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Home My WebLink About198-021 • ,= , Post Office Box 244027 ry Anchorage,AK 99524-4027 Hilcorp Alaska,LLC J U L r3' 0 2U I i 3800 Centerpoint Drive Suite 100 AVGCC Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 ��5us�� 9 2-°'k Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission O�— 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ` , ' " riRe: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp • Origl New I API_WeilNo l PermitNumberl WeliNl ame WellNumber WellNumber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-286/019 2-288 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-308 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/522 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/015 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-46B/S13 2-46B 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/S14 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EIDO1 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/509 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-665D12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/S17 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/L28 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-178 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning ProjecL They are available in the original file and viewable by direct inspection. / ?~'/-(~P.~-/ File Number of Well History File PAGES TO DELETE RESCAN [] Color items- Pages: /~ Grayscale, halftones, pictures, graphs, charts - Poor Quality Original - Pages: Other - Pages: DIGITAL DATA D Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of vadous kinds [] Other Complete COMMENTS: Scanned by: Beverly Mildred Darelh~Natha,,.~/~bwell TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha l~Lowell Date: U[,,~ 3 0 Is/ ~ -~Veil-Complian~ Report File on Left side of folder 198-021-0 MD 12738 _ DUCK IS UNIT SDI TVD 09899. Completion Date: 3-17C/M31 50- 029-21946-03 6/27/98 Completed Status: P&A BP EXPLORATION Current: Name Interval Sent Received T/C/D D 8482 ~,3~' SPERRY GR OH D 8483 ~ SPERRY GR PB1 OH ~ ~0~_.~~~,~,3.,~73~ ~1,~/~ ! ~~ o, L DGR-MD ~L 12202-12870 PBI Glil/q~ OH [ ~o~-~w L DGR-TVD ~L 9575-9900_.. PBI ~/ll/~~ OH R SRVY RPT ~RY 12150.25-12738 OH Daily Well Ops Was the well cored? yes ~" 7/15/98 7/15/98 7/15/98 7/15/98 7/22/98 7/22/98 7/22/98 7/22/98 7/22/98 7/22/98 7/22/98 7/22/98 1/19/99 1/25/99 Are Dry Ditch Samples Required? yes ~__And Receiv~ Analysis Description Recei~~ir6'-~-~Smnple Set # Comments: Tuesday, May 30, 2000 Page 1 of I ~LLTGGI~?C & LOCA. TION C---'A~.~C,F. REPORT State cf Alaska . ALASF-~ OIL &GAS CONSERVATION CO~HISSION ~,, ~_, ~,o. ¢7- oo~/. Review the well file, and-cerumen: on plugging, well head .~Zu?s:s u anus, and ~~-/--- ~!acaC~n $! ear an ce ~m~e~. /~//?Clear Code STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT 1. Status of Well Classification of Servi~e, ~e]l ~ , -,~.~ I~ Oil [] Gas [~] Suspended [~ Abandoned [] Service &iaska Ofi ~L~as Cons, 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-0021 398-166 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21946-03 4. Location of well at surface ~~~ 9. Unit or Lease Name 2755' NSL, 799' WEL, SEC. 8, T11N, R17E, UM i~' ~,~ I: Duck Island Unit/Endicott At top of productive interval ]i~11 :~~m'- i't 10. Well Number N/A~ 3-17C/M-31 At total depth : 11. Field and Pool 3332' NSL, 1333' WEL, SEC. 5, T11N, R17E, UM Endicott Field / Endicott Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 56'I ADL047502 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 12738 9899 FTI 12111 9492 FTI [~Yes I~NoI N/AMDI 1465' (Approx.) 22. Type Electric or Other Logs Run MWD/GR 23. CASlNG~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-FrOM SIZE CEMENTING RECORD AMOUNT PULLED 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) None N/A MD TVD MD TVD 2'6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. .......... DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Cement Retainer set at 12111' w/5 bbls 'G' 27. PRODUCTION TEST 0RIGId,^, Date First Production I Method of Operation (Flowing, gas lift, etc.) ~ ~'~ L Not on ProductionI N/A Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD 1 Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MOF WATER-BEE OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Isb'~ 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. N/A 31. List of ,~ttachm~nts .......................~. Summary of Daily Drilling Reports, Surveys~ :~2. I h~'rebYsigned certify,L~ .-.~,~th~ ~e fo rer~ oi'r~///~C~,~.is t rue~r~cprrect~ to the best of my knowledge /ta/tee~//~¢! Da,,~ coc~!,~ l.//&r,/'.~-"~- / Title ...Drilling Superintendent ........ D .......... ILCf-,/' ""~ 98-0~)~1 398-166 Prepared By Name/Number: Carol Withey, 564-4114 3-17C/M-31 Well Number Permit No_. / Approval No. ...... INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Progress Report Facility End SDI Well 3-17C/M-31 Rig Doyon 15 Page 1 Date 18 January 99 Date/Time 03 Jun 98 06:00-06:30 06:30-08:00 08:00-13:00 13:00-18:00 18:00-18:30 18:30-00:00 04 Jun 98 00:00-01:30 01:30-02:00 02:00-06:00 06:00-06:30 06:30-08:00 08:00-18:00 18:00-18:30 18:30-21:00 21:00-21:30 21:30-22:30 22:30-06:00 05 Jun 98 06:00-06:30 06:30-15:00 15:00-16:00 16:00-16:30 16:30-17:30 17:30-18:00 18:00-18:30 18:30-21:30 21:30-22:30 22:30-06:00 06 Jun 98 06:00-06:30 06:30-12:30 12:30-13:00 13:00-13:30 13:30-14:00 14:00-18:00 18:00-18:30 18:30-21:00 21:00-21:30 21:30-04:30 07 Jun 98 04:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-21:30 21:30-22:30 22:30-23:30 23:30-06:00 08 Jun 98 06:00-06:30 06:30-07:00 07:00-18:00 18:00-18:30 18:30-06:00 09 Jun 98 06:00-06:30 06:30-11:30 Duration 1/2 hr 1-1/2 hr 5hr 5 hr 1/2 hr 5-1/2 hr 1-1/2 hr 1/2 hr 4 hr 1/2 hr 1-1/2 hr 10hr 1/2 hr 2-1/2 hr 1/2hr lhr 7-1/2 hr 1/2 hr 8-1/2 hr lhr 1/2 hr 1 hr 1/2 hr 1/2 hr 3 hr 1 hr 7-1/2 hr 1/2 hr 6hr 1/2 hr 1/2 hr 1/2 hr 4 hr 1/2 hr 2-1/2 hr 1/2 hr 7 hr 1-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1/2 hr 1/2 hr 2hr lhr 1 hr 6-1/2 hr 1/2 hr 1/2 hr llhr 1/2 hr 11-1/2 hr 1/2 hr 5 hr Activity Held safety meeting Serviced Fluid system Skid rig Rig moved 100.00 % Held safety meeting Rigged up Drillfloor / Derrick Retrieved Hanger plug Removed Xmas tree Rigged up BOP stack Held safety meeting Cleared Mud pump fluid end Tested BOP stack Held safety meeting Retrieved Hanger plug Cleared Mud pumps Made up BHA no. 1 Singled in drill pipe to 8000.0 ft Held safety meeting Singled in drill pipe to 12102.0 ft Serviced Block line Singled in drill pipe to 12181.0 ft Circulated at 12181.0 ft Circulated at 12181.0 ft Held safety meeting Milled Casing at 12182.0 ft Circulated at 12182.0 ft Pulled out of hole to 6000.0 ft Held safety meeting Pulled out of hole to 22.0 ft Pulled BHA Made up BHA no. 2 Serviced Top drive R.I.H. to 6357.0 ft Held safety meeting R.I.H. to 12182.0 ft Circulated at 12182.0 ft Milled Casing at 12201.0 ft Circulated at 12201.0 ft Held safety meeting Pulled out of hole to 1157.0 ft Held safety meeting Pulled out of hole to 25.0 ft Pulled BHA Made up BHA no. 3 Circulated at 281.0 ft Pulled out of hole to 270.0 ft R.I.H. to 11800.0 ft Held safety meeting R.I.H. to 12201.0 ft Drilled to 12212.0 ft Held safety meeting Drilled to 12420.0 ft Held safety meeting Drilled to 12453.0 ft Progress Report Facility End SDI Well 3-17C/M-31 Rig Doyon 15 Page 2 Date 18 January 99 Date/Time 11:30-13:00 13:00-13:30 13:30-16:30 16:30-18:00 18:00-18:30 18:30-06:00 10 Jun 98 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 11 Jun 98 06:00-06:30 06:30-07:00 07:00-11:30 11:30-14:30 14:30-18:00 18:00-18:30 18:30-21:00 21:00-22:30 22:30-02:00 12 Jun 98 02:00-03:00 03:00-06:00 06:00-06:30 06:30-08:00 08:00-10:00 10:00-11:00 11:00-11:30 11:30-12:00 12:00-18:00 18:00-18:30 18:30-01:00 13 Jun 98 01:00-02:00 02:00-03:00 03:00-03:30 03:30-05:30 05:30-06:00 06:00-06:30 06:30-12:00 12:00-13:30 13:30-14:30 14:30-15:00 15:00-18:00 18:00-18:30 18:30-20:30 20:30-21:30 21:30-22:00 22:00-06:00 14 Jun 98 06:00-06:30 06:30-08:00 08:00-09:30 09:30-10:30 10:30-12:30 12:30-18:00 18:00-18:30 18:30-19:00 Duration 1-1/2 hr 1/2 hr 3 hr 1-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1/2 hr 4-1/2 hr 3 hr 3-1/2 hr 1/2 hr 2-1/2 hr 1-1/2 hr 3-1/2 hr 1 hr 3 hr 1/2 hr 1-1/2 hr 2 hr lhr 1/2 hr 1/2 hr 6 hr 1/2 hr 6-1/2 hr lhr lhr 1/2 hr 2hr 1/2 hr 1/2 hr 5-1/2 hr 1-1/2 hr 1 hr 1/2 hr 3 hr 1/2 hr 2hr 1 hr 1/2 hr 8hr 1/2 hr 1-1/2 hr 1-1/2 hr lhr 2 hr 5-1/2 hr 1/2 hr 1/2 hr Activity Circulated at 12453.0 ft Pulled out of hole to 12170.0 ft Washed to 12z~53.0 ft Drilled to 12461.0 ff Held safety meeting Drilled to 12610.0 ft Held safety meeting Drilled to 12725.0 ft Held safety meeting Drilled to 12870.0 ft Held safety meeting Circulated at 12870.0 ft Pumped out of hole to 11888.0 ft Circulated at 11888.0 ft Pulled out of hole to 4535.0 ft Held safety meeting Pulled out of hole to 281.0 ft Pulled BHA Tested All functions Made up BHA no. 4 R.I.H. to 9000.0 ft Held safety meeting R.I.H. to 11600.0 ft Circulated at 11600.0 ft Serviced Block line R.I.H. to 12160.0 ft R.I.H. to 12233.0 ft Reamed to 12462.0 ft Held safety meeting Reamed to 12490.0 ft Pumped out of hole to 12170.0 ft Circulated at 12170.0 ft Pumped out of hole to 11888.0 ft Circulated at 11888.0 ft Pulled out of hole to 10500.0 ft Held safety meeting Pulled out of hole to 271.0 ft Pulled BHA Made up BHA no. 5 Serviced Top drive R.I.H. to 5484.0 ft Held safety meeting R.I.H. to 11888.0 ft Circulated at 11888.0 ft R.I.H. to 12218.0 ft Reamed to 12423.0 ft Held safety meeting Reamed to 12435.0 ft Pumped out of hole to 11798.0 ft Circulated at 11798.0 ft Circulated at 11798.0 ft Pulled out of hole to 1985.0 ft Held safety meeting Pulled out of hole to 191.0 ft Progress Report Facility End SDI Well 3-17C/M-31 Rig Doyon 15 Page 3 Date 18 January 99 Date/Time 19:00-19:30 19:30-01:30 15 Jun 98 01:30-03:00 03:00-04:00 04:00-04:15 04:15-04:30 04:30-04:45 04:45-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-07:00 07:00-12:00 12:00-13:30 13:30-14:00 14:00-18:00 18:00-18:30 18:30-19:00 19:00-20:00 20:00-21:00 21:00-22:00 22:00-23:30 23:30-00:00 16 Jun 98 00:00-00:30 00:30-02:00 02:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 17 Jun 98 06:00-06:30 06:30-07:30 07:30-08:30 08:30-09:00 09:00-12:00 12:00-14:30 14:30-18:00 18:00-18:30 18:30-21:00 21:00-22:00 22:00-01:00 18 Jun 98 01:00-02:00 02:00-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-09:00 09:00-09:30 09:30-13:30 