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• S a , r Post Office Box 244027 0 q Anchorage,AK 99524-4027 Hilcorp Alaska,LLC JUL 3 2015 3800 Centerpoint Drive Suite 100 AOGCCAnchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 SCM4t4 5 AUG292u16 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission /� o o7 333 West 7th Avenue, Suite 100 t�/'� / Anchorage, AK 99501 33 A Re: 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 "/" 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 IOrig • New API_WeliNo PermitNumber WellName WellNumber WellNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/J19 1-01 50029226010000 1951500 DUCK IS UNIT MPI 1-03/P16 1-03 50029216050000 1861060 DUCK IS UNIT MPI 1-05/020 1-05 50029217430000 1870810 DUCK IS UNIT MPI 1-09/J18 1-09 50029217430100 1970290 DUCK IS UNIT MPI 1-09A/L21 1-09A 50029221070000 1901570 DUCK IS UNIT MPI 1-11/SN4 1-11 50029223610000 1930560 DUCK IS UNIT MPI 1-15/P25 1-15 50029221000000 1901500 DUCK IS UNIT MPI 1-17/SN2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/I17 1-17A 50029225690000 1950930 DUCK IS UNIT MPI 1-19/118 1-19 50029220050000 1900020 DUCK IS UNIT MPI 1-21/K25 1-21 50029225100000 1941280 DUCK IS UNIT MPI 1-23/015 1-23 50029217220000 1870420 DUCK IS UNIT MPI 1-25/N22 1-25 50029217220100 1970750 DUCK IS UNIT MPI 1-25A/K22 1-25A 50029216930000 1870090 DUCK IS UNIT MPI 1-27/P20 1-27 50029216690000 1861810 DUCK IS UNIT MPI 1-29/M25 1-29 50029225620000 1950720 DUCK IS UNIT MPI 1-31/M21 1-31 50029225770000 1951070 DUCK IS UNIT MPI 1-33/M23 1-33 50029225770100 1980870 DUCK IS UNIT MPI 1-33A/L24 1-33A 50029225770200 1982550 DUCK IS UNIT MPI 1-33B/L24 1-33B 50029225770300 2050040 DUCK IS UNIT MPI 1-33C/M24XX 1-33CXX 50029216720000 1861840 DUCK IS UNIT MPI 1-35/025 1-35 50029217480000 1870900 DUCK IS UNIT MPI 1-37/P24 1-37 50029218270000 1880630 DUCK IS UNIT MPI 1-39/P17 1-39 50029218270100 2061870 DUCK IS UNIT MPI 1-39A/N-16 1-39A 50029217130000 1870320 DUCK IS UNIT MPI 1-41/023 1-41 50029218640000 1881050 DUCK IS UNIT MPI 1-43/P26 1-43 50029219910000 1891240 DUCK IS UNIT MPI 1-45/Q26 1-45 50029216250000 1861310 DUCK IS UNIT MPI 1-47/021 1-47 50029216250100 1972030 DUCK IS UNIT MPI 1-47A/M20 1-47A 50029218410000 1880780 DUCK IS UNIT MPI 1-49/P21 1-49 50029223040000 1921190 DUCK IS UNIT MPI 1-51/V20 1-51 50029225010000 1941120 DUCK IS UNIT MPI 1-53/Q20 1-53 50029217880000 1880210 DUCK IS UNIT MPI 1-55/R25 1-55 50029218730000 1881140 DUCK IS UNIT MPI 1-57/R23 1-57 50029226440000 1960220 DUCK IS UNIT MPI 1-59/024 1-59 50029225200000 1941420 DUCK IS UNIT MPI 1-61/Q20 1-61 50029219050000 1890060 DUCK IS UNIT MPI 1-63/T22 1-63 50029226270000 1951880 DUCK IS UNIT MPI 1-65/N25 1-65 50029226270100 2032120 DUCK IS UNIT MPI 1-65A/N27 1-65A 50029219850000 1891140 DUCK IS UNIT MPI 1-67/T20 1-67 50029220200000 1900290 DUCK IS UNIT MPI 1-69/V19 1-69 50029215680000 1860630 DUCK IS UNIT MPI 2-02/P18 2-02 50029215850000 1860820 DUCK IS UNIT MPI 2-04/M19 2-04 50029216990000 1870180 DUCK IS UNIT MPI 2-06/J22 2-06 50029217710000 1880040 DUCK IS UNIT MPI 2-08/K16 2-08 50029223020000 1921170 DUCK IS UNIT MPI 2-12/016 2-12 50029216390000 1861490 DUCK IS UNIT MPI 2-14/016 2-14 50029218850000 