1996 Vert.sect az.: 207.15 KB elevation,: 57.30 ft Magnetic Dcln: +28.224 (E) Scale Fa6tor.: 0.99990544 Convergence..: +0.53237598 mmmmmm m · STATION MEASURED INCLN DIRECTION IDENTIFICATION DEPTH ANGLE AZIMUTH KB 0.00 0.00 0.00 KOP/BUILD 1/100 300.00 0.00 0.00 400.00 1.00 206.76 BUILD 2/100 500.00 2.00 206.76 600.00 4,00 206.76 PROPOSED WELL PROFILE VERTICAL-DEPTHS TVD SUB-SEA 0.00 -57.30 300.00 '242.70 399.99 342.69 499.96 442.66 599.82 542.52 SECTION DEPART 0.00 -0.00 0.87 3.49 8.72 COORDINATES-FROM ALASKA Zone 4 TOOL DL/ WELLHEAD X Y FACE 100 0.00 N 0.00 E 569128,18 6016128.05 HS 0.00 0.00 N 0.00 E 569228.18 6016128.05 153L 0.00 0.78 S 0,39 W 569227.79 6016127.27 153L 1.00 3.12 S 1,57 W 569226.64 601612~.92 153L 1.00 ., 7.79 S 3,93 W 569224.32 6016120.23 153L 2.00 BUILD 2:5/100 700.00 6.00 206.76 800.00 8.50 206.76 900.00 I1.00 206.76 1000.00 13.50 206.76 1100.00 16.00 206.76 1'200.00 18.,50 1300.00 21.00 699.43 642.13 798.62 741.32 897.17 839.87 994.89 937.59 1091.58 1034.28 .206,76 1187.08 1129.78 206,76 1281.19 1223.89 17.44 30.06 46.99 68.21 93.66 123.31. 157.10 15.57 S 7.85 W 569220.47 6016112.41 HS 2.00 26.84 S 13.54 W 569214.90 6016101.09 HS 2.50 ~1.96 S 21.16 W 569207.41 6016085.90 HS 2.50 60.90 iS 30,71 W 569198.04 6016066.87 HS 2.50 83.63 S 42.18 W 569186.78 6016044.04 HS 2.50 110.11 S 55.53 W 569173.68 6016017.44 HS 2.50 {40.28 S 70.75 W 569158.7~ 6015987.14 HS 2.50 (;unadrill (c)96 MPSB97P1 3.0b.08 6:2~ PM P) P~0POSED WELL PROFILE STATION MEASURED IDENTIFICATION DEPTH 1400.00 1500.00 1600.00 1700.00 1800.00 INCLN ANGLE 23.50 26.00 28.50 31.00 33.5O DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 206.76 1373.74 1316.44 206.76 1464,54 1407,24 206,76 1553.44 1496.14 206.76 1640.25 1582.95 206.76 1724.82 1667.52 END 2.5/100 BUILD BASE PERMAFROST BUILD 2.5/100 1900.00 36.00 1907. O0 36 , 17 1956.14 36 . 17 2007.00 3~.17 2100.00 38.50 206.76 1806,97 1749,67 206.76 1812,63 1755.33 206.76 '1852.30 1795.00 206.76 1893.35 1836,05 206.76 1967.29 1909.99 SECTION DEPART 194.96 236.'83 282.61 332.22 385,58 COORDINATES-FROM WELLHEAD END 2.5/100 BUILD DROP 2/100 174.08 S 211.46 S 252,34 S 296.64 S 344.28 S ,87.80 W 106.65 W 127.26 W 149'.61 W 173,.63 W 442.57 395.17 S 199.30 W 446.70 398.85 S 201,16 W 475.70 424.75 S 214.22 W 505.72 451.56 S- 227.74 W ,562.12 501.91 S 253.13 W 2200.00 41.00 ' 206.76 '2044.17 1986,87 626.06 2300.00 4].50 206.76 2118..I8 2060.88 693.29 2400.00 46.00 206.76 2189.20 2131.90 763,68 2500.00 48.50 206.76 2257.07 2199.77 837.11 2600.00 51.00 206176 2321,68 2264,38 913',42 2700.00 53.50 2800.00 56.00 2900.00 58.50 3000.00 61.00 3100.00 63.50 3200.00 66.00 3226.46 66.66 4675.97 66.66 4700.00 66.18 4800.00 64.18 206.76 2382.90 2325.60 992.'48 206".76 2440.61 2383.31 1074.14 206.76 2494.7.0 2437.40 1158.24 206.76 2545.07 2487.77 1244.61 206.76 2591.63 2534.33 1333,10 4900.00 62.18 5000.00 60.18 5100.00 58.18 (Anadrill (c)96 MPSB97P1 3.0b.0B 6:24 PM P) 206.76 2634.28 2576.98 1423.54 206.76 2644.91 2587.61 1447.77 206.76 3219.15 3161'.85 2778.65 206.76 3228.76 3171.46 2800.67 206.76 3270.73 3213.43 2891.43 206.7~ 3315.85 8258.55 2~e0.67 206.76 3~64.05 ~06.75 ~06.76 3~15.28 3357.98 3154.15 ALASKA Zone 4 Y 569142',01 6015953.18 569123.51 6015915.63 569103128 60158~4.56 569081,35 6015830.06 569057.77 6015782.20 559.00 S 281.93'W 61'9.03 S 312.20 W 681~89 S 343.90 W 747.45 S 3.76.97 W 815.59 S ¢11.33 W '569032.58 6015731.08 569030.76 6015727.38 56'9017.94 6015701.37 569004.67 60i5674.4{ 568979.74 6o~5623.85 568951.49 6015566.s° 568921.77 6o155o6.2o 568890.66 6015443.06 '568858.21' 6015377.,20 5688'24.48 6015308.75 TOOL FACE HS HS HS HS HS HS HS HS HS HS HS 886.18 S 446.93 W 568789.54 6015237.84 HS, 959.09 S 483.71 W 568753.45 6015164.60 HS 1034.18 S 521,58 W 568716.28 6015089.17 HS 1111.30 S 560.47 W 568678.11 6015011.69 HS 1190.32 S 600.32 W 568639.00 6014932.32 HS DL/ 100 2.50 2,50 2.50 2.5O 2.50 2,50 2.50 0.00 0.00 2:50 ,2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 1271,07 S 641.05 W 568599.'03 6014851.20 MS 2.50 1292.70 S 651.96 W 568588.32 6014829.47 ~S 2.50 2481.04 S 1251.28 W 568000,12 6013635.73 LS 0.00 2500.70 S 1261.20 W 567990.39 6013615.97 LS 2.00 2581.74 S '1302.07 W 567950.28 6013534.57 LS 2.00 2661.42 S 1342.25 W 567910.84 6013454.53 LS 2.00 2739.64 S 1381.70 W 567872.12 6013375.95 LS 2.00 2816'.32 S' 1420.37 W 567834.17 6013298,92 .LS 2.00 0 I 0 I 0 > > U STATION IDENTIFICATION =============~===~m END 2/100 DROP' TARGET ToP ~ .