13:30-14:00 14:00-18:00 18:00-18:30 18:30-06:00 19 Jun 98 06:00-06:30 Duration 1/2 hr 6hr 1-1/2 hr 1 hr 1/4hr 1/4 hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 5 hr 1-1/2 hr 1/2 hr 4 hr 1/2 hr 1/2 hr lhr 1 hr 1 hr 1-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 4 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1 hr 1 hr 1/2 hr 3 hr 2-1/2 hr 3-1/2 hr 1/2 hr 2-1/2 hr 1 hr 3 hr 1 hr 4 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 4hr 1/2 hr 4hr 1/2 hr 11-1/2 hr 1/2 hr Activity Pulled BHA Ran Drillpipe in stands to 12355.0 ft Circulated at 12355.0 ft Rigged up Cement unit Held safety meeting Tested High pressure lines Mixed and pumped slurry - 5.500 bbl Displaced slurry - 35.000 bbl Pulled Drillpipe in stands to 11985.0 ft Reverse circulated at 11985.0 ft Held safety meeting Held 2000.0 psi pressure on 2.300 bbl squeezed cement Pulled out of hole to 0.0 ft Made up BHA no. 6 Tested MWD - Via string R.I.H. to 9320.0 ft Held safety meeting R.I.H. to 11800.0 ft Serviced Block line Washed to 12180.0 ft Circulated at 12180.0 ft Washed to 12208.0 ft Drilled cement to 12213.0 ft Pulled out of hole to 12180.0 ft Circulated at 12180.0 ft Drilled to 12222.0 ft Held safety meeting Drilled to 12886.0 ft Held safety meeting Drilled to 12343.0 ft Held safety meeting Drilled to 12374.0 ft Pumped out of hole to 12144.0 ft Serviced Draw works Circulated at 12144.0 ft Circulated at 12144.0 ft Pulled out of hole to 6400.0 ft Held safety meeting Pulled out of hole to 161.0 ft Pulled BHA Tested All functions Made up BHA no. 7 R.I.H. to 9000.0 ft Held safety meeting R.I.H. to 12170.0 ft Circulated at 12170.0 ft Fill pits with Lo/Hi vis combination Cleared Flowline Circulated at 12170.0 ft R.I.H. to 12374.0 ft Drilled to 12444.0 ft Held safety meeting Drilled to 12560.0 ft Held safety meeting Progress Report Facility End SDI Well 3-17C/M-31 Rig Doyon 15 Page 4 Date 18 January 99 Date/Time 06:30-07:00 07:00-07:30 07:30-08:30 08:30-09:30 09:30-18:00 18:00-18:30 18:30-06:00 20 Jun 98 06:00-06:30 06:30-08:00 08:00-09:00 09:00-09:30 09:30-11:00 11:00-12:30 12:30-15:00 15:00-16:30 16:30-18:00 18:00-18:30 18:30-21:30 21:30-22:30 22:30-23:00 23:00-03:30 21 Jun 98 03:30-04:30 04:30-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-21:30 21:30-23:00 23:00-03:30 22 Jun 98 03:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-12:00 12:00-13:00 13:00-14:00 14:00-14:30 14:30-15:30 15:30-18:00 18:00-18:30 18:30-06:00 23 Jun 98 06:00-06:30 06:30-18:00 18:00-18:30 18:30-02:00 24 Jun 98 02:00-03:00 03:00-05:00 Duration 1/2 hr 1/2 hr 1 hr 1 hr 8-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1-1/2 hr 1 hr 1/2 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 3 hr 1 hr 1/2 hr 4-1/2 hr 1 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 10-1/2 hr 1/2 hr 1 hr 1 hr 1 hr 1-1/2 hr 4-1/2 hr 1/2 hr lhr 1 hr 1/2 hr 1/2 hr 1/2 hr 4-1/2 hr lhr 1 hr 1/2 hr 1 hr 2-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 7-1/2 hr 1 hr 2 hr Activity Drilled to 12569.0 ft Circulated at 12569.0 ft Pumped out of hole to 12170.0 ft R.I.H. to 12569.0 fi Drilled to 12644.0 ft Held safety meeting Drilled to 12738.0 ft Held safety meeting Circulated at 12738.0 ft Pumped out of hole to 12170.0 ft R.I.H. to 12738.0 fi Circulated at 12738.0 ft Worked stuck pipe at 12738.0 ft Pumped out of hole to 11702.0 ft Circulated at 11702.0 ft Pulled out of hole to 8689.0 ft Held safety meeting Pulled out of hole to 187.0 ft Pulled BHA Made up BHA no. 9 R.I.H. to 11702.0 ft Circulated at 11702.0 ft R.I.H. to 12375.0 fi Reamed to 12579.0 ft Held safety meeting Worked toolstring at 12575.0 ft Pumped out of hole to 12380.0 ft Reamed to 12725.0 ft Held safety meeting Reamed to 12738.0 ft Circulated at 12738.0 ft Pumped out of hole to 11702.0 ft Circulated at 11702.0 ft Pulled out of hole to 109.0 ft Pulled BHA Made up BHA no. 10 R.I.H. to 3000.0 ft Held safety meeting Fill pits with Brine Tested MWD - Via string R.I.H. to 11702.0 ft Circulated at 11702.0 ft Serviced Block line R.I.H. to 12181.0 ft Set tool face Reamed to 12377.0 ft Held safety meeting Reamed to 12620.0 ft Held safety meeting Reamed to 12645.0 ft Held safety meeting Reamed to 12720.0 ft Worked stuck pipe at 12720.0 ft Pumped out of hole to 11702.0 ft Progress Report Facility End SDI Well 3-17C/M-31 Rig Doyon 15 Page 5 Date 18 January 99 Date/Time 25 Jun 98 26 Jun 98 27 Jun 98 05:00-06:00 06:00-06:30 06:30-12:30 12:30-14:00 14:00-18:00 18:00-18:30 18:30-21:30 21:30-22:00 22:00-22:30 22:30-23:30 23:30-06:00 06:00-06:30 06:30-08:00 08:00-14:30 14:30-16:00 16:00-16:30 16:30-18:00 18:00-18:30 18:30-23:00 23:00-23:30 23:30-05:00 05:00-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-10:00 10:00-14:30 14:30-17:30 17:30-18:00 18:00-18:30 18:30-20:00 20:00-21:30 21:30-01:30 01:30-03:00 03:00-06:00 06:00-06:30 06:30-08:30 08:30-09:30 09:30-12:00 12:00-13:00 13:00-14:30 14:30-16:30 16:30-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-21:30 Duration lhr 1/2 hr 6 hr 1-1/2 hr 4hr 1/2 hr 3hr 1/2 hr 1/2 hr 1 hr 6-1/2 hr 1/2 hr 1-1/2 hr 6-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 5-1/2 hr 1 hr 1/2 hr 1-1/2 hr 1 hr 1 hr 4-1/2 hr 3 hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 4 hr 1-1/2 hr 3 hr 1/2 hr 2 hr 1 hr 2-1/2 hr 1 hr 1-1/2 hr 2 hr 1-1/2 hr 1/2 hr 1 hr lhr 1 hr Activity Circulated at 11703.0 ft Held safety meeting Pulled out of hole to 110.0 ft Pulled BHA Ran Drillpipe in stands to 7093.0 ft Held safety meeting Ran Drillpipe in stands to 12130.0 ft Rigged up Cement unit Circulated at 12130.0 ft Pulled Drillpipe in stands to 11607.0 ft Pulled Drillpipe in stands to 0.0 ft Held safety meeting Made up BHA no. 10 R.I.H. to 11702.0 ft Circulated at 11702.0 ft R.I.H. to 12181.0 ft Circulated at 12181.0 ft Held safety meeting Pulled out of hole to 193.0 ft Pulled BHA Ran Drillpipe in stands to 12030.0 ft Washed to 12110.0 ft Held safety meeting Functioned Cement retainer Mixed and pumped slurry - 5.000 bbl Circulated at 12111.0 ft Pulled out of hole to 1794.0 ft Pulled out of hole to 0.0 ft Ran Drillpipe to 1880.0 ft (2-3/8in OD) Held safety meeting Reverse circulated at 1888.0 ft Laid down 1888.0 ft of 2-3/8in OD drill pipe Ran Drillpipe to 10951.0 ft (2-3/8in OD) Circulated at 10951.0 ft Laid down 5751.0 ft of 2-3/8in OD drill pipe Held safety meeting Laid down 3700.0 ft of 2-3/8in OD drill pipe Freeze protect well - 22.000 bbl of Diesel Laid down 1500.0 ft of 2-3/8in OD drill pipe Installed Hanger plug Rigged down Drillfloor / Derrick Rigged down BOP stack Installed Xmas tree Held safety meeting Cleared Sand traps Retrieved Hanger plug Skid rig Endicott Alaska State Plane Zone 3 Endicott SDI 3- ~ 7C/M-3 ~ S UR VEY REPORT 7 July, 1998 Your Ref: API-500292194603 Cast Survey Date 20.June-98 Job# AKMWS0251 KBE- 56.00' DRILLING SERVICES 008912.6 ORIGINAL RECEIVED JUl ~ 1 1998 l~P~ pDC Survey Reft svy426 Sperry-Sun Drilling Services Survey Report for 3-17C/M-31 Your Ref: API-500292194603 Endicott Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 12150.25 27.575 256.782 9474.60 9530.60 12181.00 28.110 255.690 9501.79 9557.79 12213.00 28.990 260.600 9529.90 9585.90 12232.50 29.110 263.550 9546.95 9602.95 12262.51 29.250 267.970 9573.15 9629.15 12293.08 33.220 270.660 9599.29 9655.29 12327.16 32.900 275.260 9627.85 9683.85 12349.06 34.370 275.560 9646.09 9702.09 12376.95 36.710 279.010 9668.78 9724.78 12405.78 41.240 278.910 9691.19 9747.19 12437.48 42.820 277.090 9714.74 9770.74 12469.19 45.900 282.510 9737.41 9793.41 12499.65 50.670 283.120 9757.68 9813.68 12537.17 56.380 285.810 9779.98 9835.98 12566.25 61.600 285.180 9794.95 9850.95 12595.21 66.550 287.870 9807.61 9863.61 12632.22 72.470 290.240 9820.56 9876.56 12662.99 78.630 289.860 9828.24 9884.24 12738.00 78.630 289.860 9843.02 9899.02 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 5779.50 N 127.84W 5976754.54'N 270292.51E 1859.85 5776.08 N 141.79W 5976751.55 N 270278.47 E 2.404 1872.13 5772.95 N 156.74W 5976748.88 N 270263.42 E 7.829 1885.45 5771.65 N 166.12W 5976747.86 N 270254.01 E 7.371 1894.00 5770.57 N 180.70W 5976747.23 N 270239.40 E 7.195 1907,58 5770.40 N 196.55W 5976747.54 N 270223.56 E 13.762 1922.64 5771.36 N 215.10W 5976749.07 N 270205.04 E 7.421 1940.63 5772.50 N 227.18W 5976750.58 N 270193.01E 6.755 1952.49 5774.57 N 243.25W 5976753.14 N 270177.01E 11.047 1968.44 5777.39 N 261.16W 5976756.51 N 270159.19 E 15.714 1986.37 5780.34 N 282.17W 5976760.10 N 270138.28 E 6.294 2007.29 5784.14 N 304.00W 5976764,56 N 270116.58 E 15.393 2029.25 5789.18 N 326.16W 5976770.29 N 270094,58 E 15.731 2051.90 5796.74 N 355.35W 5976778.73 N 270065.64 E 16.272 2082.02 5803.39 N 379.36W 5976786.12 N 270041.84 E 18.046 2106.92 5810.81 N 404.32W 5976794.30 N 270017.13 E 19.023 2132.95 5822.14 N 437.06W 5976806.62 N 269984.74 E 17.082 2167.58 5832.35 N 465,04W 5976817.68 N 269957.09 E 20.055 2197.34 5857.33 N 534.20W 5976844.77 N 269888.72 E 0.000 2270.81 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 287.500° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12738.00ft., The Bottom Hole Displacement is 5881.64ft., in the Direction of 354.789° (True). Comment Tie-on Survey Window Point Projected Survey Alaska State Plane Zone 3 Endicott SDI Continued...' 7 July, 1998 - 9:11 - 2 - DrillQuest Endicott Sperry-Sun Drilling Services Survey Report for 3-17C/M-31 Your Ref: API-500292194603 Alaska State Plane Zone 3 Endicott SDI Comments Measured Depth (ft) 12150.25 12213.00 12738.