1881340 DUCK IS UNIT MPI 2-16/M16 2-16 50029220320000 1900430 DUCK IS UNIT MPI 2-18/L16 2-18 50029220480000 1900600 DUCK IS UNIT MPI 2-20/L15 2-20 50029219310000 1890340 DUCK IS UNIT MPI 2-22/L14 2-22 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Complete Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: ~,/ z_/~,~,O,_) ~,,~__.. Poor Quality Original'- Pages' D Other- Pages: DIGITAL DATA Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds n Other COMMENTS: Scanned by.Mildred Daretha Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: ~si Well Compliance Report File on Left side of folder 198-087-0 DUCK IS UNIT MPI 1-33A/L2.4--- 50- 029-22577-01 BP EXPLORATION (ALASK A MD 12165 .' TVD 09962" Completion Date:L-~24/98 Completed Status: P&A Current: Microfilm Roll / Roll 2 / Name Interval Sent Received T/C/D 9395 t~- 1 SCHLUM RST CH 12/1/99 12/8/99 9100 5,8 SPERRY GR PB1 OH 3/19/99 3/23/99 9101 20,21 SPERRY GR OH 3/19/99 3/23/99 DGR-MD &--- FINAL 11796-12165 OH 3/23/99 3/23/99 DGR-MD ~ FINAL 11815-12282 PB1 OH 3/23/99 3/23/99 L DGR-TVD ~'"" FINAL 9851-9962 OH 3/23/99 3/23/99 L DGR-TVD FINAL 9867-10002 PBI OH 3/23/99 3/23/99 R SRVY RPTd--"' SPERRY 11700-12165 OH 3/17/99 3/17/99 R SRVY RPT ~.w' Daily Well Ops ~2ffh~ ~' _) ~.~7'~ Was the well cored? yes ~ Comments: SPERRY 11800-12282 PB1 OH 3/17/99 3/17/99 Are Dry Ditch Samples Required? yes ..~-And Receiv~~o-~-~ Analysis Description Recei *vedg--.y4~--.o~ Sample Set # ~- ---~ Tuesday, August 01, 2000 Page 1 of 1 Schlumberger NO. 12986 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print CD 1D-108 I 994~0 .ST .~ ~!%9 ~- 991006 1 (PRINTS SENT PREVIOUSLY) t '" 081999 DATE: Atmka 0il & Gas ~ens. ~x~.'~°"- Please sign and return one copy of this transmittal to $herrie at the above address or fax to (907) 561-8317. Thank you. 12/1/99 0 I::! I I--I--I ~ G S E I:IL~ I I-' E S WELL LOG TRANSMITTAL To: State of Alaska March 23, 1999 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine St. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1-33A/~24 & PB1, AK-MW-80313 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.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 /.. 1-33A / t~g'-24: 2" x 5" MD Gamma Ray Logs: 50-029-22577-01 2" x 5" TVD Gamma Ray Logs: 50-029-22577-01 /- 1-33A/~-24 PB1: 2"x 5"MD Gamma Ray Logs: 50-029-22577-01 2" x 5" TVD Gamma Ray Logs: 50-029-22577-01 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1999 ~as~a O~ & ~ ~s. Commission ?~.~0r~e 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company OF! I I_1--1 ~ G SEI:I~JI r- E S WELL LOG TRANSMITTAL To: State of Alaska March 19, 1998 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Drive. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - 1-33A/,1g-24, AK-MW-80313 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention off Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22577-01 NAR :'~ .3- i999 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company PLUGGING- ,& LOCATION CLEAR~_~CE REPORT State of Alaska .~= 0;= ~ ~ c~sz~A=:0~ cam~ISsza~¢ ~.= .~o. ~~ ao~ 7 .qeview the well file, and-c-~,enu on plugging, well head s uacus, a~d !ace=ich c!eara~ce - uruvide loc. clear, code. Well head ca= o~_~: .