~mR Ng TOP OA TOP OB/BASE SCHRADER 7" CASING POINT MEASURED INCLN DEPTH ANGLE 5200.00 56~18 5300.00 54.18 5400.00 52.18 5500.00 50.18 5600.00 48~18 5700~00 '46.18 58~0.00 44.18 5900.00 42.18 ,6000.00 40.18 6009.05 40.00 6209,05 , 40,00 620'9,05 40,00 6408,77 40,00 6501,46 40'100 6651',46 40,00 TD 6651,46 40.00 9ROPOSED WELL PROFILE DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 206.76 3469,48 3412,18 206.76 3526,57 3469,27 ~06.76 3586.50 3529,20 206,76 3649,18 3591.88 206,76 3714.55 3657,25 SECTION DEPART 3238.18 3320,27 3400.32 3478.23 3553.90 206,76 3782,51 3725,21 3627,24 206,76 3853,00 3795,70 3698.17 206,76 3925,91 3868,61 3766,60 206,76 4001,17 3943,87 3832,44 206,76 4008,09 3950,79 3838,26 COORDINATES-FROM ALASKA Zone 4 TOOL WELLHEAD X Y FACE 2891,35 S 1458.21 W 567797.03 6013223,55 LS 2964.65 S 1495.18 W 567760.75 6013149.92 LS 3036.12 S 1531.23 W 567725,37 6013078.12 LS 3105.68 S 1566,31 W 567690,94 6013008.24 LS 3173,25 S 1600.'39 W 567657,49 6012940,37 LS DL/ 100 2.00 2.00 2,00 2.00 2,00 3238,74 S 1633.42 W 567625,08 601.2874.58 'LS 2.00 3302,07 S .1665,36 W 567593.73 60128'10,96' LS 2,00 3363,17 S 1696.17 W 567563,49 6012749,'$9 E~S 2,00 3421,96 S i725,82 W 567534,39 6012690.53' LS 2.00 3427,16 S 1728,44 W 567531,82 6012685,31 lis 2.00 206,76 4161,30 4104,00 3966,81 3541,94 S 2~6,76 4161,~0 4104,00 3966.81 3541.94 S l l.~ 206,76 43 4,30 4257,00 4095,19 3656,57 S 206,76 4385,30 4328,00 41~4.77 3709.77 S 206,76 4500.21 4442,91 4251,18 3795.85 S 1786,33 W 567475,00 6012570,00. HS 1786,33 W 567475,00 6012570,00 HS 1844,14 W 567418,26 6012454.85 HS 1870.97 W 567391,93 6012401,41 HS 1914.39 W 567349.32 6012314.93 3795.85 S 1914.39 W 567349.32 6012314.93 206,76 4500,21 4442.91 4251.18 0,00 0.00 0,00 0,00 0,00 0.00 , O I o W I o (Anadrill (c}96 MPSB97P1 3.0b.08 6:24 PM P) SHARED SERVICES DRILLING MPSB97 (Pi) VERTICAL SECTION VIE~ Section at: .207.15 TVD Scale.' 1 inch = BOO feet ; Dep Scale.' ~ inch = 800 feet <KB> o. , '- i Drawn .... · 02 Dec ~996 i i i i 400-- .i- . ... t ' Anadr~ ]] Schlumberger · I' iii i O-~ : I Marke¢ Identification MO 8KB SECTN INCLN 800 ' ~ ' ' ': Al KB ' ' · 0 0 0 0.00 ~ . ' ~ B] KOP/BUILD ~/~00 300 300 -0 0.00 ~ ' ~ '. C) BUILD 2/~00 500 500 3 2.00 1200-- '~ · , .- D} BUILD 2.5/100 - 700 699 17 6.00 . ' ~ -~ , ' ri. BUILD 2.5/~00 . 2007 '1893 506 '36.17 ' ~ ~ ' ' ~" ' : I G) END 2.5/100 BUILD 3226 2645 I44B 66.~6 ~600 ] ' - ~j- - · . . - .! -' Hi. DROP 2/~00' 4676 '32~9 2779 66.66 ~' - j , ' Zi END 2/S00 DROP 5009. '400B 3838 '40.00 '' .... ~---.'gl~'~ ............ ~~r'~ dl TARGET ' 6209 416l 3967 40.00 T 2ooo--- ' - ~F~ .... J K) 7" CASING POINT 6651 4500 4251 40.00 ! _ ~__ ,j L) TD 6651 4500 425t 40.00 V . - 02400 ~oo-- '.. -3200 m ' - ~ ' i' ' :. '-~ ' ' 3600'- - ;I ' ' ~ ' ': ' ' ~' ":" '~] ' I 't ~r'~''-'-~---=- ' ....... = .... '-'-' ......... "; .......... T ..... ..... I" ............. ,-', .......... ' ........ ~::: '48oo , I i , . . ,. 5200'- J ........ i ...... J "- ~oo , 6000- ; t , 0 400 800 ~200 ~600 2000 2400 2800 3aO0 3600 4000 4400 ~800 5200 Section ~eparture (Anad¢ill (c)96 t4~897P! 3.0b.08 6:25 PH PI uec-03-96 08:32A Anadrq i i uvb ' ' SHARED' SERV ICES Marker Identification A) KB B) KOP/BUILO 1/100 C) BUILD 2/100 BUILD 2.5/$00 E) END 2.5/~00 BUILD F) BUILD 2.5/100 G) END 2.5/~00 BUILD DROP 2/100 I) END 2/100 DROP J) TARGET K) 7" CASING POINT TD ND N/S E/~ 300 0 N 700 16 S 3907 399 S 20t 2007 452 S 228 3226 1293 S 652 4676 2481 S 125! 6009 3427 S t728 6209 3542 S t7B6 665~ 3796 S lB14 665~ 3796 5 ~914 DRILLING MPSB97 (P PLAN VIEW CLOSURE ..... : 4251 feet at'Azimuth 206.76 DECLINATION.: +28.224 {E) SCALE ....... : 1 inch : 600 feet DRAWN ....... : 02 Dec 1996 Anadri l I Schlumberger TARGET ] . . ' ! ,~ i i 3900 3600 3300 3000 2700 2400 etoo tsoo tsoo t200 900 600 300 0 300 <- WEST · EAST -> [Ana~rili [c)~ MPSBg~PI 3.0b.08 6:26 PM PI Alaska District Directional Well Planning Department NORMAL PLANE TRAVELLING CYLINDER RESULTS INCLUDING ELLIPSES OF UNCERTAINTY Ciinnt .............. : BP EXPLORATION Well Name ....... : MPSB97{P011 Field ................ : MILNE POINT Cntlnt¥ i State..: BEECHEY POINT, ALASKA APl# ................ : 50-029-96082-00 Anudfiil ID# ...... : 500299608200P01 03 ; MIN. OFFSET WELL FLOWING [ SAFETY SEP. 7.7 18.5 47,5 48,5 81.5 107.1 109.9 1'63.1 166.1 160.5 289.3 291.8 161.5 346.1 154.1 i 89.3 233.2 233.2 233.2 233.2 175.3 229.8 . 236.0 i 177.4 · . 325.6 302.5 348.0 437.6 498.8 MPE-15 MPE-15(O01 MPE-24(P04) MPE-20 MPE-20{D01 MPE-18(P08} MPE- 11 MPE-11(D01) MPE-090H MPE-09 MPE-09(G01) MPE-21 {PO8} MPE-22 MPE-22(D01) MPE-23 MPE-10 MPE-17(P13) MPE-07 MPE-13 MPE-13A- MPE-13AST MPE-13AST2 MPE-16(P16} MPE-06 MPE-13(D02) MPE-16(D01 KAVEA32-25 MPE-05 ' - MPE-04 MPE-02 tvlPE-03 -MPE-08 MPB-22 MPB-21 MPCFP-1 MPH-0S(D01 MPH-OS(D02} MPH-O6(D01 ELLIPSE i SURVEY SEP. SEP. ' I 20.5 i 20.4 29.4 55.8 j- ! 56.8 89.4 -115.7 i I 18:2 173.9 174,9 176,9 301.3 ' 303,5 j 167.9. 359.2 ~ 159;7 195.9 241.1 241.1 I 241.1 241.1 i 180.6 .j 236.2- 242.0 181.6 _, 332,6 308.8 354.3 444,9 506.9 25.7. 25;4 33.4 58.7 59.7 92.2 121.3 121.1 182.0 183.0 182.7 159.1 309.5 307.9 170.1 364.7- 161.7 199.0 246.1 248.1 246.1 246.1 182.4 239.2 244.1 183,1 336.9 311.7 ; 358.4 .j 4.4.9.7 i 512.2 ! 523.3 529.9: j 533.0 3941.4 3982~8 j 4711.8 I 4679.7 .j 4719.4 : 5425.4 J 1989.5 [ 1996.3 - 2000.9 [ 14001.7 ' 14006.1 1.14007.6 14002.0 14006.4 14007.9 14039.7 14044. i 14045.6 _ Planned Well Survey Program St~t Enc~ Type Interval 0 6651 MEWD 93 MD 854 829 726 552 526. 575! . 651 .788. 789 787 4.24 '805 782 425 868 377 444 524 524 524 524 352 .425 402 278 4~3 418 :418 488 641 440 3139 2977 ' 452 292 292 291 j FLOWING PLUGGED SAFETY 12.8 J 12.4 , 10.9 I 8.2 6.3. . .7,9 6.3 i 11,8 ~ 11.8 11.8 ; 6.4 12.1 i 11.7 ~ 6,4 13.0 5.7 852 j 827 726 [ 550 552 . 525 J 575 i 551 7871 : 787 786 J 424 · 804 7R1 i 425 ! 865 377 j ~z~4 J 524 '~; .524 .524 i 524 -425 402 278 463 418 418 488 541 j' 440 2609 2534 . 452 i 292 ~ 292 ' 291 i j. 7.9 j 7.9 5.3 6.4 i 6.0. - 6,9 6.~. Sol ' 8,6 41.4 . 1 39.8 I 6.8 4.4 . i Date Calculated ..... : 12/02/96 18:15 Date Plotted .......... : 12102196 18:16 EeL ..................... : 57.30 Grid X .................. : 569228.1 8 Grid Y .................. : 601 61 28.05 Grid Zone ............. : ASP ZONE 04 DIST. ZONE MD I ZONE{ ZONE j MD MO I ! 2.1 2'.1[ 1.8 1.4. 1.4 i.4 2,0 2.0 2,0 1,1 2.0 2,2 0,9 1.1 1,3 1.3 1.3 0.9 ! .1 1.0 0,7 1.2 1,0 1;2 · 1.4 1.1 7.8 7.4 1.1 0.7 0.7 -0,7 ~ I j i EXIT PLUG ZONE MD CLOSE APPROACV STATUS [ FLOW FLOW I FLOW I FLOW FLOW i FLOW FLOW FLOW ~ FLOW FLOW i FLOW · FLOW FLOW FLOW FLOW i FLOW )FLOW ~ FLOW : FLOW FLOW ; FLOW ! FLOW FLOW ~ FLOW : ;FLOW ' FLOW FLOW FLOW FLOW J- FLOW · FLOW FLOW FLOW , FLOW : FLOW ; FLOW FLOW FLOW j , I : ; NOTES: All depths & d~stances are in FEET All depths are referenced from well MPSBgT(P01) MIn Rowing Safety Sap. i$ amount of additional clearance from flowing eatery line. 1111 East 80:h Avenue · Anchorage, Alaska 99518 · Telephone= (gOT) 349-a, 511 · FAX: (907) 344-2160 Anedriil Alaska District Directional Well Planning Department NORMAL PLANE TRAVELLING CYLINDER RESULTS INCLUDING ELLIPSES OF UNCERTAINTY Cli~.nt .............. : I~P EXPLORATION Well Name ....... : MPSB97(P01) Field ................ : MILNE POINT County I State..: 8EECHEY POINT. ALASKA APl// ................ : 50-O29-96082-00 Anadrill ID//' ...... ; 5002~19608200P0103 Planned Well Survey Program start End Type Interval 0 6651 MEWD 93 Date Calculated ..... : 12/02196 18:15 Date Plotted .......... : 12/02/96 18:16 KeN ..................... : 57.30 Grid X .................. ; 569228.18 Grid ¥ .................. : 60161 28.05 Grid Zone ............. : ASP ZONE 04 Z 3600 120( 1 3200 6000 -50 -25 0 25 50 75 100 125 150 175 200 225 250 NORMAL PLANE SEPARATION (1" = 50 ft) TD 6651.46 1 I I I East 80th Avenue o Anchorage, Alaska 99518 - Telephone: (907) 349-4511 - FAX: (907) 344-2 I (50 PROGRAM: expD dev~redrlO servD wellbore segr~ ann disp para req~ o ,o. ADMINISTRATION 7. 8. 9. 10. 11. D~TE ~ 12. ENGINEERING Permit fee attached ................... Y ~ Lease number appropriate ............... N Unique well name and number .............. N Well located in a defined pool ............ N Well located proper distance from drlg unit boundary. N Well located proper distance from other wells ..... N Sufficient acreage available in drilling unit ..... N If deviated, is wellbore plat included ........ N Operator only affected party ............. N Operator has appropriate bond in force ........ N Permit can be issued without conservation order .... N Permit can be issued without administrative approval. N Can permit be approved before 15-day wait ....... N REMARKS 14. Conductor string provided ............... %~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg..~~ 17. CMT vol adequate to tie-in long string to surf csg . . . 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ 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 ..................... N 26. BOPE press rating adequate; test to ~~pslg N 27. Choke manifold complies w/API RP-53 (May 84) ...... N 28. Work will occur without operation shutdown ....... N 29. Is presence of H2S gas probable ............ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/_ 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones ........... Y//NY N 33. Seabed condition survey (if off-shore) ....... 34. Contact name/phone for weekly progress reports . . '6/' Y N [exploratory only] GEOlOGy':' ENGINEERING :' 'coMMISSiON: Comments/instructions: HOW/dE - A:%FORMStcheklist rev 01197 · FIELD & PC)OL ADMINISTRATION WELL PERMIT CHECKLIST COMPANY -'~/" WELLN,~,ME',,~,,~-~'~ ~ ~Nrr CLASS~.¢.,, / ~-~ ¢'-/~ o_. _ 1. Permit fee =t~c. hed ....................... [.Y~N 2. Lease number appropriate ................... 'IilN 3. Unique wet] name and number ................. N 4. Well Ioc~ in a defined pool ........... _ _ N we"' { i i { i { {{ 7. Sufficient acreage m,'aJla, ble in N 8. If deviated, is wellbore plat included N 9. Operator orfly affeC, ed party .................. N 10. Operator h~ appropfime bond in force ............ N 11. Permit can be issued Wil~om conserv~on order ...... N 13. Can permit be approved before 15-day wa~ ........ N ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. · -GEoLoGY ......... 30. 31. 32. 33. AP, PR D~T~/ 34. ~ ,//,~?? Conductor string provided ................... N Surface casing protects all known USDWs .......... '*"~ N CMl- vol adequate to circulate on conductor & surf csg . . . .~ N CMT vol =equate to tie-in long string to surf csg ...... CMT will cover all known productive horizcx'~s. ........, Casing designs adequate for C, T, B & permaJro~ ..... { N Adequate t~.nk~ge or reserve pit. ............... I N If a re-drill, has a 10-4.03 for abndnmnt been approved .... Adequate wellbore separation proposed ........... N If diverl:er required, is it adequate ................ N Drilling fluid program schemstic & equip list adequate .... N BOPEs adequate ........................ t N BOPE press ra'dng adequate; test to '~.¢'¢rt~ psig. 1 N Choke mardfold complies w/APl RP-53 (May 84) ....... ( N Work will occur without operation shutdown .......... ~ N Is presence of H2S gas probable ............... ~ N Pe'rmit can b~ L.~u'ed W/O ~"droge~ ;;';;a-measures.'- '. -' . .Y Data presented on potential overpressure zones ....... '~/~ Seismic analysis of shallow gas zones ............ ///Y N Seabed condition survey (if off-shore) ......... .//.. Y N Ccr'~.ct name/phone for weekly progress repom .. ...... Y N jexptoratory only] PROGRAM: exp r'l de;~'/t~reddl [] serv [] wellbore seg r-]ann, disposal para req I'-] ~'~ UNIT# .,,'/,'/.~_Z~ ON/OFF SHORE.__.~.,~L.L_ REMARKS GEOLOGY: ENGINEERING_: COMMISSION: BEW ~. JDH ~ JDN TAB ~.~ ~ Comments/Instructions: HOW4~- A.~r-OR~st r~, ~ Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Thu May 15 17:37:47 1997 Reel Header Service name ............. LISTPE Date ..................... 97/05/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/05/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Con~nent Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL N~E: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-70089 B. ZIEMKE J. PYRON 1ST STRING MPE-14 500292273400 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 15-MAY-97 MWD RUN 2 AK-MM-70089 B. ZIEMKE J. PYRON MWD RUN 4 AK-MM-70089 B. ZIEMKE J. PYRON 25 13N 10E 3590 1918 .00 57.60 24.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2ND STRING 3RD STRING PRODUCTION STRING REI~ARKS: 20.000 112.0 12.250 9.625 5543.0 8.500 9370.0 !. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. A2~TNULAR HYDRAULICS ARE CALCULATED USING THE POWER LAW MODEL. 3. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GMarA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 4. MWD RUN 3 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 5. MWD RUN 4 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD). 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9370'MD, 7300'TVD. SROP = SMOOTHED RA_TE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC = SMOOTHED BULK DENSITY (CALIPER CORRECTED). SCOR = SMOOTHED STANDOFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR/NEUTRON LOG PROCESSING: HOLE SIZE = MUD FILTRATE SALINITY = MUD WEIGHT = FO~qATION WATER SALINITY = FLUID DENSITY = MATRIX DENSITY = LITHOLOGY = $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 850 PPM. 8.6 - 10.2 PPG. 14545 PPM. 1.0 G/CC 2.65 G/CC S~DSTONE Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX PEF ROP FCNT NCNT NPHI DRHO RHOB PEF $ .5000 START DEPTH 232.5 241.5 241.5 241.5 241.5 303 0 304 5 5454 5 5454 5 5454 5 5540 0 5540.0 5543.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 232.5 5538 0 5540 0 5543 0 5555 0 5556 5 5571 0 5572 5 5578 0 5579 5 5607 5 5609.0 5675.5 5677.0 5683.5 5686.0 5688 0 5691 0 5694 0 5700 0 5703 5 5723 5 5735 5 5747 5 5765 5 5770 5 5780 0 5892 5 5898 5 5901 5 5916 5 5921 0 ~e37 ~ 5948 5 5953 5 5960 0 5964 0 5967 0 6305 0 6309 5 6311 0 GR 228.5 5534.0 5538.0 5540.0 5548.5 5550.0 5563 0 5565 0 5570 0 5571 0 5604 5 5606 5 5669 0 5670 5 5676 5 5680 5 5683 0 5687 5 5690 5 5695 5 5703 5 5721 5 5733 5 5742 5 5763 5 5768 5 5775 0 5890 5 5892 5 5897 0 5913 0 5917 0 5933 5 5944 0 5946 5 5953 5 5960 5 5963 5 6304 5 6310 5 6312 0 STOP DEPTH 9320 0 9300 5 9300 5 9300 5 9300 5 9300 5 9380 5 9274 0 9274 0 9274 0 9309 0 9309 0 9309 5 EQUIVALENT UNSHIFTED DEPTH -- 6436 5 6538 5 6543 0 6548 5 6837 0 6864 5 6895 5 6928 5 6979 0 6981 5 7011 0 7023 0 7026 5 7039 5 7044 5 7046 5 7o49.o 7053 5 7063 0 7067 0 7074 5 7079 5 7081 0 7090 5 7098 5 7100 0 7110 5 7117 0 7120 0 7122 0 7124 0 7126 0 7132 5 7160 5 7163 0 7165 5 7172 0 7174 0 7176 5 7181 0 7185 0 7188 0 7191 0 7198 5 7201 0 7205 5 7209 0 7221 5 7225 5 7230 5 7235 0 7239 0 7242 0 7244 5 7249 0 7251 0 7252 5 7254 5 7268 5 7270 5 7280 0 7283 0 7285 5 7289 0 6435 5 6528 0 6537 5 6550 0 6831 0 6853 5 6886 0 6913 5 6979 0 6983 0 7008 0 7017 0 7018 5 7036 0 7041 5 7044 5 7046 5 7052 5 7057 5 7062 0 7065 0 7072 0 7075 5 7085 0 7088 5 7090 0 7105 5 7111 5 7116 0 7118 5 7123 5 7126 5 7133 0 7156 5 7159 5 7162 5 7171 0 7172 5 7174 0 7181 5 7184 5 7186 5 7188 5 7193 0 7196 0 7200 0 7204 5 7216 5 7220 0 7222 5 7229 5 7232 0 7235 5 7238 5 7242 0 7244 5 7246 5 7249 0 7264 0 7265 5 7274 5 7278 0 7280 0 7283 5 7293 7296 7298 7301 7305 7317 7321 7329 7332 7340 7342 7347 7350 7353 7357 7359 7366 7373 7378 7381 0 7384 5 7391 0 7398 0 7409 5 7415.0 7418 0 7422 0 7424 0 7427 0 7432 0 7438 0 7439 0 7443 0 7447 5 7451 5 7454 5 7461 7464 0 7466 0 7478 0 7480 5 7482 0 7484 0 7486 5 7490 5 7494.5 7496 0 7498 5 7503 0 7505 5 7507 5 7512 0 7516 5 7519 5 7522 0 7525 0 7531 0 7536 5 7538 0 7542 0 7544 5 7555 5 7560 5 7562 0 7288 0 7290 5 7292 5 7295 5 7299 5 7311 5 7314 0 7326 0 7328 0 7336 0 7338 5 7343'0 7346 5 7348 0 7350 0 7352.0 7361.5 7366.5 7372.5 7375.5 7380 0 7386 0 7392 0 7403 0 7408 5 7411 5 7414 5 7417 5 7420 5 7425 5 7431 5 7433 0 7437 5 7443 0 7445 5 7448 5 7454 0 7456 5 7460 0 7471 0 7475 0 7476 0 7478 5 7480 5 7484 5 7488 0 7489 5 7492 5 7496 5 7499.0 7501.5 7505.5 7511.0 7515.0 7517.0 7520.5 7524 0 7528 5 7530 5 7535 0 7536 0 7550 5 7554 5 7557 0 7565 7571 7574 7576 7580 7582 7584 7600 7602 7617 7619 7626 7630 5 7635 5 7639 5 7646 0 7658.5 7664 0 7667 0 7704 0 7708 5 7723 5 7769 5 7774 0 7781 0 7786 5 7790.0 7794.0 7802.0 7807.0 7812 5 7879 5 7882 0 7891 0 7896 0 7903 0 7908 0 7912 5 7917 5 7923 0 7931 5 7945 0 7948.0 7967 5 7975 5 7977 5 7980 0 7983 5 7986 5 7990 0 7993 0 7996 0 8000 5 8004 0 8008 0 8018 5 8046.0 8048.0 8050.5 8082.0 8085.0 8088. 