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 9530.60 5779.50 N 127.84 W 9585.90 5772.95 N 156.74 W 9899.02 5857.33 N 534.20 W Comment Tie-on Survey Window Point Projected Survey 7 July, 1998 - 9:11 - 3 - DrillQuest Directional Survey Calculator Report Well: 3-17C/M-31PB1 Access Date and Time: Thu Jun 25 00:34:11 1998 Facility: End SDI Operator: BP Exploration Ail Depths relative to BRT . Listing contains: 21 points. Vertical Section Details: Origin North Origin East (ft) (ft) 0.00 0.00 Section Azimuth Max Depth(TVD) (deg) (ft) 287.50 Applied to TD Tie In Details: MD Inc Azi North East TVD (ft) (deg) (deg) (ft) (ft) (ft) 12150.25 27.580 256.780 5779.53 -127.84 9530.60 Survey Instrument Depth Range Summary: Instrument MWD - Standard (declination corrected) Start(ft) End(ft) 12181.00 12821.53 Corrected Survey Data Computed Positional Information Travelling Cylinder Co-ords Stn Measured Drl Grid Local 3-D Co-ordinates Vertical Relative Radial Relative No Depth Inc Azi North East TVD DLS Section Depth Dist Azimuth (ft) (deg) (deg) (ft) (ft) (ft) (deg/100ft) (ft) (ft) (ft) (deg) 1 12181.00 28.110 255.690 5776.11 -141.79 9557.79 2.390 1872.14 12180.86 0.477 76.717 2 12221.06 27.630 257.270 5771.73 -160.00 9593.20 2.199 1888.18 12220.85 1.446 80.877 3 12253.03 29.720 258.330 5768.50 -174.99 9621.25 6.728 1901.51 12252.51 4.104 96.841 4 12282.91 32.860 259.200 5765.48 -190.21 9646.78 10.617 1915.12 12281.79 7.474 106.728 5 12315.20 37.150 260.040 5762.15 -208.43 9673.22 13.369 1931.49 12313.05 11.662 116.017 6 12349.14 41.960 260.820 5758.57 -229.73 9699.39 14.247 1950.73 12345.46 16.554 125.181 7 12381.41 46.730 261.540 5755.11 -252.02 9722.46 14.863 1970.95 12375.83 21.717 133.374 8 12410.39 50.810 263.110 5752.21 -273.61 9741.55 14.656 1990.67 12402.77 26.718 139.929 9 12442.32 54.170 270.710 5750.89 -298.87 9761.01 21.604 2014.36 12432.33 31.619 144.250 10 12473.29 57.570 273.290 5751.79 -324.48 9778.39 12.963 2039.06 12460.94 35.545 146.182 11 12503.23 60.670 276.730 5754.05 -350.07 9793.75 14.296 2064.14 12488.43 39.070 147.146 12 12535.83 64.870 278.090 5757.79 -378.81 9808.67 13.406 2092.68 12518.18 42.671 147.830 13 12567.20 69.510 280.220 5762.40 -407.34 9820.83 16.060 2121.28 12548.95 45.190 148.453 14 12599.71 73.070 283.090 5768.63 -437.49 9831.26 13.777 2151.90 12581.43 45.287 149.853 15 12631.74 75.860 287.870 5776.87 -467.22 9839.84 16.809 2182.73 12613.33 42.710 151.147 16 12662.36 78.750 289.280 5786.39 -495.53 9846.57 10.453 2212.59 12643.58 38.077 152.638 17 12693.96 79.030 289.030 5796.56 -524.82 9852.66 1.178 2243.59 12674.23 32.630 156.314 18 12727.19 79.640 292.370 5808.10 -555.36 9858.81 10.047 2276.19 12705.93 27.055 163.504 19 12758.17 77.210 296.030 5820.54 -583.04 9865.03 13.980 2306.32 12735.58 21.860 171.128 Corrected Survey Data Computed Positional Information Travelling Cylinder Co-ords Stn Measured Drl Grid Local 3-D Co-ordinates Vertical Relative Radial Relative No Depth Inc Azi North East TVD DLS Section Depth Dist Azimuth (ft) (deg) (deg) (ft) (ft) (ft) (deg/100ft) (ft) (ft) (ft) (deg) 20 12787.44 74.590 298.430 5833.52 -608.28 9872.16 11.973 2334.30 12763.82 17.442 177.540 21 12821.53 70.960 301.510 5849.77 -636.48 9882.25 13.705 2366.08 12797.00 13.069 181.720 3-17B/M-31 parent well (proj onto view) EMG 6124198 STATE OF ALASKA ALASI'~,'-OIL AND GAS CONSERVATION COT~MISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program' [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2524' SNL, 799' WEL, SEC. 8, T11N, R17E, UM At top of productive interval N/A At effective depth 3288' NSL, 234' WEL, SEC. 5, T11 N, R17E, UM At total depth 3288' NSL, 234' WEL, SEC. 5, T11N, R17E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 56' 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 3-17C/M-31 9. Permit Number 98-0021 10. APl Number 50-029-21946-03 11. Field and Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured 12738 feet true vertical 9861 feet Effective depth: measured 12738 feet true vertical 9861 feet Plugs (measured) Junk (measured) Casing Length Size Cemented :-*'- MD TVD Structural Conductor 142' 30" Driven .... '~- 142' 142' Surface 2498' 13-3/8" 4185 c.f. Permafrost 2498' 2496' Intermediate 10520' 9-5/8" 575 c.f. Class 'G' 10520' 8095' Production ~-~ Liner 2844' 4-1/2" 218 c.f. Class 'G' 10338'-13182' 7976'-10079' Perforation depth: measured N/A RECEIVED true vertical N/A ~ ~-D . 1 (5 1998 Tubing (size, grade, and measured depth) 4-1/2" 12.6# L80 to 10324' ~aska0il & Gas 00ns. O0mrnlssi0~ Anchorage Packers and SSSV (type and measured depth) 4-1/2" SVLN at 1522'; 9-5/8" TIW HBBPT Packer at 10266'; 7" ZXP Baker Liner Packer at 10312' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 4. Estimated date for commencing operation September 18, 1998 16. If proposal was verbally approved Blair Wondzell Name of approver 9/15/98 Date approved 15. Status of well classifications as: [] Oil [--~ Gas [] Suspended Service Contact Engineer Name/Number: Chris West, 564-5089 Prepared By Name/Number: Carol W/they, 564-4114 17. I hereby certify that the fo, regoing is true end correct to the best of my knowledge s,.ned Lowell Cran T~,-le Drilling Engineering Supervisor ' ~ Commission Use Only Conditions of Approval: Notify Commission so representative may witness Date I Approval No: Plug integrity ¢ BOP Test ~ Location clearance__ ~, ¢~ MechaQical Integrity Test Subsequent form requi, r.,~d 10- -- . ........ -_.-,O~'~;>~-,._~;/?:(4 ~ ~ Commissioner Appro~¢.,~ by order of the'Commission , ;.'~ ~:~yll~u Dy Form 10-403 Rev. 06/15/88 ,.avia W. Johnston Submit In Triplicate SDI 3-17C/M-31 SUMMARY PROCEDURE COMMENTS 1. The 9-5/8" x 4-1/2" production packer is a Baker permanent packer with a tubing seal assembly above. The packer and tubing will not be recovered. 2. The existing perfora{ions were plugged with cement and the previous sidetrack window is plugged with a cement retainer. 3. This well will be sidetracked at app. 11,200 feet. PRE-RIG OPERATIONS 1. Pressure test IA (tubing and annulus) to 3,500psi. Circulate kill weight fluid (estimated BHP at 9850'SS is 5000psi - 9.76 ppg EMW). 2. RU wireline, Pull the WL SSSV. Drift and dummy off gas lift mandrels. 3. Drift 4-1/2" tubing and liner for 3.80" whipstock assy. 4. Check that the well is dead. Freeze protect the top 200' with diesel. Set BPV and test. If rig move is delayed more than 2 days freeze protect to 500 feet 5. Remove flowlines, level pad. RIG OPERATIONS (SUMMARY) 1. Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. 2. Check that the well is dead. If not, attempt bleed off pressure. If unable to bleed off pressure, Pull BPV, RU slickline and pull btm glv.circ well w/brine or milling fluid until dead. 3. If well is dead, pull BPV. Run TWC and test. ND the tree, and NU the BOPE. Test the BOPE and pull TWC. 4. Rig up on E-Line. Run and set DW-1 Packer with orientating sub. Verify lug orientation for eccentric weight bars to determine anchor and whipstock alignment. 5. Run whipstock and anchor on drill pipe. Set Whipstock face + 10 ° right of high side. 6. Pick up 2-3/8" Drillpipe and Milling BHA. 7. Cut TTRD window through 4.5" liner and 20 feet of new hole. 8. Pick up Sperry directional BHA to turn and build @ 12°/100 feet to 50° at appx 11445' MD. Hold 50° to 12085' md, drop to 20° at 12456' md and hold 20° to TD at +/- 12900' ..- MD. . 10. 11. 12. 13. 14. If there are hole problems, run a 3.75" Baker fixed blade HO over whole interval and spot lubricant in OH section. POOH. Run a 2.875" solid liner from 10,311 to 12898' MD, cement as per plan. POOH. RIH with inner string to displace to KWB. (2 days). Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. Set the BPV. ND the BOPE, and NU the tree. Shear the RP valve and freeze protect the well. Turn the well over to Production. TREE: 4-1/16" / 5000 psi/CIW/Baker A..~tors WELLHEAD: 13-5/8" / 5000 psi/'FMC SSH Big Bore ., ,Sidetrack 4 1/2" L-80 IBM TBG. 12.6 #/FT 9-5/8', 47#/ft NTSOS XO to NT95HS NOTE: SECTION WINDOW IN 9 5/8 CASING FROM 10500' -10550' 10312' 0338' 7" ZXP BAKER LINER PKR 7" X 4.5" XO (3.875" ID) CO SIZE SPF INTERVAL SWS 2-7/8 6 12,812- 12,822 Sqzd SWS 2-7/8 6 12,916-12,931 Sqzd SWS 2-7/8 6 13,086 13,098 Sqzd AWS 2-7/8 6 13,116 13,136 Sqzd , 4,.5 HYRIL 511 CASING 12.6 #/F-:T (3.958" ID) PBTD 5" SHOE 12111 RT ELEV= 56' BF ELEV-- 17.2 MAX. DEV. = 27 DEG. ~ SSSV LANDING NIPPLE I 1522 HES "HXO" (3.813" ID) 4.5 X 1.5 CAMCO "TB" 9CR GLM'S.. RA LATCHES CAMCO 'qB" 9 OR ==~62u=~' :3504' Tvr) . 6326' 5253' 7936' 6291' 9009' 7009' 10031' 7711' 10186' 17815' {4-1/2" "X" NIPPLE ~9 5/8 X 7 tlW HB-BP-T PACKER (3.9.35 ID) 4-1/2" 'X" NIPPLE [UdES)_(3_._a_13" ~D) 4-1/2" "XN" NIPPLE (Milled out to 3.81" ID) NOTE: 4-1/2" WLIEG ELMD 10255' 10266' HOLE IS TEMPORARILY ABANDONED CEMENT RETAINER SET AT 12111' MD. WELL LOADED WITH 10.2 PPG BRINE W/1500' DIESEL FREEZE PROTECT Cement retainer SA 12,111 with cement ~ on top Initial 3-17c/M-31 sidetrack attempt filled with cement. Previous window at 12,195' MD. SF, P 2 Date 6/27/98 9/23/98 Comments HOLE ABANDONED Current Mechanical Condition ENDICO'I-r WI=LL: 3-ITc/M-31 APl NO:_ COMPLETION DIAGRAM BP INC MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnsteri~ DATE: Chairman ~ THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor FROM: John Spaulding~ SUBJECT: Petroleum inst. ' - September 19, 1998 alhlisfe.doc Confidential' Yes No X BOPE Test Doyon 15 BPX / DIU / 3-17C / M-31 PTD 98-0021 September 19, 1998' I traveled to BPX's Duck Island Unit to witness the BOPE Test on Doyon rig 15. The AOGCC BOPE Test report form is attached for reference. The rig has been down for summer maintenance and was found to be very good condition. As noted on the test report no failures were observed. The accumulator system appeared to slightly Iow (2700 psi), requested the toolpusher to have the pressure raised to the normal working range (3000 psi). Summary: I witnessed the BOPE Test on; Doyon ~ 9119198, test time ~ hours, 0 failures Attachments: alhlisfe.xis STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: Doyon Rig No. BPX/Alaska 3-17C/M-31 Set @ Weekly Other 1'5 PTD Ct Rep.: Rig Rep.: Location: Sec. DATE: 9/19/98 98-0021 Rig Ph. Ct 659-6510 E. Vaughn J. Willingham 8 T, 11N R, 17E Meridian UM TEST!DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok PTD On Location yes Standing Order Posted BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve (Gen) yes Well Sign yes Drl. Rig ok Hazard Sec. yes Quan. Test Press. P/F 1 250/250O P I 250/5,000 P 1 250/5, 000 P 1 250/5, 000 P 1 250/5,000 P 2 250/5,000 P 1 250/5, OOO P N/A 250/5, 000 MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok H2S Gas Detector ok ok FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quan Pressure P/F I 250/5,000 P I 250/5,000 P I 250/5,000 P 1 250/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 13 250/5,000 P 26 250/5, 000 P 2 P Functioned Functioned ACCUM U LATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: 4 @ 2200 avg. 2, 700 P 1,400 P minutes 38 sec. minutes 40 sec. x' Remote: x' Psig. TEST~RESULTS:.; : : : Number of Failures: 0 ,Test Time: 3.5 Hours. Number of valves tested 19 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to tl'~e AOGCC Commission office at: Fax NO. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: pressure increased. Very good test!! The Accumulator system pressure appeared to be slighly Iow,: requested the toolpusher to have the Distribution: Grig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spaulding FI-021L (Rev.12/94) Alhlisfe.xls WELL LOG TRANSMITTAL To: State of Alaska July 22, 1998 Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor Anchorage, Alaska 99501 ~!: /~ ~ ~.