~arksr pos= or pla=s: Lots=ion Claara~cs: Code ,? ) '! · o % % -. STATE OF ALASKA ..~ .... ALASKA OIL AND GAS CONSERVATION COMMISSION Plugged Back for Sidetrack WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well E~ Oil [-] Gas [--I Suspended [~ Abandoned i--] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 98-087 398-226 & 316 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22577-01 4. Location of well at surface ~~ 9. Unit or Lease Name 3217' NSL, 2114' WEL, SEC. 36, T12N, R16E, UPM~-t¢~'~. Duck Island Unit/Endicott At top of productive interval ~ ~ 10. Well Number N/A 1-33A/N-24 At total depth i 11. Field and Pool ~ NSL, 3963' EWL, SEC. 31, T12N, R17E, UPM ~~ Endicott Field / Endicott Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE - 56'I ADL 312828 12. Date Spudded 113. Date T.D. Reached I 14. Date Comp., Susp., or Aband.115. Water depth,if offshore 116. No. of Completions 7/31/98I 8/20/98I 8/24/98I 6' - 12' MSLI Zero 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD) 119. Directional Survey ]20. Depth where SSSV set 121. Thickness of Permafrost 12165 9962 FTI 11770 9831 FTI [~Yes [--lNo N/A MD 1650' (Approx.) 22. Type Electric or Other Logs Run MWD, DIP, GR, RES 23. CASING, LINER AND CEMENTING RECORD ~ D I F'_ I I~ ! ^ I CASING SETTING DEPTH HOLEt~.~J SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 30" Struct. Drive 40' 130' Driven 10-3/4" 45.5# L-80 42' 5013' 13-1/2" 795 sx Permafrost 'E', 600 sx Class 'G' 7-5/8" 29.7# USS-95 39' 11780' 9-7/8" 500 sx Class 'G' · -~ ~ ~ ,"~ .-:: ~... 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, 13Cr80 11198' 11110' MD TVD MD TVD 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11511' P&A, 16 Bbls Class 'G' 11740' Set Top of 1 st Whipstock 11714' Set Top of 2nd Whipstock 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Not on ProductionI N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD 1 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. _~4-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 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. S3A1 11748' 9813' K2B 11778' 9837' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the fo, regoing is true and correct to the best of my knowledge s, ed TerrieHubble ~ Title Technical Assistant III Date ~)'~'!7 1-33A/N-24 98-087 398-226 & Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility I End MPI Progress Report Well 1-33A/N-24 Page 1 Rig ~ DO¥Ot'l I~ Date 16 March 99 Date/Time 24 Jul 98 25 Jul 98 26 Jul 98 27 Jul 98 28 Jul 98 29 Jul 98 30 Jul 98 19:00-22:30 22:30-00:00 00:00-02:30 02:30-06:00 06:00-09:30 09:30-03:00 03:00-06:00 06:00-09:30 09:30-03:00 03:00-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-13:00 13:00-14:00 14:00-18:00 18:00-18:30 18:30-20:30 20:30-21:00 21:00-01:00 01:00-03:00 03:00-06:00 06:00-06:30 06:30-08:30 08:30-12:00 12:00-18:00 18:00-18:30 18:30-20:00 20:00-20:30 20:30-22:30 22:30-02:30 02:30-03:30 03:30-04:00 04:00-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-09:00 09:00-12:30 12:30-13:00 13:00-18:00 18:00-18:30 18:30-20:00 20:00-00:00 00:00-00:30 00:30-01:30 01:30-06:00 06:00-06:30 06:30-07:00 07:00-15:30 15:30-18:00 18:00-18:30 18:30-20:00 