0 8141.5 8144.0 7561 0 7566 5 7569 5 7572 0 7575 0 7576 0 7579 5 7591 0 7593 5 7607 5 7610 0 7621 0 7625 0 7631 0 7636 0 7641 5 7655 5 7660.5 7665 0 7697 0 7703 0 7717 5 7766 5 7769 0 7775 5 7783 0 7786.0 7791.5 7799.0 7801.0 7806 5 7874 5 7876 5 7886 5 7890 5 7897 5 7901.5 7905 5 7908 5 7917 5 7925 5 7939 0 7943 5 7962 5 7971 0 7973.0 7975 0 7978 0 7983 0 7984 0 7987 5 7992 0 7995 0 7998 5 8000 5 8012 5 8040 5 8041 5 8043 5 8077 5 8079 5 8082 5 8136 0 8138 0 8147 8160 8164 8168 8175 8180 8184 8186 8189 8216 8218 8220 8224 8232 8233 8238 8241 8245 8259 8261 8263 8264 8266 8270 8274 8277 8278 8280 8285 8291 8293 8298 8300 8303 8305 8308 8314 8317 8320 8324 8327 8332 8337 8341 8343 8345 8348 8359 8363 8367 8372 8375 8380 8382 8384 8386 8390 8393 8394 8395 8397 8400 8403 8406 5 5 0 0 5 0 0 5 5 0 5 5 0 0 5 5 0 5 0 .0 .5 .5 .5 5 0 0 5 5 5 0 0 0 5 0 0 5 5 5 5 0 0 5 0 0 5 5 5 5 0 5 0 0 0 5 0 5 0 0 5 5 5 5 0 0 8143 0 8157 5 8160 5 8163 5 8169 0 8173 0 8177 0 8181 5 8183 0 8209 5 8211 5 8214 0 8217 5 8225 5 8231 0 8234 5 8236 0 8237 5 8252 0 8253 0 8254 5 8256 0 8257 0 8262 5 8264 0 8268 0 8272 5 8273 0 8281 5 8284 5 8285.5 8291 0 8293 0 8295 5 8298 5 8302 5 8309 0 8312 0 8315 0 8319 0 8321 0 8326 5 8329 5 8334 0 8336 0 8338 5 8340.5 8351 0 8355 5 8360 0 8364 5 8367 0 8372 0 8374 5 8376 5 8379 0 8381 5 8385 0 8387 0 8388 5 8390 5 8392 5 8395 0 8399 5 8411 8416 8418 8420 8422 8425 8430 8436 8438 8440 8443 8446 8450 8452 8455 8464 8471 8480 8495 8516 8538 8556 8567 8581 8583 8593 8596 8602 8605 8609 8619 8623 8626 8656 8658 8661 8666 8713 8716 8718 8739 8742 8744 8789 8792 8794 8808 8810 8813 8829 8834 8838 8842 8875 8892 8895 8920 8922 8927 8928 8930 8934 8941 8942 5 5 0 5 5 0 5 5 5 5 5 0 5 5 0 0 5 0 5 5 5 5 5 0 0 0 0 0 5 0 5 5 0 0 0 0 5 0 5 0 5 5 5 0 5 5 0 0 5 5 5 5 0 0 5 0 0 5 0 5 5 0 0 5 8405 5 8408 5 8411 0 8414 0 8415 5 8418 0 8424 5 8428 0 8432 0 8434 5 8436 0 8439 0 8442 5 8446 0 8448 0 8459 0 8464 0 8473 0 8491 5 8508 5 8527 0 8549 0 8560 0 8572 5 8576.5 8585.0 8587.5 8592.5 8596.0 8603 0 8613 5 8615 0 8617 0 8648 0 8649 5 8653 5 8658 5 8705 5 8708 5 8712.5 8731 5 8734 5 8735 0 8782 5 8784 5 8787 0 8799 0 8801 5 8803.5 8822.0 8825 5 8829 0 8833 5 8870 5 8883 5 8886 5 8910 5 8913 5 8919 0 8920 0 8922.0 8926. 0 8932.0 8934.0 8949 8998 9002 9004 9023 9031 9036 9042 9055 9059 9065 9067 9079 9085 9092 9195 9198 9201 9208 9217 9220 9224 9380 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: 8938 0 8990 0 8992 0 8994 5 9014 5 9021 5 9027 0 9033 0 9045 0 9050 0 9054 5 9057 5 9069 0 9074 0 9082 0 9187 0 9188 0 9191 0 9197 5 9206 5 9211 0 9214 0 9370 0 BIT RUN NO MERGE TOP MERGE BASE 1 300.0 2329.0 2 2329.0 5560.0 4 5560.0 9370.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD ~API 4 1 68 RPX M~D OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI I~D P.U. 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean Nsam DEPT 232.5 9380.5 4806.5 18297 ROP 8.3141 1204.76 224.052 18153 GR 13.431 372.49 79.0939 18176 RPX 0.2981 54.1183 7.44356 18119 RPS 0.2893 116.226 9.94223 18119 RPM 0.2224 2000 12.5577 18119 RPD 0.1502 2000 20.0884 18119 FET 0.1215 51.4357 1.22725 17996 NPHI 20.3983 81.7622 48.1131 7640 NCNT 2107.7 3562.45 2566.15 7640 FCNT 408 1074.04 635.581 7640 RHOB 1.3115 3.1589 2.33621 7539 DRHO -0.876 0.3638 0.0336777 7539 PEF 1.8898 12.5232 2.55177 7533 First Reading 232 5 304 5 232 5 241 5 241 5 241 5 241 5 303 5454.5 5454.5 5454.5 5540 5540 5543.5 Last Reading 9380.5 9380.5 9320 9300.5 9300.5 9300.5 9300.5 9300.5 9274 9274 9274 9309 9309 9309.5 First Reading For Entire File .......... 232.5 Last Reading For Entire File ........... 9380.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 1 .5000 START DEPTH 228 5 237 5 237 5 237 5 237 5 299 0 300 5 STOP DEPTH 2329 0 2329 0 2329 0 2329 0 2329 0 2329 0 2329 0 LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR R~.AL-TIME) : TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM AJgGLE: MAXIMUM A/qGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GA/~vtA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 03-APR-97 4.96 CIM 5.46 MEMORY 2329.0 300.0 2329.0 .1 42.8 TOOL NUMBER P0702CGR8 P0702CGR8 12.250 12.3 SPUD/PAC GEL 10.20 86.0 8.7 7OO 7.6 3.200 2.869 2.600 3.400 32.2 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 RPX MWD 1 OHI~ 4 1 68 8 3 RPS RPM RPD ROP FET MWD 1 MWD 1 MWD ! MWD 1 MWD 1 OHMM 4 1 68 OHMM 4 1 68 OHM: 4 ' 68 FT/H 4 1 68 HOUR 4 1 68 12 16 20 24 28 N a me DEPT GR RPX RPS RPM RPD ROP FET Min 228.5 13.7835 0 2981 0 2976 0 2305 0 2294 25 5873 0 1215 Max Mean 2329 1278.75 125.907 52.655 54.1183 15.0744 116.226 23.3756 2000 34.3171 2000 35.0786 1204.76 224.495 5.869 0.66576 Nsam 4202 4202 4184 4184 4184 4184 4058 4061 First Reading 228 5 228 5 237 5 237 5 237 5 237 5 300 5 299 Last Reading 2329 2329 2329 2329 2329 2329 2329 2329 First Reading For Entire File .......... 