}fj~ \ RE: MWD Formation Evaluation Logs 3-17C/M-31 & 3-17C PB1/M-31, .~-MW-80251 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of.' .Mi Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 3-17C/M-31: 2" x 5" MD Gamma Ray Logs: 50-029-21946-03 TVD Gamma Ray Logs: 50-029-21946-03 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 3-17C PB1/M-31: 2"x 5"MD Gamma Ray Logs: 50-029-21946-70 11 x 5 TVD Gamma Ray Logs: 50-029-21946-70 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax 907) 563-7252 A Division of Dresser Industries, Inc. WELL LOG TRANSMTUFAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Drive. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - 3-17C/M-31 & 3-17C PB1/M-31, July 15, 1998 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.' Ali Turker? Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, ~AK 99518 2 LDWG formatted Discs with verification listing. API#: 50-029-21946-03 & 50-029-21946-70 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries. inc. STATE OF ALASKA ALASKA-~,'L AND GAS CONSERVATION COIV~-IISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [~Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2755' NSL, 799' WEL, SEC. 8, T11 N, R17E, UM At top of productive interval N/A At effective depth 3288' NSL, 234' WEL, SEC. 5, T11N, R17E, UM At total depth 3288' NSL, 234' WEL, SEC. 5, T11 N, R17E, UM 12. Present well condition summary Total depth: measured 12738 feet true vertical 9861 feet Effective depth: measured 12738 feet true vertical 9861 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) 142' 30" Driven 5. Type of well: [~ Development [] Exploratory I--I Stratigraphic I--IService 6. Datum Elevation (DF or KB) KBE -- 56' 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 3-17C/M-31 9. Permit Number 98-0021 10. APl Number 50-029-21946-03 11. Field and Pool Endicott Field / Endicott Pool _ , Cemented MD TVD 2498' 13-3/8" 4185 c.f. Permafrost 10520' 9-5/8" 575 c.f. Class 'G' 142' 142' 2498' 2496' 10520' 8095' 2844' 4-1/2" 218 c.f. Class 'G' 10338'-13182' 7976'-10079' Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth) 4-1/2" 12.6# L80 to 10324' OFRi®IN,,, Packers and SSSV (type and measured depth) 4-1/2" SVLN at 1522'; 9-5/8" TIW HBBPT Packer at 10266'; 7" ZXP Baker Liner Packer at 10312' 13. Attachments [] Description summary of proposal [-I Detailed operations program [] BOP sketch 4. Estimated date for commencing operation June 24, 1998 16. If proposal was verbally approved Blair Wondzell 6/24/98 Apl)roved by order of the CommissiorOrlqlRa~ ,~Jt,9l'-'~u ,-~) Form 10-403 Rev. 06/15/88 David W. Johnston 15. Status of well classifications as: [~ Oil I--I Gas E~ Suspended Service Carol Withey, 564-4114 I Approval Nor._'~ ~' ~;~,.- / ~ Submit In Triplicate Name of apl)rover Date approve¢ Contact Engineer Name/Number: Chris West, 564-5089 Prepared By Name/Number: efCgoing ,/~ 17. I hereby certify that th is true,and correct to the best of my knowledge Signed r/~'~,.~../~ ~' Lowell C -~--~/ ~" ~ Title Drilling Engineering Supervisor Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity ~-- BOP Test ~ Location clearance ~ Mechanical Integrity Test~ Subsequent forr~equired 10- /,~ cl. F'V~'¢e~.o'. ,~' . ~ "'0....../ Commissioner 3-17C/M-31 SUSPENSION PROCEDURE , . , . . . COMMENTS 1. The Doyon 15 drilling operations on this well have been hampered by formation stability, especially in the HRZ. With drilling fluid weights up to 11.0 ppg, we have not been able to stop the formation from sloughing / running. We need to review the information gathered and plan to re-drill this reservoir target at a future date. 2. The drilling permit is AOGCC Permit Cf 98-0021 RIG OPERATIONS 1. Pick up a cement retainer and RIH to set 50 to 100 feet above window at 12,181' MD. 2. Establish injection rate through the retainer. Unsting from retainer to displace cement to the CR at minimum pressures. Mix and pump 5 BBL sx of class G cement and circulate down the drillpipe. Sting into the retainer and displace 4 BBLS of cement below retainer, unsting to leave 1 bbl of cement on top of the retainer. Circulate the 4.5" tubing with 1.5 volumes of 10.0 ppg brine. Check that the well is dead. Freeze protect the top 500' with diesel. Set BPV. Pump Corrosion inhibitor. (1/2 day) Set the BPV. ND the BOPE, and NU the tree. Shear the RP valve and freeze protect the well. (1/2 day). Turn the well over to Production. RDMO Doyon 15 06/24/98 BP EXPLORATION BP Exploration (Alaska) Inc. g00 East.Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-51tl DATE: TO: Name: tq~t "~(^,.~, Company: /~0 6CC Location: A.~ e..~4t~0AoF-.- Fax Number: TELECOPY FROM: Name: Department: Location: Fax Number: PAGES TO FOLLOW) 3-17C/M-31 C~OMMENT~S~ 1. , , ST PROCEDURE The HRZ while drilling the sidetrack of this well was not stable, and could not be kept clean. : The well witl be sidetracked to the same BHL as permitted in AOGCC permit 98-0021. This well will be sidetracked at app. 12,200 feet. RIG OPERATIONS (SUMMARY) 1, RIH with OEDP and 2.375 stinger to set a 5 BBL cement plug from 12,355 to 12,195' MD. 2. POOH with stinger. 3. Pick up 2-3/8" Drilipipe and 1.5 BHM and HC 335 PDC Directional Drilling BHA to turn and build @ 14°/100 feet to 73° at appx 12,618' MD. Drill ahead as specified by the rig supervisor to CP at 13,153. POOH. (12 days). New directional plan #9 4. If there are hole problems, run a HO over whole interval and spot lubricant in OH section. POOH, 5. Run a 2.875" solid liner from 10,311 to 13,143 MD with inner string, cement as per plan. (2 days). 6. Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. 7. Displace with KW Brine. 8. Pump Corrosion inhibitor. (1/2 day) 9. Set the BPV. ND the BOPE, and NU the tree. Shear the RP valve and freeze protect the well. (1/2 day). 10. Turn the well over to Production. LC) ,rd I DrillQuest Endicott Alaska Stale Plane Zone 3 Endicott SD! 3-17C/M-31 Rig Scale: linch = lOOft Eastings .8~0 -"z~o -s~o .s~)o -4~o -3~o ,. 6100 - 5BOD - '~3 700 - -lOOO ~!]0 · cale: lf=ch = IOIN=t -8OO Ioo05~$ff'rVD f,~@ 68.250°: 12846.42ft MD, 9S95,751t TVD -i I Eastinlls O~r @ 8.oo0'VIO0#: 17.,561,0~ M.D, ,9829.33~tTVD O[r, Sa~ @ 69~9~a°: 12523,37~t MD, I ~ -i I · ~;oo -400 -300 -200 Fle,lerence Is Tr~e N~ortl~ 0 ~art O~r 0 I .= 57Q0~' 14"Jl00lt: 12~95.(~' ' ~1 Endicott Alaska State Plane Zone 3 Endicott SDI 3-17CIM-~1 Rig P: Star{ Dir @ 14°I1001t: 12195.0r. Zt MD, ~570.0~ft TVD Dir, Salt @ 69.g~°: 12523.37# MD, 9782.23f1: TVD D~r @ 8.000"/1001t: 12661,04R MD, 9829.33ft TVI3 1/~50 1950 ,~=ale~ 1Inch = lOGit 2050 I 2150 L k I 2250 2.150 2450 Ymticai SectTon [ DrillQues£ MD, 10005.75ft TVD Sperry-Sun Drilling Services Proposal Report for 3.17C/M.31 RigSt Wp9 Endicott Measured Sub-Sea Vertical Lo;al Coordinates Depth Incl, Azim. Depth Depth Northings Eastlngs (fl) ~t) Ct) (a) (ft} Global Coordinates Dogie9 Northings Easfings Rate (it:) (ft) (V'{Oaft) 12200.08 27~S~3 256,433 9518.5'7 9574.57 5~.93 N 122~0.00 ~,120 260.946 ~570.~ 9~G.52 57~8.13 N 179.95 W 123~.00 ~.0~ 2~.7~7 ~G03.~ 9659.45 5755.55 N 2~38 W 12400.00 49.8~ ~3.935 9~5.97 9731.97 5755.92 N ~D.88 W 1~00.00 ~.0Sl 279.~1 9731.11 ~787.11 5775.94 N ~5~.~9 W 12552.86 70.148 281.879 9752,08 9808,08 5784..95 N 4(~.03 W ~2600.~0 ~.357 287.9~ 0766.~ 9822,~ 5796.49 N 4~.26 W 12618.10 73,~9 2~0.595 9~2.~ 9~5.~ 5~1 N 460,62 W 127~,~ ~.~ 290.595 9795.46 9S51.4G 5~g_82 N 534.09 W 12800.00 73.379 290.595 9824.06 9880.66 5863.52 N 623.79 W 12855.7l 73.379 290.595 9840.U0 9896.00 5582.30 N 673.76 W 129~0.00 70.44G 295.259 9853.76 9909.76 5898.68 N 712.52 W 12949.08 67.342 300.625 9871.4~ 9~27,44 5920.10 N 752.96 W 13060.Q0 67.342 300.625 9891,06 9947.0~ 5944.04 N 793.39 W 13160.Q0 67,342 3(]0.625 9~29~58 9985.58 5991 .O5 N 872.81) W 131,~3.01 57.342 3~0,62E, 9950.00 10006,00 6015.97 N 914,90 W 597b-'749.§S N 270269.75 E 5978744.?6 N 270240.18 E 8.000 597G742.88 N 270217.58 E 14700 59767,~5.34 N 270149.13 E 14.060 5976757,S8 N 2700SS.95 E 14.000 5976768,35 N 270019.61 E 14.000 5976781.20 N 269976.76 E t 4.000 5976781.22. N 269976.73 E 14,01X) 5976787.42 N 269960.58 E 14.000 5976617~7 N 269897.99 E O.000 5976853.70 N 269799.37 E 0.000 5976B74-.00 N 269750.(]0 E 0.000 5976891.56 N 269711,75 E 12,000 5976914;.2! N 289671,99 E 12.0(}Q 5976988.79 N 269554.37 5977014.~9 N 269513.06 All data is ir~ feet u~less otherwise stated. Directions and coordinates are relative te True North. Vert[ca/deplhs are relative to Well Ne~things and Easfings are relative to WelT. The Dogleg Severibj is in Degrees per 100ft. Vertical Sectien is [rom Well and calculated along an Azimuth of 287.500° C-i'me). Based upon Minimum Curvature type ca[curations, at a Measured Depth of 13153.01ft., The Bottom Hole Displacement is 6085.14fL, in the Direction of 351.353° (True)_ Ve~ical S~:tion 1~79.73 ~906.03 1926.75 1992.19 2~73.90 2122.04 2166.73 2165.77 2184.06 22.52.43 235:8.11 2411.41 2453.31 24~8.32 2544.(]8 2633,95 2.681 Con~ rio ent Target: 3-17C/~-31 Targel, Gee~ogic~l Tar§~t: 3-17C/M-,31 TD TAR, Geological Alaska State Plane Zone 3 Endicett SD! I4 June. 1998 - 71:13 - 1 - DriitQuest MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission David John s~/~, DATE' June 4, 1998 Chairman THRU: Blair Wo ndzell.~.3~¢- P. I. Superviso'r~'/t°!'~* FROM' John Spauld~ng,'~, ;L,~. SUBJECT: Petroleum Insp. FILE NO: alhfdfe.doc Confidential: Yes , No X BOPE Test, Doyon 15 BPX / DIU / M-31 PTD 98-0021 Thursday June 4, 1998: I traveled this date to BPX's Duck Island Unit to witness the BOPE test on Doyon rig 15. The AOGCC BOPE test report form is attached for reference. The rig has recently undergone some modifications in order to perform thru tubing rotary drilling. This required a different size BOPE Stack, drilling spools and other assorted equipment. Three failures were observed, 1 valve on the choke manifold, mud gauge on the choke manifold and flanges on the drilling spool. All failures were repaired and testing was completed. Summary: I witnessed the successful BOPE test on Doyon 15. Doyon 15, 6/4/98, test time 6.5 hrs., 3 failures Attachments: alhlfdfe.xis STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Doyon Operator: BPX Well Name: 3-17C/M-3'1 Casing Size: 4 1/2 Set @ Test: Initial Weekly Rig No. 15 PTD # Rep.: Rig Rep.: 14,073 Location: Sec. X Other DATE: 6/4/98 98-0021 Rig Ph.