20:00-21:00 Duration 3-1/2 hr 1-1/2 hr 2-1/2 hr 3-1/2 hr 3-1/2 hr 17-1/2 hr 3hr 3-1/2 hr 17-1/2 hr 1-1/2 hr lhr 1/2 hr 1/2 hr 6-1/2 hr lhr 4hr 1/2 hr 2 hr 1/2 hr 4hr 2hr 3hr 1/2 hr 2hr 3-1/2 hr 6hr 1/2 hr 1-1/2 hr 1/2 hr 2 hr 4hr 1 hr 1/2 hr 2 hr 1/2 hr lhr 1/2 hr 1 hr 3-1/2 hr 1/2 hr 5hr 1/2 hr 1-1/2 hr 4 hr 1/2 hr lhr 4-1/2 hr 1/2 hr 1/2 hr 8-1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr lhr Activity Rig moved 50.00 % Preloaded rig - 20.00 klb Rig moved 100.00 % Skid rig Rigged up Drillfloor / Derrick Held safety meeting Rigged up Drillfloor / Derrick Rigged up Drillfloor / Derrick Held safety meeting Removed Hanger plug Removed Xmas tree Rigged up BOP stack Held safety meeting Rigged up BOP stack Repaired BOP stack Tested BOP stack Held safety meeting Removed Hanger plug Installed Wear bushing Singled in drill pipe to 4000.0 ft Pulled Drillpipe in stands to 0.0 ft Singled in drill pipe to 4000.0 ft Held safety meeting Pulled Drillpipe in stands to 0.0 ft Made up BHA no. 1 R.I.H. to 8000.0 ft Held safety meeting R.I.H. to 11300.0 ft Circulated at 11300.0 ft Circulated at 11300.0 ft Pulled out of hole to 151.0 ft Pulled BHA Made up BHA no. 1 R.I.H. to 7500.0 ft Held safety meeting Serviced Block line Serviced Top drive R.I.H. to 11387.0 ft Logged hole with LWD: DIR/FE from 11387.0 ft to 11558.0 ft R.I.H. to 11760.0 ft Drilled cement to 11805.0 ft Held safety meeting Drilled cement to 11816.0 ft Pulled out of hole to 151.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 11750.0 ft Held safety meeting R.I.H. to 11814.0 ft Drilled to 11821.0 ft Pulled out of hole to 4769.0 ft Held safety meeting Pulled out of hole to 147.0 ft Pulled BHA Progress Report Facility End MPI Well 1-33A/N-24 Rig (null) Page 2 Date 16 March 99 Date/Time 21:00-22:00 22:00-02:30 31 Jul 98 02:30-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-09:00 09:00-10:30 10:30-12:00 12:00-16:30 16:30-17:30 17:30-18:00 18:00-18:30 18:30-06:00 01 Aug 98 06:00-06:30 06:30-18:00 18:00-18:30 18:30-02:00 02 Aug 98 02:00-05:00 05:00-06:00 06:00-06:30 06:30-12:30 12:30-13:30 13:30-15:00 15:00-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-22:30 22:30-23:30 23:30-06:00 03 Aug 98 06:00-06:30 06:30-07:00 07:00-07:30 07:30-08:00 08:00-13:00 13:00-13:30 13:30-16:00 16:00-18:00 18:00-18:30 18:30-23:00 23:00-23:30 23:30-00:30 04 Aug 98 00:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-11:00 11:00-11:30 11:30-12:00 12:00-18:00 18:00-18:30 18:30-06:00 05 Aug 98 06:00-06:30 Duration lhr 4-1/2 hr 1/2 hr 2hr lhr 1/2 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr 4-1/2 hr lhr 1/2 hr 1/2hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 7-1/2 hr 3hr lhr 1/2 hr 6hr lhr 1-1/2 hr 3hr 1/2 hr 1-1/2 hr 1 hr 1-1/2 hr lhr 6-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 5hr 1/2 hr 2-1/2 hr 2hr 1/2 hr 4-1/2 hr 1/2 hr 1 hr 4 hr 1 hr 1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 6 hr 1/2 hr 11-1/2 hr 1/2 hr Activity Made up BHA no. 3 R.I.H. to 11750.0 ft Circulated at 11750.0 ft --Milled Casing at 11814.0 ft Pulled out of hole to 10000.0 ft Held safety meeting Pulled out of hole to 147.0 ft Pulled BHA Made up BHA no. 4 R.I.H. to 11730.0 ft Circulated at 