228.5 Last Reading For Entire File ........... 2329 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUIVf~LARY VENDOR TOOL CODE START DEPTH GR 2257.5 RPD 2267.5 RPM 2267.5 RPS 2267.5 RPX 2267.5 FET 2326.0 ROP 2327.5 $ STOP DEPTH 5488.5 5498.5 5498.5 5498.5 5498.5 5498.5 5560.0 LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR RR~L-TIME) : TD DRILLER (FT) : TOP LOG INTERPlA_L (FT): BOTTOM LOG iNTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINII~UM A/~GLE: IqAX_IMUM AiqGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL ST~i~DOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 06-APR-97 4.96 CIM 5.46 MEMORY 5560.0 2329.0 5560.0 24.0 50.4 TOOL NUMBER P0702CGR8 P0702CGR8 12.250 12.3 SPUD/PAC GEL 10.20 57.0 9.0 700 6.6 3.200 2.243 2.600 3.400 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 47.2 RPX M?~D 2 OH~M 4 ! 68 RP S ~D 2 OH_~M 4 1 68 RPM MWD 2 OHM~ 4 1 68 RPD I~D 2 OHI~M 4 ! 68 ROP ~D 2 FT/H 4 1 68 FET M?~D 2 HOUR 4 i 68 8 12 16 20 24 28 Name Min Max Mean Nsam DEPT 2257.5 5560 3908.75 6606 GR 13.431 102.752 56.8281 6463 RPX 0.5283 53.0081 8.16552 6463 RPS 0.2893 76.8672 9.70536 6463 RPH 0.2224 79.7789 9.82235 6463 RPD 0.1502 73.2161 10.0397 6463 ROP 8.3141 2112.25 216.296 6466 FET 0.135 8.2247 0.917466 6346 First Reading 2257 5 2257 5 2267 5 2267 5 2267 5 2267 5 2327 5 2326 Last Reading 5560 5488.5 5498.5 5498.5 5498.5 5498.5 5560 5498.5 First Reading For Entire File .......... 2257.5 Last Reading For Entire File ........... 5560 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP 4 .5000 START DEPTH 5363 0 5363 0 5363 0 5363 0 5363 0 5383 5 5444 0 STOP DEPTH 9290.0 9290.0 9290.0 9290.0 9290.0 9309.5 9370.0 FCNT 5450 5 NCNT 5450 5 NPHI 5450 5 DRHO 5537 5 RHOB 5537 5 PEF 5540 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINI~UM ANGLE: MAXINFgM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABI. LITHO DENSITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 9263 5 9263 5 92 63 5 9298 5 9298 5 9299 0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL ST~dqDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 10-APR-97 4.96 CIM 5.46 MEMORY 9370.0 5560.0 9370.0 29.9 52.1 TOOL NUMBER P0706CRDGP6 P0706CRDGP6 P0706CRDGP6 P0706CRDGP6 8.500 8.5 PAC/GEL 10.30 46.0 9.3 850 4.0 1.900 .850 1.800 3.000 70.5 Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined _Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT GR RPX RPS RPH RPD NPHI ROP FET FCNT NCNT RHOB DRHO PEF Service Order Units Size Nsam FT 4 1 ~D 4 AAPI 4 1 I~,JD 4 OHMM 4 1 !~D 4 OHMM 4 1 MWD 4 OHM~ 4 1 I~D 4 OHMM 4 1 MIND 4 P.U. 4 1 I~{D 4 FT/H 4 1 Mg{D 4 HOUR 4 1 MWD 4 CNTS 4 1 MWD 4 CNTS 4 1 MWD 4 G/CC 4 1 MWD 4 G/CC 4 1 MWD 4 BARN 4 1 Rep Code Offset Channel 68 0 t 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 First Name Min Max Mean Nsam Reading DEPT 5363 9370 7366.5 8015 5363 GR 26.9743 372.49 110.1 7853 5383.5 RPX 0.7627 32.3181 2.72738 7855 5363 RPS 0.7831 33.9787 2.92471 7855 5363 RPM 0.7419 2000 4.74835 7855 5363 RPD 0.1018 2000 62.5445 7855 5363 NPHI 20.3983 81.7622 48.1662 7627 5450.5 ROP 3.3757 987.891 230.083 7853 5444 FET 0.1858 51.4357 3.43172 7855 5363 FCNT 408 1083 635.063 7627 5450.5 NCNT 2107.7 3562.45 2564.98 7627 5450.5 RHOB 1.3115 3.1589 2.33659 7523 5537.5 DRHO -0.876 0.3638 0.03331 7523 5537.5 PEF 1.8898 12.5232 2.54887 7518 5540.5 Last Reading 9370 9309.5 9290 9290 9290 9290 9263.5 9370 9290 9263.5 9263.5 9298.5 9298.5 9299 First Reading For Entire File .......... 5363 Last Reading For Entire File ........... 9370 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/05/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Services Writing Reel Trailer Service name ............. LISTPE Date ..................... 