# 659-6510 E. Vaughn J. Willingham 8 T. 11N R. 17E Meridian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location ok Standing Order Posted ok BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Qua Well Sign ok Drl. Rig ok Hazard Sec. ok ' n. Test Press. P/F 300/3,000 P 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P 500/5, 000 P 500/5,000 P MUD SYSTEM' Visual Trip Tank ok Pit Level Indicators ok Flow Indicator ok Meth Gas Detector ok H2S Gas Detector ok FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P CHOKE MANIFOLD: No. Valves 13 No. Flanges Manual Chokes Hydraulic Chokes I Test Pressure P/F 500/5,000 P 36 500/5,000 P 2 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 3,100 I P Pressure After Closure 2,000 I P Alarm 200 psi Attained After Closure minutes 22 sec. ok System Pressure Attained I minutes 27 sec. ok Blind Switch Covers: Master: ok Remote: ok ok Nitgn. Btl's: 4 @ 2600 avg. ok .. Psig. ok .- TEST RESULTS Number of Failures: 3 ,Test Time: ,~6.5 Hours. Number of valves tested 27 Repair or Replacement of Failed Equipment will be made within 0 days. otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. 1. Supervisor at 279-1433 REMARKS: New equipment had just been installed for TTRD. Problems seating the test plug, drilling spool valve leaked, and mud guage on choke manifold ruptured. Minor problems and afl were repaired and tested ok. Distribution: orig-Well File c - Oper./Rig c - Database c- Trip Rpt File c - Inspector F1-021L (Rev. 12/94) STATE WITNESS REQUIRED? YES X' NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Alhlfdfe.xls ,To h n Ft. pc u/ding TONY KNOWLE$, GOVERNOR ~I~A OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 13. 199{l Chip Alvord Engineering Supervisor BP Exploration (Alaska) Inc. POBox 196612 Anchorage, AK 99519-6612 ae~ Duck Island 3-17C/M-31 BP Exploration (Alaska) Inc. Permit No. 98-0021 Sur. Loc. 2755'NSL. 799'WEL, Sec. 8. TI IN. RI7E. UM Btmnhole Loc. 3913'NSL, 2219'WEL, Sec. 5. T1 IN. RITE. UPM Dear Mr. Alvord: Encloscd is the approvcd application for permit to rcdrill thc above rcfcrcnccd well. Thc pcrmit to rcdrill docs not exempt you from obtaining additional permits required bx' law from othcr governmental agcncics, and docs not authorize conducting drilling operations until all other rcquircd pcrmitting dctcrminations arc made. Blowout prcvcntion cquipmcnt (BOPE) must bc tcstcd in accordancc vdth 20 AAC 25 035. Sufficicnt notice (approximately 24 hours) must be givcn to allow a representative of the Commission to witness a tcst of BOPE installcd prior to drilling ncw holc. Noticc max' be given bx' contacting thc Commission pctrolcum ficld inspcctor on thc North Slope pager at 659-3607. David W. J~~ Chairman BY ORDER OF THE COMMISSION dlffEnciosurcs CC: Dcpartmcnt of Fish & Game. Habitat Section v,'/o cncl. Department of Environmental Conscn'ation w/o cncl. STATE OF ALASKA AL~,.~,..:/~, OIL AND GAS CONSERVATION~OOMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepenl [] Service [] Development Gas [] Single Zone I-I Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 56' Endicott Field / Endicott Pool 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047502 ~ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2755' NSL, 799' WEL, SEC. 8, T11 N, R17E, UPM Duck Island At top of productive interval 8. Well Number Number 2S100302630-277 3608' NSL, 1612' WEL, SEC. 5, T11N, R17E, UPM 3-17C/M-31 At total depth 9. Approximate spud date Amount $200,000.00 3913' NSL, 2219' WEL, SEC. 5, T11N, R17E, UPM 02/10/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 312828, 1367'I No Close Approach 2560 13740' MD / 10160' TVD i''6. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} KickOff Depth 11885' MD Maximum HoleAngle 53° Maximum surface 4055 psig, At total depth (TVD) 9590'/4900 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) 3-3/4" 2-7/8" 6.4# L-80 STL 3449' 10291' 7935' 13740' 10160' 75 sx Class 'G' RFFFi 'ED i 9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary J A i;i .5 © 10. o,o Total depth: measured 13183 feet Plugs (measured) ,'-, true vertical 10079 feet Effective depth: measured 13164 feet Junk (measured) Alaska 0il & Gas 00ns. O0rnP,~issi0D true vertical 10073 feet Casing Length Size Cemented M D TVD Structural Conductor 142' 30" Driven 142' 142' Surface 2498' 13-3/8" 4185 c.f. Permafrost 2498' 2496' Intermediate 10520' 9-5/8" 575 c.f. Class 'G' 10520' 8095' Production Liner 2844' 4-1/2" 218 c.f. Class 'G' 10338'-13182' 7976'-10079' Perforation depth: measured 13116'-13136' true vertical 10058'-10064'0RiGINAL 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: Chris West, 564-5089 Prepared By Name/Number: Kathy Campoarnor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipAIvord/~/~ 1~'~ Title Engineering Supervisor Date Commission Use Only Permit Number I AP, Number I AoprovalDato I See cover letter o~.~)-.(~6~. J 50- O ,,~.c/-¢1.! ~/"1' (¢ - O.~ ~//~J~( for other requirements Conditions of Approval: Samples Required []Yes [;~No Mud Log ReqL~ired ! []Yes ,[~No Hydrogen Sulfide Measures [~Yes []No Directional Survey Required []Yes []No Required Working Pressure for BOPE []2M; []3M; [~5M; [] 10M; [] 15M Other: 0riginal Signed 8~ by order of Approved By David W. Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 riplicate IWell Name: 13-17c/M-31 Well Plan Summary IType of Well (Producer or injector)' Well Design (Conventional, slimhole, etc.): IProducer TTRD SIDETRACK FSL FEL SEC TWP RNG Surface Location: 2755 798 8 11N 17E Tie in survey Location: 3273 802 5 11N 17E Target 1 Location: 3608 1612 5 11 N 17E Bottom Hole Location: 3913 2219 5 11 N 17E I AFE Number: 1727026 I I Rig: I DOYON 15 Estimated Start Date: I10/February/98 IOperating days to drill and complete: 12+3 Formation Markers Well Bore: Formation Tops MD TVDSS EMW RESERVOIR PRESSURE KBE -56 Max surface pressure =4055 psi TOP WEST SAK TOP SEABEE/AYLYAK TOP SHALE WALL/TUFFS 11,571 8925 KOP 11,885 MD / 9233TVDSS TOP HRZ 12,216 9500 BASE HRZ 12,574 9755 LCU 12988 9840 KEKIKTUK - Top Flow 2B 12,988 9840 9.83 4900 psi @ 9590 TVDSS Top Flow 2A 13,399 10015 K-35 Target Base2A 13,740 10160 TD 13,740 10,160 ,, Logging Program: Logs: 3.75" Hole Curve and Tangent DPC Open Hole Cased Hole: MWD-GR Slim hole Quad Combo NA Casing/'l'ubin(. Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/I'VD MD/TVD 3.75 2.875" 6.4 L-80 STL 3449 10291/7935 13740/10160 TBG* 4.5" 12.6 L-80 IBM 10286 38 10324/7960 Note: The existing tubing will be left in 31ace and re-used. 3-17c/M-31 Drilling Permit Directional Plan #2 1/28/98 Cementing Program (Inner String job),: Hole Section Liner Size Depth Volume Cement Production 2.875" Liner from Cement from + 75 Sxs Class 'G' 10,291 to 13,740 11,988 to 0.5% CFR 2 with 2.875" x 4.5" 13,740 0.7% Halad 344 liner hanger in 'X' 0.1% HR-5 Nipple 2 pps Super CBL Mud Program: Production Mud Properties: 13.75" hole section: LSND Depth Density Marsh Yield 10 sec LSR YP pH Fluid Flow (PPG) Viscosity Point 10 Min Loss Rate Gel Milling 9.5-10 150-180 50-60 8-16 8.5- <6 600 11-24 9.5 Intermediate 10.0 - 65 - 95 25 - 35 8 - 16 8.5 - < 5 600 10.2 11 - 32 9.5 Reservoir 10.2 - 45 - 65 16 - 24 4 - 10 7 - 11 8.5 - <4 250 10.4 9.5 Hazards/Concerns Pore pressure (_+8.6 - 9.4 ppg EMW) based on offset SIBHP. Lost Circulation due to overbalance in Flow sands. Differential sticking with overbalance situation. Excessive Torque to be combated with lubricant additions after testing. Maintain minimum YP of 25 #/100 sq ft WELLHEAD EQUIPMENT Casing Head: Casing Hanger: Tubinghead: X-mas Tree: McEvoy 13 3/8" X 13 5/8", 5M Flange SSH McEvoy Mandrel Hanger McEvoy 13 5/8",5M X 13 5/8", 5M Cameron 4-1/8",5M DIRECTIONAL STATS FOR 9 5/8" CASING ON 3-17c/M-31 Average Angle: 50 53° 37" @ 9570' 4.38 °/100 @ 4057' 3.41 °/100' @ 4157' 10607 {~Calc. assuming 30% washout) Maximum Angle Maximum Dogleg Top of Cement Drilling Hazards DRILLING CLOSE APPROACH WELL SHUT-INS After the sidetrack of the original 3-17c/M-31 well-bore, there are not any wells which are a close approach. The closet is the original well 3-17b/M-31 which quickly diverges from the sidetrack. This well will meet the deep intersection risk assessment. Close attention to the tolerance lines are necessary to avoid this well. See the TC plot for details. 3-17c/M-31 Drilling Permit Directional Plan ~ 1/28/98 · PORE PRESSURE / LOb~,- CIRCULATION Production Interval (8.5"); The Kekiktuk Sands reservoir pressure may be slightly higher than normal AND VARIES GREATLY, but the Asset estimate of pore pressure of 4800 psi at 9590 TVDss should range from + 7.4 to 9.5 ppg EMW. The formation also has the potential for lost circulation (see Geologic Prognosis for faulting details). Lubricant additions (see above) should be utilized if torque and drag become troublesome, and after extensive testing of mud on location. Flex collars should be utilized in the BHA to minimize potential differential sticking. Liquid casing and OM seal should be on location to help combat severe lost circulation. NOTE: See the Geologic Prognosis for a detailed description of the expected fault locations and sizes. Review the Pad Data Sheet for trouble highlights throughout MPI history. Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Disposal Cuttings Handling: Fluid Handling: CC2A Annular injection is not available at Endicott for this well. Contacts Office Home Pager Drilling Superintendent Dan Stoltz 564-4922 349-6483 Sr Drilling Engineer Steve Shultz 564-5405 373-1657 Operations Drilling Engineer: Chris West 564-5089 345-4699 Production Engineer Mark Sauve 564-5407 279-9049 Reservoir Engineer Kim Coyne 564-5308 349-0226 Geologist: Evvy Goebel 564-5367 276-1045 Geophysicist: Steve Roberts 564-5911 348-0358 Sperry Sun Directional Gordon Hecht 563-3256 Sperry Sun MWD/LWD Jim Galvin 563-3256 349-2746 Baroid Dave Higbie 248-3511 345-0398 275-4570 275-1789 275-7530 275-1337 3-17c/M-31 Drilling Permit Directional Plan #2 1/28/98 Drilling Discussion General The 3-17c/M-31 well on MPI at Endicott will target the Kekiktuk in the 2A in accordance with the 1998 development plan. We will have to abandon the existing perforation in the 3-17b/M- 31 well by pumping cement down coil-tubing, setting a through tubing whipstock and kick off through the 4.5" casing to the new M-31 BHL utilizing the 2.875" liner design. We will not pull the existing production packer or tubing in this well. The 2.875" liner length will be _. 