11750.0 ft Drilled to 11833.0 ft Held safety meeting Drilled to 11955.0 ft Held safety meeting Drilled to 12055.0 ft Held safety meeting Drilled to 12132.0 ft Circulated at 12132.0 ft Pumped out of hole to 11750.0 ft Held safety meeting Pulled out of hole to 177.0 ft Pulled BHA Made up BHA no. 5 R.I.H. to 8000.0 ft Held safety meeting R.I.H. to 11760.0 ft Serviced Block line R.I.H. to 11820.0 ft Circulated at 11750.0 ft Pulled out of hole to 1100.0 ft Held safety meeting Pulled out of hole to 177.0 ft Pulled BHA Made up BHA no. 6 R.I.H. to 11750.0 ft Circulated at 11820.0 ft Milled Casing at 11820.0 ft Pulled out of hole to 8000.0 ft Held safety meeting Pulled out of hole to 178.0 ft Pulled BHA Retrieved Wear bushing Tested BOP stack Made up BHA no. 7 R.I.H. to 1500.0 ft Held safety meeting R.I.H. to 11790.0 ft Circulated at 11790.0 ft R.I.H. to 12132.0 ft Drilled to 12195.0 ft Held safety meeting Drilled to 12256.0 ft Held safety meeting Facility Date/Time 06 Aug 98 07 Aug 98 08 Aug 98 09 Aug 98 10 Aug 98 End MPI Progress Report Well 1-33A/N-24 Rig (null) Page Date Duration Activity 06:30-13:00 13:00-13:30 13:30-14:30 14:30~18:00 18:00~18:30 18:30-21:30 21:30-02:30 02:30-06:00 06:00-06:30 06:30-07:30 07:30-10:00 10:00-10:30 10:30-17:00 17:00-18:00 18:00-18:30 18:30-19:00 19:00-22:00 22:00-03:30 03:30-04:00 04:00-06:00 06:00-06:30 06:30-13:30 13:30-18:00 18:00-18:30 18:30-20:30 20:30-21:00 21:00-23:00 23:00-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-09:30 09:30-12:00 12:00-18:00 18:00-18:30 18:30-23:30 23:30-00:30 00:30-06:00 06:00-06:30 06:30-08:00 08:00-09:30 09:30-10:00 10:00-17:00 17:00-18:00 18:00-18:30 18:30-18:45 18:45-22:15 22:15-22:30 22:30-23:30 23:30-00:00 00:00-00:30 00:30-01:00 01:00-06:00 06:00-06:30 6-1/2 hr 1/2 hr lhr 3-1/2 hr 1/2 hr 3 hr 5hr 3-1/2 hr 1/2 hr 1 hr 2-1/2 hr 1/2 hr 6-1/2 hr lhr 1/2 hr 1/2 hr 3hr 5-1/2 hr 1/2 hr 2 hr 1/2 hr 7hr 4-1/2 hr 1/2 hr 2 hr 1/2 hr 2 hr 6hr 1/2 hr 1/2 hr 1/2 hr 3hr 2-1/2 hr 6 hr 1/2 hr 5 hr 1 hr 5-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 7hr 1 hr 1/2 hr 1/4 hr 3-1/2 hr 1/4 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 5 hr 1/2 hr Drilled to 12282.0 ft Investigated pressure change Pumped out of hole to 11750.0 ft Pulled out of hole to 6500.0 ft Held safety meeting Pulled out of hole to 172.0 ft Made up BHA no. 8 R.I.H. to 9650.0 ft Held safety meeting R.I.H. to 11814.0 ft Washed to 11827.0 ft Circulated at 11814.0 ft Pulled out of hole to 0.0 ft Made up BHA no. 9 Held safety meeting Serviced Top drive Made up BHA no. 9 R.I.H. to 11790.0 ft Set tool face Washed to 11827.0 ft Held safety meeting Washed to 11848.0 ft Pulled out of hole to 3446.0 ft Held safety meeting Pulled out of hole to 466.0 ft Pulled BHA Made up BHA no. 10 R.I.H. to 11760.0 ft Set tool face Washed to 11821.0 ft Held safety meeting Washed to 12100.0 ft Reamed to 12041.0 ft Drilled to 12052.0 ft Held safety meeting Drilled to 12068.0 ft Reamed to 11945.0 ft Drilled to 11962.0 ft Held safety meeting Drilled to 11970.0 ft Pumped out of hole to 11814.0 ft Flow check Pulled out of hole to 150.0 ft Pulled BHA Held safety meeting Retrieved Wear bushing Tested All functions Installed Wear bushing Made up BHA