97/05/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... ***'*************************** COMPANY NAME : BP EXPLORATION (ALASKA) , INC. WELL NAME : MPE- 14 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22734-00 REFERENCE NO : 97182 MICROFILME LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1997 00:23 PAGE: **** REEL HEADER **** SERVICE NA~4E : EDIT DATE · 97/05/ 7 ORIGIN : FLIC REEL NAME : 97182 CONTINUATION # : PREVIOUS REEL : COf~4~2~T : B.P. EXPLORATION, MPE-14, MILNE POINT, API #50-029-22734-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/05/ 7 ORIGIN : FLIC TAPE NAME : 97182 CONTINUATION # : 1 PREVIOUS TAPE : COf~4ENT : B.P. EXPLORATION, MPE-14, MILNE POINT, API #50-029-22734-00 TAPE H~ER MILNE POINT CASED HOLE WIRELINE LOGS WELL NAME: MPE- 14 API NUMBER: 500292273400 OPERATOR: BP Exploration (Alaska), Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 7 -MAY- 97 JOB NUMBER: 97182 LOGGING ENGINEER: JOHN MAJCHER OPERATOR WITNESS: FOX/LINDER SURFACE LOCATION SECTION: 25 TOWNSHIP: 13N RANGE: 10E FNL : FSL : FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 57.60 GROUND LEVEL: 24.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 9344.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) · LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1997 00:23 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: NONE LDWG CURVE CODE: NONE RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... THIS IS THE PDC LOG FOR THIS WELL, FROM A GR/CCL LOGGED BY SCHLUMBERGER ON 16-APR-97. NO DEPTH CORRECTIONS WERE MADE. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE NUM~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~gVlARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9247.0 5354.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER: BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH THIS IS THE CLIPPED DATA FROM THE PDC GR (GR/CCL) LOGGED 16-APR-97 BY SCHLUMBERGER. $ ~LIS Tap'e Verification Listing Schlumberger Alaska Computing Center 8-MAY-1997 00:23 PAGE: LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 66 66 73 66 66 73 65 0 0 16 1 0.5 FT 64 1 2 3 4 5 6 7 8 68 9 65 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 557836 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH GR GAPI 557836 O0 000 O0 0 1 1 1 4 68 0000000000 TENS GR LB 557836 O0 000 O0 0 1 1 1 4 68 0000000000 CCL GR V 557836 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9247.000 GRCH. GR -999.250 TENS. GR 2928.000 CCL.GR DEPT. 5354.000 GRCH.GR 33.961 TENS.GR 1619.000 CCL.GR -999.250 - O. 052 ** END OF DATA ** 'LIS Tap'e Verification Listing Schlumberger Alaska Computing Center 8-MAY-1997 00:23 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : GRCH $ LOG HEADER DATA FILE HEADER FILE NUM~ER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9247.0 5353.0 DATE LOGGED: 16-APR-97 SOFTWARE VERSION: 8C0 - 609 TIME LOGGER ON BOTTOM: 1151 16-APR-97 TD DRILLER (FT) : 9260.0 TD LOGGER (FT): 9247.0 TOP LOG INTERVAL (FT) : 5353.0 BOTTOM LOG INTERVAL (FT) : 9242.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR G~ RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : TOOL NUMBER ........... SGTL 8.500 9344.0 -LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1997 00:23 PAGE: LOGGERS CASING DEPTH (FT) : 9344.0 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) : SEAWATER/DIESEL NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX .. MATRIX DENSITY: HOLE CORRECTION (IN): 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) : FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: LOG MEASURED FROM DFE 57.6 FT. PRIMARY DEPTH CONTROL IS MAGNETICALY MARKED LINE. LIS FORMAT DATA R . BATES , D. BLODGETT. ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 'LIS TaP~ Verification Listing Schlumberger Alaska Computing Center 8-MAY-1997 00:23 PAGE: 6 TYPE REPR CODE VALUE .............................. 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 557836 O0 000 O0 0 2 1 1 4 68 0000000000 GR GR GAPI 557836 O0 000 O0 0 2 1 1 4 68 0000000000 TENS GR LB 557836 O0 000 O0 0 2 1 1 4 68 0000000000 CCL GR V 557836 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9276.500 GR.GR 59.887 TENS.GR 1823.000 CCL.GR DEPT. 5353.500 GR.GR 33.961 TENS. GR 1582.000 CCL. GR O. 003 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION . O01CO1 DATE : 97/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1997 00:23 PAGE: **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/05/ 7 ORIGIN · FLIC TAPE NAME : 97182 CONTINUATION # '. I PREVIOUS TAPE : COMMENT : B.P. EXPLORATION, MPE-14, MILNE POINT, API #50-029-22734-00 **** REEL TRAILER **** SERVICE NAM~ : EDIT DATE : 97/05/ 7 ORIGIN '. FLIC REEL NAME : 97182 CONTINUATION # : PREVIOUS REEL '. CO~VlENT : B.P. EXPLORATION, MPE-14, MILNE POINT, API #50-029-22734-00