3449 feet, with the top of the liner hanger back into the 4.5" production tubing. The existing 6 valve (ultra)slimhole (4.5" x 1.5" for 9.625" casing) GLM design for the completion on a 4.5" L-80 tubing design with a X/XN nipple profile. Directional Plan: The directional plan for the 3-17c/M-31 well consists of kicking off with a whipstock and conventional BHA's for the Kekiktuk Flow sands. Current plans call for up to 8°/100' doglegs in this section, but this may be adjusted pending results during the drilling process. After sidetracking, drilling the tangent at 64° degrees, and steering directionally back into the Sands with 64° of inclination, the well will be drilled to _+13,740 MD (10,215' TVD). Ensure that any and all tolerance lines are not crossed to avoid policy violations. Please coordinate this through both the Operations Drilling Engineer and the Endicott Drilling Superintendent. There are not any known close approaches which require wells be shut in. Any BHA's indicating less than required BUR should immediately be pulled for a more aggressive assembly. Recommended BHA's All motors should NOT be jetted to account for the proposed flowrate and motor performance. Hole conditions and directional objectives should dictate actual flowrates. As mentioned previously, flex collars should be utilized to minimize potential differential sticking. We will be using bent housing motors with either 7/8 for a roller cone or 5/6 rotor/stator configurations for PDC bits. Sperry proposed BHA's are attached, however the actual BHA with motor design, MWD/LWD tool configuration, MWD battery life, bit hydraulics will be discussed at the daily meeting. ~, ~. ~ ~ Directional Survey Program The survey program for 3-17c/M-31 calls for use of Sperry's SOLAR MWD~_l~l~y~t~i~.~~tss[o~ well. Because of Sperry's standard practice of changing the MWD probes""a~b"r ~v~¥~[@~n, an electronic single shot (ESS) will not be needed, and a gyro is not warranted. Close attention to JORPS is required, with the use of checkshots and survey data validation. Bit Program We will kick off the in the HRZ with a conventional directional BHA and PDC bit, which should make it to the Kekiktuk. After milling the window, a 3.75" tangent section is planned to the Kekiktuk. The penetration rate will vary due to the variable lithology, but these bits have proven durable enough to drill through most of this interval. However, if there is any indication of bit failure such as torque spikes, the bit should be pulled at the descretion of the rigsite team. Recommended Jet Sizes Expected Interval Bit Type Flowrate HSI Casing Section Standard Window Mills 90 - 120 gpm 3.75" Kickoff STAR 09 90 - 120 gpm 3 x 12 2.9 - 4.8 3.75" Tangent PDC Bit 90 - 120 gpm 3 x 15 2.9 - 4.8 3-17c/M-31 Drilling Permit 1/28/98 Directional Plan #2 NOTE: Real time rigsite information such as condition of bits previously pulled, hole conditions, drilling fluids, downhole motor constraints (if any) will be instrumental in actual final bit selection. Mud Program: We will use LSND on this well to both mill the window and drill to TD. There should not be any additions of any lubricants in this well without extensive testing of the actual fluid on location. A new Gel/Biozan polymer will be used for milling the window. Ditch Magnets should be used and WEIGHED to ensure metal cuttings removal. Rheology control can be maintained using Gel and Biozan polymer. At this time raise the LSR YP to the recommended range using Biozan. Biozan sweeps should be pumped to assist in hole cleaning and to prevent the build up of cuttings beds. Mud sweeps are essential for good hole cleaning while drilling. Additions of 3#/BBL each of Baranex and Barotrol should be maintained throughout this well. This treatment should result in an HPHT of <14 which is our target. Maintain the pH in the 9-9.5 range using caustic soda. If torque problems arise, a treatment of 1- 2% Lubetex should be used. If the torque persists, the ERD lubricant mix should be evaluated. The LSND mud will be taken to TD on this well. Maintain the weight at the density required in the intermediate section. The Barotrol and Baranex treatments should be maintained at 3#/bbl untill the ICP. The APl filtrate should be reduced to the 4 cc range with PAC and starch. This will reduce the chances of differential sticking and reduce filtration invasion. Tripping Practices / Stuck Pipe / Hole Cleaning Tripping should be undertaken with caution due to swabbing possibilities with high viscosity fluids in the tight annular clearance. The bottom hole pressure is approximately 4800 psi (7.4 to 9.5 ppg ). It is recommended that mud weights be maintained in the 10.2 to 10.4 ppg range to control the hydrocarbon intervals, maintain shale stability and minimize the possibility of differential sticking. Faulted intervals may require additions of LCM prior to tripping to insure that the hole remains full at all times. Keep the pipe moving and have an ample supply of lost circulation materials on hand. Baroid recommends utilization of Iow viscosity sweeps to assist with hole cleaning and to minimize the formation of cuttings beds on the Iow side of the hole. No potential hazardous levels of H2S are anticipated in the 3-17c/M-31 well. There have been H2S reading on offset SDI wells of over 1000 ppm. Ensure rig gas detectors are calibrated prior to N/D tree and/or circulating to kill the well. 3-17c/M-31 Drilling Permit Directional Plan ~ 1/28/98 Logging Program : ILogs: 3.75" Hole Curve and Tangent DPC logs In open hole Cased Hole: MWD-GR Slim hole QUAD Combo NA Sample catchers and a wellsite Geologist are planned to be used while drilling reservoir. Casing and Cementing This TTRD sidetrack will require a 2.875" 6.4# L-80 liner to be run across the entire interval. This will be hung off in the 4.5" tubing at 10,291 feet. Ensure that prior to running liner that the hole is in good condition and that the mud has been conditioned to run casing. Before POH to run liner spot lubricant across the open hole section. If this is considered essential to getting the pipe to bottom ensure that adequate lubricant testing has been performed prior to doing this. Also, consideration must be given to a hole opener trip prior to running liner if hole conditions suggest that there may be problems running pipe. This liner will use STL connections to allow rotation and reciprocation. Special equipment will be required for this including XO for safety valve and having the liner hanger cut with a STL connection on bottom. The liner should be filled every 5 joints, and circulated prior to going into open hole. Any problem intervals identified while drilling, such as ledges, will require special care while running casing through. The liner will require 1 straight blade centralizers on every other joint to the window. If the liner starts to packoff in the open hole, establish circulation and try to wash through. Do not continue to run casing without circulation. If necessary, we will pull casing and make a wiper trip prior to running the liner. The liner running procedure in the detail section should be reviewed. The cementing program is designed place cement to at least1000 feet above the top of the Kekiktuk formation, or to the liner hanger. The approximate volume will be 68 sacks of Class 'G' with additives as specified in the casing detail section. Cementing operations at Endicott are continue to be critical with the advancement of both the waterflood and gas fronts. Close attention to detail for this part of the well is critical for the economical success of our drilling program. DPC Perforating This sidetrack well will require a DPC perforating across the intervals picked from LWD logs. 3-17c/M-31 Drilling Permit Directional Plan #2 1/28/98 SUMMARY PROCEDURE COMMENTS 1. The 9-5/8" x 4-1/2" production packer is a TIW permanent packer with a tubing seal assembly above. The packer and tubing will not be recovered. 2. The existing perforations will be plugged with cement and or sand. 3. This well will be sidetracked at app. 11,885 feet. PRE-RIG OPERATIONS 1. RU wireline, Pull the WL SSSV. Drift and dummy off gas lift mandrels. 2. RU and run coil tubing across perforations, and establish circulation. 3. Pump 31 sx of class G cement and circulate down the coil tubing. Displace to place cement from 11,800 to 13,047' MD above mechanical bridge plug. Squeeze cement if possible up to 1500 psi. 4. Circulate the 4.5" tubing with 1.5 volumes of sea-water. Check that the well is dead. Freeze protect the top 200' with diesel. Set BPV. 5. Freeze protect the top 200' with diesel. Set BPV. RIG OPERATIONS (SUMMARY) . , . , , . 10. 11. 12. 13. 14. Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. Check that the well is dead. If not circ well w/brine or milling fluid until dead. ND the tree, and NU the BOPE. Test the BOPE and pull BPV. (1/2 day) Pick up 2-7/8" Drillpipe and underreamer BHA, TIH to cleanout cement to 11,900. POOH. Run and set TTRD Whipstock at _+ 11,885' MD. Displace seawater with drilling fluid (1/2 day). Cut TTRD window through 4.5" liner Pick up Sperry directional BHA to turn and build @ 8°/100 feet to 64° at appx 12,362' MD. Drill ahead as specified by the rig supervisor to CP at 13,740. POOH. (12 days) If there are hole problems, run a HO over whole interval and spot lubricant in OH section. POOH. Run a 2.875" solid liner from 10,291 to 13,740 MD with inner string, cement as per plan. (2 days). Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. Make a clean out trip with bit and scraper and displace with KW Brine. Perforate with DPC based on intervals picked from the open hole logs. Pump Corrosion inhibitor. (1/2 day) Set the BPV. ND the BOPE, and NU the tree. Shear the RP valve and freeze protect the well. (1/2 day). 15. Turn the well over to Production. 3-17c/M-31 Drilling Permit Directional Plan #2 1/28/98 I I I I '--' EE: 4-1/16' / 5000 ps~/C~/~aker Actuators ,I Sidetrack 13-3/~. 6,84/ft, L~O CYHE BUTT CSG ( SD! WELL 3-17B/M-31 RT ELEV= 56' MAX. DEV,= 71DEG, [ HAW- XPI PLOT IN MD SS/MD NEXT PAGE MARKER PROJECT "7, I -7 IE~/J',,4--TM, 'J 50029-2194602 · ENDICOTT ,J--_L/U/' , ] ,.~J- 1ST LOG: 06/29/97 r..IE~4 HARKER LOGS - XPT: 0~,-993 O9/.:t9/97 13:58:O4 DI~PTH UNiT - FI~ET COHHENT: NONE /ACTUAL6.''~:~AL-(-'gEt+S('-I'~' I:g HI~ PERF~ ; EWR , ,4D l~'-'.~- ~!