no. 11 Tested MWD - Via string Serviced M.W.D. tool Tested M.W.D. tool - Via string R.I.H. to 11800.0 ft Held safety meeting 3 16 March 99 Facility End MP! Progress Report Well 1-33A/N-24 Rig (null) Page Date 4 16 March 99 Date/Time 11 Aug 98 12 Aug 98 06:30-07:00 07:00-09:00 09:00-09:30 09:30-10:00 10:00-10:30 10:30-11:00 11:00-14:30 14:30-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-23:30 23:30-02:00 02:00-02:30 02:30-04:00 04:00-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-06:45 06:45-07:00 07:00-07:15 07:15-07:30 07:30-08:30 08:30-09:00 09:00-10:00 10:00-10:30 10:30-11:00 11:00-14:30 14:30-15:00 15:00-16:00 16:00-16:30 16:30-18:00 18:00-18:30 18:30-20:30 20:30-21:00 21:00-22:00 22:00-23:00 23:00-00:00 00:00-01:00 01:00-06:00 06:00-06:30 06:30-07:30 07:30-10:00 10:00-14:00 14:00-15:00 15:00-15:30 15:30-16:00 16:00-18:00 18:00-18:30 18:30-21:00 21:00-21:30 21:30-22:30 22:30-03:30 Duration 1/2 hr 2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 3-1/2 hr 1/2 hr lhr lhr 3 hr 2-1/2 hr 1/2 hr 1-1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/4 hr 1/4 hr 1 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 1 hr 1/2 hr 1-1/2 hr 1/2 hr 2hr 1/2 hr lhr lhr lhr lhr 5 hr 1/2 hr 1 hr 2-1/2 hr 4 hr 1 hr 1/2 hr 1/2 hr 2 hr 1/2 hr 2-1/2 hr 1/2hr 1 hr 5 hr Activity Set tool face Washed to 11886.0 ft Took MWD survey at 11886.0 ft Worked toolstring at 11846.0 ft Took MWD survey at 11842.0 ft Circulated at 11800.0 ft Laid down 2800.0 ft of 2-3/8in OD drill pipe Pulled out of hole to 2200.0 ft Held safety meeting Pumped out of hole to 150.0 ft Pulled BHA Ran Drillpipe in stands to 8905.0 ft Singled in drill pipe to 10794.0 ft Ran Drillpipe in stands to 11810.0 ft Circulated at 11810.0 ft Circulated at 11810.0 ft Ran Drillpipe to 11886.0 ft (2-3/8in OD) Circulated at 11886.0 ft Held safety meeting Rigged up High pressure lines Tested High pressure lines Mixed and pumped slurry - 13.000 bbl Displaced slurry - 32.000 bbl Pulled out of hole to 11660.0 ft Rigged up High pressure lines Reverse circulated at 11660.0 ft Pulled out of hole to 10700.0 ft Serviced Drillstring handling equipment Pulled out of hole to 0.0 ft Serviced Top drive Made up BHA no. 15 Tested M.W.D. tool - Via string R.I.H. to 3800.0 ft Held safety meeting R.I.H. to 8988.0 ft Singled in drill pipe to 9836.0 ft Serviced Block line R.I.H. to 11660.0 ft Circulated at 11600.0 ft R.I.H. to 11665.0 ft Drilled cement to 11770.0 ft Held safety meeting Drilled cement to 11780.0 ft Circulated at 11660.0 ft Pulled out of hole to 115.0 ft Pulled BHA Made up BHA no. 14 Tested M.W.D. tool - Via string R.I.H. to 5300.0 ft Held safety meeting R.I.H. to 16660.0 ft Circulated at 16660.0 ft R.I.H. to 11165.0 ft Pulled out of hole to 115.0 ft Progress Report Facility End MPI Well 1-33A/N-24 Rig (null) Page 5 Date 16 March 99 Date/Time 13 Aug 98 14 Aug 98 15 Aug 98 16 Aug 98 03:30-04:30 04:30-04:45 04:45-05:00 05:00-06:00 06:00-06:30 06:30-10:00 10:00-10:30 10:30-11:00 11:00-14:00 14:00-14:30 14:30-17:30 17:30-18:00 18:00-18:30 18:30-22:00 22:00-22:30 22:30-23:00 23:00-23:15 23:15-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-08:30 08:30-11:30 11:30-12:00 12:00-13:00 13:00-14:00 