~'.: PC'~ :T j2,~ j 4 1/2' L-80 IBM TBG. 12.6 #/FT 9-5/8', 4.5 X 1.5 CAMCO 'TB" 9CR ~--~'AMCO 'TB' 9 CR [6 I 3620' I3504' ......... ......... ....... ......... ::::;:;:: :::::::.. ......... :::::;::: 4-1/2' "X' NIPPLE NOTE: SECTION WINDOW IN 9 5/8 10312' ] 7' ZXP BAKER ' UNER PKR [10338' ] 7'X4,5' XO (3.875' ID) 9 5/8 X 7 'rIw HB-BP-T 4-1/2' 'X' NIPPLE (HES) (3.813' ID) 4-1/2' 'XN' NIPPLE (3.725 ID) -- 4-1/2' WLEG ~1,0324'I ELMD Ref. Log CNL,/GR 7/9/97 12916'-12931' OPEN 13086'-13098' ISO 13116'-13138' ISO TOP o! MBP= 13047.6' md bkb PES 'WR' Rel. Mech. Bridge Plug 'HW' Equalizing Sub Equalize mechanically (1' prong) or hydraulically (4 steel pins x 575 psVpln = 2300 psi) 4,.5 HYRIL 511 CASING 12.6 #/FT (3.958' ID) P~,To p318,~' I' ~'S,OE (~31~o' I----~ I Comments I ENDICOTT WELL: 3-17b/M-31 Inilial Perfs & Completion APl NO: 50-029-21946-0? COMPLETION DIAGRAM ADD-PERFS . ( 09,/19.-'97 ~ 08/11/97 ~37,.'2~.-'97 ......... :;:::;:: :::::::: · ......... ......... ......... ::::::::: :;:::::;: ::::::::: ::::::::: WELL NAME LOG/DATE 3-17B/M-3! CNL 7/9/97 ZONE TOPM.D. BOTM.D. H TOPTVD BOTTVD SPINNER 8/11/97 3A2 12812 12822 10 9896 9899 0.00 3A3 12916 12931 15 9933 9939 0,48 F 1 13086 13098 12 9993 9997 0.52 2B 13116 13186 20 10002 10009 0.00 Last Revised: 09/22/97 7C/M-31 Proposed Completion (TTRD Sidetrack out of 4-1/2" Liner) O . SSS,V. @ 1522' MD,, 2,498' MDIj DATE REVISED BY COMMENTS ENDICO~ 1/26/98 Kimberly Coyne Proposed 3-17C/M-31 Sidetrack WELL: 3-17C/M-31 APl NO 50-029-xxxxx-xx COMPLETION DIAGRAM BP Exploration (Alaska) GAS LIFT MANDRELS (, .5Xl.5 Camc¢ 'TB' 9CF{) N MD(BKB) TVDss 6 3620' 3504' 5 6326' 5253' 4 7936' 6291' 3 90O9' 7009' 2 10031' 7711' 1 10186' 7815' SDI WELL 3-17C I M-31 (Wp2) - SURFACE & DOWNHOLE LOCATIONS 1128198 ITEM NAME COMMENTS ALASKA STATE PLANE ZONE 3 (NAD 27) DECIMAL DEGREES (NAD 27) !S & E SEC LINE OFFSETS SECTION, TOWN., NEAREST SECTION LINE OFFSETS NO. Y X LATITUDE (N°) I LONGITUDE (VV~) FSL FEL RANGE, UMIAT, AK DIST. LINE DIST. LINF 1 SDI 3-17C/M-31 Surface @ SDI Surface Location 5,970,973.83' 270,243.36' 70.322319° , 147.863046° 2755 798 SEC 08 TllN R17E 2524 N 798 E 2 SDI 3-17C/M-31 MD:11885.00 Tie In Point 5,976,769.81' 270,400.34' 70.338159° 147.863213° 3273 802 SEC 05 T11N R17E 2005 N 802 E 3 SDI 3-17C/M-31 MD:12988.60 LCU/TFU 2B - Top of Kekiktuk 5,977,130.00' 269,600.00' 70.339076° 147.869793° 3608 1612 SEC 05 T11N R17E 1670 N 1612 E 4 SDI 3-17C/M-31 MD:13740.27 TD/ 2 7/8" Liner 5,977,452.95' 269,001.41' 70.339907° 147.874728° 3913 2219 SEC 05 T11N R17E 1366 N 2219 ~- Notes: All coordinates shown are North American Datum 1927 (NAD 27). Alaska State Plane Coordinates shown are Zone 3 (Feet). F. Robert Bell & Assoc. Jeff Cotton 564-4969 File Name: DIUBH128.xIs 1/28/98 NW Sec5 T11N R17E Umiat X=265980.55 Y=5978913.24 NW Sec 8 SW Sec8 T11N R17E Umiat X=265688.10 Y=5968357.70 528O 91046'08'' N Sec 5&4 MD 13740:27 TD - 2 7/8" Liner- X=269001.41 Y=5977452.95 MD12988.60 Top Of Kekiktuk X=269600.00 528O 91o46'O7'' .,3,- 17,,/M- 31 3-21 SURFACE LOC. X=270243.36 Y=5970973.83 5280 271046'06'' MDl1885.00 '-Tie In Point X:270400.34 Y:5976769.81 S Sec 8&9 5280 91 °43'42" N Sec 4&3 528O 91 °43'42" N Sec 9&10 o~ 5280 271043'40'' S Sec 9&10 5280 91o41,17,, o~ 528O 91o41'16" 5280 271o41'16'' NE Sec 3 T11N R17E Umiat X=281812.67 Y=5978435.49 SDI Well 3-17/M-31 Wp2 Downhole Location Scale: 1"= 2000' 1/28/98 Jeff Cotton NE Sec 10 SE Sec 10 T11N R17E Umiat X=281520.22 Y=5967880.08 NW Sec 5 T11N R17E Umiat X=265980.55 Y=5978913.24 o~ NW Sec 8 528O 91 °46'08" N Sec 5&4 528O 91 °43'42" MD12988,60 /-Top Of Kekiktuk MD 13740.,,27 /' X=269600.00 TD - 2 7/8 Liner-,~ /Y=5977130.00 X=269001.41 ) ( Y=5977452.95 .~' --. / ._. 22.__20__ __ . -- ! , ~ ~o2 o~ 5280 91o46'07'' MDl1885.00 Tie In Point X=270400.34 Y=5976769.81 N Sec 8&9 5280 91o43'42'' DRILLING SERVICES Shared Services Drilling DrillQuestTM Scale: linch = 300ft -1500 -1200 -900 I I I Eastings -600 -300 I I 6450 -- 6150 - C ~5850 - O Z 5550 - 2 7/8" Liner- 13740.27 MD, 10215.75 TVD 0000.00 SURFACE LOCATION REFERENCE PLOT DATE: 21 - Jan - 1997 Horizontal CoordlnateJ: 5970973.83 N, 270243.38 E RKB Elevation: 41.25 fl Pdg (EST) 14.50ft Well (CBE) 55.75 It RKB-/tMSL Coordinate System: NAD27 Alaska State Pfane~, Z~ne 3, US Foot 3-17C/M-31 Tugel 9895.75 TVD 6133.59 N, 83152 W T;irg¢l N;iIi~: 3-17C/M-31 Checked By; Proposal Target Summary TVl)sx: TVDrkh: Wellhead Offsets:Gloh',d C,m~rdinales: 9:'140.(~1 9895.75 613.1.59 N. 831.52 W 5977130.~) N. 269~(X).6X) E 5250 - I I I -1500 -1200 -900 Scale: linch = 300ft I I -600 -300 Eastings 3OO ' 0 300 Reference is True North 6450 615O 5850 13 O Z 555O 525O 930O 12100.00 96OO 9900 12300.00 II ~ 10200 ,-- .,i- I 2400 I 2700 Scale: linch = 300ft 2500.00 Proposal Data for 3-17C/M-31 Wp 2 Vertical O~gin: Well Horizontal Orig~: Well Measurement Units". fl North Reference: True Ncnlh Dogleg Seveffiy: Degrees per 100fi Vertical S~c6on Azimuth: 294.280' Vertical Secdo~ Description:Well Vertical Section Ofigln: 0.00 N,0.00 E Measuredlncl, Azlm. VerticalNo-things Depth Depth I [8R5.00 23.432 260.635~..88.80 5797.74 N 11915.00 25.537 263.4199316.10 5796.03 N 12362.14 64.804 296.593~629.05 5879.84 N 12988.60 64.804 296393 9895.75 613339 N 13740.27 64.804 296393 10215.75 6438.06 N Easflnge Vertical Dogleg SectionRate 20.73 w 2402.~) 33.04 W 2413.428.000 334.63 W2713.o8lO.Ooo 831.52W 3280.080.1300 1439.72 W 3959.680.000 Pro mity not complete H 00.00 3-17C/M~1 Ta~ 9895.75 TVD 613359 N. 83152 W ............... ~F'J ~ I I 3000 3300 Vertical Section 13700.00 2 7/8" Liner - 13740.27 MD, 10215.75 TVD I I 3600 3900 Section Azimuth: 294.280° (True North) O L'f Sperry-Sun Drilling Services Proposal Report for 3-17C/M-31 - 3-17C/M-31 Wp 2 Shared Services Drilling Endicott Alaska State Plane Zone 3 Endicott SDI Measured Vertical Depth Incl. Azim. Depth Northings Eastings (ft) (ft) (ft) (ft) Vertical Dogleg Section Rate (ft) (°/100ft) 11885.00 23.432 260.635 9288.80 5797.74 N 20.73W 2402.90 11915.00 25.537 263.419 9316.10 5796.03 N 33.04W 2413.42 8.000 12362.14 64.804 296.593 9629.05 5879.84 N 324.63W 2713.68 10.000 12988.60 64.804 296.593 9895.75 6133.59 N 831.52W 3280.08 0.000 13740.27 64.804 296.593 10215.75 6438.06 N 1439.72W 3959.68 0.000 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 294.280° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13740.27ft., The Bottom Hole Displacement is 6597.07ft., in the Direction of 347.395° (True). Formation Tops Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) 12988.60 9895.75 9840.00 13399.67 10070;75 10015,00 Northings Eastings Formation Name (ft) (ft) 6133.59 N 831.52 W LCU/TFU 2B 6300.10 N 1164.13 W TFU2A Casing details From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) <Surface> <Surface> 13740.27 Vertical Depth Casing Detail (ft) 10215.75 2 7/8" Liner Targets associated with this wellpath Target Name 3-17C/M-31 Target Target Entry Coordinates TVD Northings Eastings (ft) (fi) (ft) 9895.75 6133.59 N 831.52W Target Shape Point Target Type Geological 21 January, 1998- 16:17 - 1 - DrillQuest Sperry-Sun Drilling Services Proposal Report for 3-17C/M-31 - 3-17C/M-31 Wp 2 Shared Services Drilling Endicott Measured Depth (ft) Incl. Azim. 11885.00 23.432 11900.00 24.478 11915.00 25.537 12000.00 32.100 12100.00 40.668 12200.00 49.698 12300.00 58.970 12362.14 64.804 12400.00 64.804 12500.00 64.804 12600.00 64.804 12700.00 64.804 12800.00 64.804 12900.00 64.804 12988.60 64.804 260.635 262.083 263.419 274.707 283.457 289.542 294.166 296.593 296.593 296.593 296.593 296.593 296.593 296.593 296.593 296.593 296.593 296.593 296.593 296.593 296.593 296.593 296.593 296.593 296.593 13000.00 64.804 13100.00 64.804 13200.00 64.804 13300.00 64.804 13399.67 64.804 13400.00 64.804 13500.00 64.804 13600.00 64.804 13700.00 64.804 13740.27 64.804 Sub-Sea Depth (ft) 9233.17 9246.76 9260.35 9334.84 9415;33 9485.77 9544.O3 9573.30 9589.42 9631.99 9674.57 9717.14 9759.71 9802.28 9840.00 9844.85 9887.42 9930.00 9972.57 10015.00 10015.14 10057,71 10100.28 10142.86 10160.00 Vertical Depth (ft) 9288.92 9302.51 9316.10 9390.59 9471.08 9541.52 9599.78 9629.05 9645.17 9687.74 9730.32 9772.89 9815.46 9858.03 9895.75 9900.60 9943.17 9985.75 10028.32 10070.75 10070.89 10113.46 10156.03 10198.61 10215.75 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (fi) (fi) (fi) (ft) (°/100fi) (ft) 5798.07 N 20.53W 5976769.81 N 270400.34 E 2402.86 5796.83 N 26.75W 5976768,76 N 270394.09 E 8.000 2408.01 5796.03 N 33.04W 5976768.15 N, 270387.78 E 8.000 2413.42 5795.78 N 73.82W 5976769.15 N 270347.00 E 10.000 2450.50 5805.57 N 132.14W 5976780.72 N 270289.01 E 10.000 2507.68 5825.96 N 199.94W 5976803.18 N 270221.87 E 10.000 2577.86 5856.33 N 275.15W 5976835,84 N 270147.62 E, 10.000 2658,92 5879.84 N 324.63W 5976860,85 N 270098,88 E 10.000 2713.68 5895.17 N 355.27W 5976877.11N 270068.73 E 0.000 2747.91 5935.68 N 436.18W 5976920.08 N 269989.10 E 0.000 2838.33 5976.18 N 517.09W 5976963.04 N 269909.46 E 0.000 2928.74 6016.69 N 598.01W 5977006.01 N 269829.83 E 0.000 3019.15 6057.19 N 678.92W 5977048,97 N 269750.19 E 0.000 3109.56 6097.70 N 759.83W 5977091.93 N 269670.56 E 0.000 3199.97 6133.59 N 831.52W 5977130.00 N 269600.00 E 0.000 3280.08 6138.21N 840.75W 5977134.90 N 269590.92 E 0.000 3290.39 6178.71N 921.66W 5977177.86 N 269511.29 E 0.000 3380.80 6219,22 N 1002.57W 5977220.83 N 269431.65 E 0.000 3471.21 6259.72 N 1083.49W 5977263,79 N 269352.02 E 0.000 3561.62 6300.10 N 1164.13W 5977306.61 N 269272.64 E 0.000 3651.74 6300.23 N 1164.40W 5977306.75 N 269272.38 E 0.000 3652.03 6340.73 N 1245.31W 5977349.72 N 269192.75 E 0,000 3742.45 6381.24 N 1326.22W 5977392.68 N 269113.11E 0.000 3832.86 6421.75 N 1407.14W 5977435.64 N 269033.48 E 0.000 3923.27 6438.06 N 1439.72W 5977452.95 N 269001.41E 0.000 3959.68 Comment LCU/TFU 2B Target: 3-17C/M-31 Target, Geological TFU 2A 2 7/8" Liner Alaska State Plane Zone 3 Endicott SDI Continued... 21 January, 1998 - 16:18 - 1 - DrillQuest Sperry-Sun Drilling Services Proposal Report for 3-17C/M-31 - 3-17C/M-31 Wp 2 Shared Services Drilling Endicott All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 294.280° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13740.27ft., The Bottom Hole Displacement is 6597.07ft., in the Direction of 347.395° (True). Alaska State Plane Zone 3 Endicott SDI 21 January, 1998 - 16:18 - 2 - DrillQuest ,. WELL PERMIT CHECKLIST COMPANY !~ ¢ WELL NAME ~ J L~ '~ -! ~ C,//~v'l-~ { PROGRAM: exp [] dev [] redrll,l~'serv [] wellbore seg LI ann. disposal para req [] FIELD & POOL ~ ~ C...b / O © INIT CLASS ~'~ ~ V / - (~ t L- 6EOL AREA ~' ~ UNIT# l L~ ~( ~- 0 ON/OFF SHORE OAC' ADMINISTRATION 1. Permit fee attached ....................... /'~i 2. Lease number appropriate ................... "' 3. Unique well name and number .................. 