14:00-14:30 14:30-15:00 15:00-15:30 15:30-16:00 16:00-18:00 18:00-18:30 18:30-22:00 22:00-22:30 22:30-23:00 23:00-02:30 02:30-03:30 03:30-04:00 04:00-04:30 04:30-05:00 05:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-21:00 21:00-01:00 01:00-01:30 01:30-02:00 02:00-02:15 02:15-05:30 05:30-06:00 06:00-06:30 Duration lhr 1/4 hr 1/4hr lhr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 3hr 1/2 hr 3 hr 1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 1/4 hr 4-1/4 hr 1 hr 1-1/2 hr 1/2 hr 2hr 3hr 1/2 hr lhr lhr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 2hr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr 11-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 4 hr 1/2 hr 1/2 hr 1/4 hr 3-1/4 hr 1/2 hr 1/2 hr Activity Pulled BHA Made up BHA no. 15 Tested M.W.D. tool - Via string R.I.H. to 3888.0 ft Held safety meeting R.I.H. to 11632.0 ft Circulated at 11632.0 ft Set tool face Washed to 11775.0 ft Pumped out of hole to 11600.0 ft Circulated at 11600.0 ft Pulled out of hole to 10213.0 ft Held safety meeting Pulled out of hole to 109.0 ft Pulled BHA Made up BHA no. 16 Tested M.W.D. tool - Via string R.I.H. to 11665.0 ft Washed to 11725.0 ft Circulated at 11660.0 ft Held safety meeting Washed to 11770.0 ft Washed to 11779.0 ft Pumped out of hole to 11660.0 ft Circulated at 11660.0 ft Rest hole at 11660.0 ft R.I.H. to 11759.0 ft Set tool face Washed to 11779.0 ft Worked toolstring at 11779.0 ft Circulated at 11660.0 ft Held safety meeting Pulled out of hole to 113.0 ft Pulled BHA Made up BHA no. 16 R.I.H. to 11220.0 ft Serviced Block line R.I.H. to 11630.0 ft Circulated at 11630.0 ft Set tool face R.I.H. to 11779.0 ft Held safety meeting Milled Casing at 11788.0 ft Held safety meeting Drilled to 11790.0 ft Pumped out of hole to 11650.0 ft Circulated at 11650.0 ft Pulled out of hole to 109.0 ft Pulled BHA Made up BHA no. 17 Tested M.W.D. tool - Via string R.I.H. to 11650.0 ft Circulated at 11650.0 ft Held safety meeting Facility Date/Time 17 Aug 98 18 Aug 98 19 Aug 98 20 Aug 98 End MPI Progress Report Well 1-33A/N-24 Rig (null) Page Date Duration Activity 06:30-07:00 07:00-08:00 08:00-13:00 13:00-14:00 14:00-14:30 14:30-15:00 15:00-18:00 18:00-18:30 18:30-19:00 19:00-19:15 19:15-19:30 19:30-03:00 03:00-03:30 03:30-04:30 04:30-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-11:30 11:30-13:00 13:00-13:30 13:30-17:00 17:00-17:30 17:30-18:00 18:00-18:30 18:30-20:00 20:00-23:30 23:30-00:00 00:00-01:30 01:30-06:00 06:00-06:30 06:30-16:30 16:30-17:00 17:00-18:00 18:00-18:30 18:30-20:30 20:30-21:00 21:00-02:00 02:00-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-09:30 09:30-10:30 10:30-11:30 11:30-13:00 13:00-13:30 13:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-09:30 1/2 hr 1 hr 5 hr lhr 1/2 hr 1/2 hr 3hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 7-1/2 hr 1/2 hr 1 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 4-1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr 4-1/2 hr 1/2 hr 10 hr 1/2 hr 1 hr 1/2 hr 2hr 1/2 hr 5hr 1 hr 1 hr 1 hr 1 hr 1/2 hr 1 hr 2 hr 1 hr lhr 1-1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 3 hr Circulated at 11660.0 ft Set tool face Pulled out of hole to 114.0 ft