4. Well located in a defined pool .................. ~, N 5. Well located proper distance from drilling unit boundary .... ~(~ N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included ............... (~ N 9. Operator only affected party ................... ~__.N 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ ~) N 12. Permit can be issued without administrative approval ...... y~ N 13. Can permit be approved before 15-day wait ........... N REMARKS ENGINEERING APPR ~ 14. Conductor string provided ................... Y N 15. Surface casing protects all known USDWs ........... Y N 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N 17. CMT vol adequate to tie-in long string to surf csg ........ ,,~Y N 18. CMT will cover all known productive horizons .......... Y~N 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. Ifa re-drill, hasa 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. f..~N 'fl 23. If diverter required, does it meet regulations .......... .~N 24. Drilling fluid program schematic & equip list adequate ..... (,~N 25. BOPEs, do they meet regulation ..... ~, .......... (.~Y~N 26. BOPE press rating appropriate; test to ~~ psig. ~::~N 27. Choke manifold complies w/APl RP-53~... Y(Y(Y(Y(~N ~'/.,,,.'"~' 28. Work will occur without operation shutdown ........... (~N 29. Is presence of H2S gas probable ................. Y(,Y(~ N GEOLOGY A~.~ DATE 30. Permit can be issued w/o hydrogen sulfide m~ Y N 31. Data presented on potential overpress~~nes .~- ..... Y N 32. Seismic analysis of shallow gas. z-ones ............. Y N 33. Seabed conditi0~ff.-shore) ............. Y N 34. Contact n_cme/p~one for weekly,progress repo, rts ....... Y N ~ ' [exploratory on~yj GEOL(~Y: RPC ~ ! ENGINEERING: COMMISSION: Comments/Instructions: HOW/Ijt - A:\FORMS\cheklist rev 09/97 H 132G93 o~-;,^, ,,,--~-,--,~- .... '-' VENDOR A A~-;.AST i ~DC DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 010598 CK01059~V i00. OD i00_ O0 HANDLINP= INST' s/h kath9 campom~or x 51aa STATE OF ALASKA ALAS~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging r-]Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2524' SNL, 799' WEL, SEC. 8, T11N, R17E, UPM At top of productive interval 2738' NSL, 1438' WEL, SEC. 5, T11 N, R17E, UPM At effective depth 2711 NSL, 1312' WEL, SEC. 5, T11 N, R17E, UPM At total depth 2677' NSL, 1481' WEL, SEC. 5, T11 N, R17E, UPM 5. Type of well: [~ Development [--I Exploratory [--] Stratigraphic I--I Service 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 13183 feet 10079 feet 13164 feet 10073 feet Length Plugs(measured) Junk(measumd) Size Cemented Structural Conductor 142' 30" Driven Surface 2498' 13-3/8" 4185 c.f. Permafrost Intermediate 10520' 9-5/8" 575 c.f. Class 'G' Production Liner 2844' 4-1/2" 218 c.f. Class 'G' Perforation depth: measured 13116'-13136' true vertical 10058'-10064' Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 to 10324' 6. Datum Elevation (DF or KB) KBE = 56' 7.. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 3-17B/M-31 9. Permit Number 97-108 10. APl Number 50-029-21946-02 il 1. Field and Pool Endicott Field / Endicott Pool MD 142' 2498' 10520' 10338'-13182' TVD 142' 2496' 8095' 7976'-10079' Packers and SSSV (type and measured depth) 4-1/2" SVLN at 1522'; 9-5/8" TIW HBBPT Packer at 10266'; 7" ZXP Baker Liner Packer at 10312' 13. Attachments [~3 Description summary of proposal [--I Detailed operations program I-'-] BOP sketch 14. Estimated date for commencing operation February 10, 1998 16. If proposal was verbally approved Name of approver Contact Engineer Name/Nurnber: Chris West, 564-5089 Date approved I15. Status of well classifications as: [~3 Oil i--]Gas [--1 Suspended Service Prepared By Name/Number: Kathy Campoamor, 564-5122 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /1. steve Shu,tz //~ &(~r,J(4..~,- S-~(~, Title Engineering Supervisor / Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test __ Subsequent form required 10- Approval No. order of the Commission Form 10-403 Rev. 06/15/88 Commissioner Date Submit In Triplicate Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Tue Jul 07 15:02:33 1998 Reel Header Service name ............. LISTPE Date ..................... 98/07/07 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/07/07 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER DUCK ISLAND UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MW-80251 E. CRIBBS E. VAUGHN 3-17CPB1 / M-31 500292194670 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 07-JUL-98 8 liN 17E 2755 799 .00 56.00 15.20 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.375 2498.0 9.625 10266.0 4.500 12181.0 3.750 12870.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH SOLAR GAMMA RAY. 3. MWD RUN 2 CONTAINS NO VALID DATA AND IS NOT PRESENTED. 4. GAPS IN GAMMA RAY DATA (SGRD) DUE TO SMALL COLLAR SIZE AND INABILITY TO STORE VALUES OVER 210 API. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN MARSHALL MUNYAK OF SPERRY-SUN DRILLING SERVICES AND EVY GOEBEL OF BP EXPLORATION (ALASKA), INC ON 07 JULY, 1998. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12870'MD, 9898'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY SOLAR. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 12154.0 12822.0 ROP 12202.5 12870.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH MERGED MAIN PASS. BIT RUN NO MERGE TOP MERGE BASE 1 12202.0 12870.0 $ 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 Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12154 12870.5 12512.2 1434 12154 GR 70.6436 210.084 156.13 939 12154 ROP 2.8749 174.389 23.0122 1337 12202.5 Last Reading 12870.5 12822 12870.5 First Reading For Entire File .......... 12154 Last Reading For Entire File ........... 12870.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/07 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: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12154.0 ROP 12202.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: GM 1.22 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12822.0 12870.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING 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 Il-JUN-98 ISC 5.07 TM3.29/.41 DM3.07/.13 MEMORY 12870.0 12202.0 12870.0 27.6 -79.6 TOOL NUMBER SOLAR GM 82764 3.750 3.8 GEM 10.00 48.0 9.2 3.0 .000 .000 .000 .000 80.0 .3 Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12154 12870.5 12512.~2 1434 12154 GR 70.6436 210.084 156.13 939 12154 ROP 2.8749 174.389 23.0122 1337 12202.5 Last Reading 12870.5 12822 12870.5 First Reading For Entire File .......... 12154 Last Reading For Entire File ........... 12870.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/07/07 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/07/07 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Wed Jul 08 10:23:43 1998 Reel Header Service name ............. LISTPE Date ..................... 98/07/08 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 ..................... 98/07/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER DUCK ISLAND UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NI/MBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 3 AK-MW-80251 E. CRIBBS J. CARLILE 3-17C / M-31 500292194603 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 08-JUL-98 MWD RUN 4 AK-MW- 80251 K. ALLEN J. CARLILE 8 liN 17E 2755 799 .00 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 56.00 15.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 12738.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1,2, AND 5 CONTAIN NO VALID DATA AND ARE NOT PRESENTED. 3. MWD RUNS 3 AND 4 ARE DIRECTIONAL WITH SOLAR GAMMA RAY. 4. REALTIME GAMMA RAY DATA (SGRD) PRESENTED FROM 12342'MD, 9696'TVD TO 12530'MD, 9832'TVD DUE TO INABILITY TO RECORD HIGH GAMMA RAY VALUES. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN MARSHALL MUNYAK OF SPERRY-SUN DRILLING SERVICES AND EVY GOEBEL OF BP EXPLORATION (ALASKA) , INC. ON 07 JULY, 1998. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12738'MD, 9899 ' TV]D. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY FROM SOLAR TOOL. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 12181.0 12698.5 ROP 12213.0 12738 . 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 3 12213.0 12374.0 4 12374.0 12738.0 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 Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12181 12738 12459.5 1115 12181 GR 11.2074 301.818 146.578 1036 12181 ROP 1.2893 167.52 21.3332 1051 12213 Last Reading 12738 12698.5 12738 First Reading For Entire File .......... 12181 Last Reading For Entire File ........... 12738 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12181.0 ROP 12213.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: GM 1.22 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12337.0 12374.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 17-JUN-98 ISC 5.07 TM3.29/.41 DM3.07/.13 MEMORY 12374.0 12213.0 12374.0 29.0 33.2 TOOL NUMBER SOLAR GM 78655 3.750 3.8 GEM 10.20 44.0 9.0 2.3 .000 .000 .000 66.7 MI/D 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 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12181 12374 12277.5 387 12181 GR 106.529 301.818 231.547 313 12181 ROP 1.2893 150.293 19.9229 323 12213 Last Reading 12374 12337 12374 First Reading For Entire File .......... 12181 Last Reading For Entire File ........... 12374 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/08 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 ....... 98/07/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 R3AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12337.5 ROP 12370.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: GM 1.22 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12698.5 12738.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 20-JUlq- 98 ISC 5.07 TM3.29/.41 DM3.07/.13 MEMORY 12738.0 12374.0 12738.0 34.4 78.6 TOOL NUMBER SOLAR GM 74165 3.750 3.8 QUICK DRIL 11.00 50.0 9.3 2.8 .000 .000 .000 69.8 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 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12337.5 12738 12537.8 802 12337.5 GR 11.2074 203.939 109.794 723 12337.5 ROP 4.0644 1902.03 26.3772 737 12370 Last Reading 12738 12698.5 12738 First Reading For Entire File .......... 12337.5 Last Reading For Entire File ........... 12738 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/07/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/07/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Library. Scientific Scientific Physical EOF Physical EOF End Of LIS File