Pulled BHA Made up BHA no. 18 Tested M.W.D. tool - Via string R.I.H. to 9078.0 ft Held safety meeting R.I.H. to 11660.0 ft Circulated at 11660.0 ft Set tool face Backreamed to 11790.0 ft Drilled to 11795.0 ft Circulated at 11760.0 ft Drilled to 11797.0 ft Circulated at 11700.0 ft Held safety meeting Circulated at 11797.0 ft Pulled out of hole to 109.0 ft Pulled BHA Retrieved Wear bushing Tested BOP stack Installed Wear bushing Serviced Top drive Held safety meeting Made up BHA no. 19 R.I.H. to 11710.0 ft Circulated at 11710.0 ft Washed to 11797.0 ft Drilled to 11815.0 ft Held safety meeting Drilled to 11859.0 ft Pumped out of hole to 11790.0 ft Circulated at 11859.0 ft Held safety meeting Drilled to 11863.0 ft Pulled out of hole to 11710.0 ft Pulled out of hole to 127.0 ft Pulled BHA Made up BHA no. 20 Repaired Draw works R.I.H. to 4000.0 ft Held safety meeting Serviced Top drive R.I.H. to 11450.0 ft Serviced Block line R.I.H. to 11863.0 ft Drilled to 11902.0 ft Installed Flowline Drilled to 11977.0 ft Held safety meeting Drilled to 12130.0 ft Held safety meeting Drilled to 12164.0 ft 6 16 March 99 Facility End MPI Progress Report Well 1-33A/N-24 Rig (null) Page Date 7 16 March 99 Date/Time 21 Aug 98 22 Aug 98 23 Aug 98 24 Aug 98 09:30-12:00 12:00-13:30 13:30-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-23:30 23:30-00:30 00:30-02:00 02:00-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-12:30 12:30-13:30 13:30-15:00 15:00-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-20:30 20:30-00:00 00:00-01:00 01:00-01:30 01:30-04:30 04:30-06:00 06:00-06:30 06:30-11:30 11:30-13:00 13:00-13:30 13:30-18:00 18:00-18:30 18:30-19:00 19:00-21:00 21:00-22:30 22:30-03:30 03:30-04:30 04:30-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-08:30 08:30-14:00 14:00-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-22:00 22:00-03:00 03:00-03:30 03:30-06:00 06:00-06:30 06:30-09:00 09:00-11:00 Duration 2-1/2 hr 1-1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 1/2 hr 4hr lhr 1-1/2 hr 4hr 1/2 hr 1/2 hr 1 hr 4-1/2 hr lhr 1-1/2 hr 3 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 3-1/2 hr 1 hr 1/2 hr 3hr 1-1/2 hr 1/2 hr 5hr 1-1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 2 hr 1-1/2 hr 5hr lhr 1/2 hr lhr 1/2 hr 1/2 hr 1-1/2 hr 5~1/2 hr 4 hr 1/2hr 1 hr 1/2 hr 2 hr 5 hr 1/2 hr 2-1/2 hr 1/2 hr 2-1/2 hr 2 hr Activity Circulated at 12164.0 ft Pumped out of hole to 11730.0 ft Pulled out of hole to 114.0 ft Held safety meeting Pulled BHA Made up BHA no. 21 R.I.H. to 11720.0 ft Circulated at 11720.0 ft Circulated at 11720.0 ft Pulled out of hole to 113.0 ft Held safety meeting Pulled BHA Made up BHA no. 22 R.I.H. to 11750.0 ft Circulated at 11787.0 ft Circulated at 11750.0 ft Pulled out of hole to 3000.0 ft Held safety meeting Pulled out of hole to 114.0 ft Pulled BHA Made up BHA no. 23 R.I.H. to 10200.0 ft Serviced Block line R.I.H. to 11700.0 ft Reamed to 11796.0 ft Circulated at 11750.0 ft Held safety meeting Pulled out of hole to 114.0 ft Pulled BHA Made up BHA no. 24 R.I.H. to 10498.0 ft Held safety meeting R.I.H. to 11720.0 ft Reamed to 11799.0 ft Circulated at 11720.0 ft Pulled out of hole to 114.0 ft Pulled BHA Retrieved Wear bushing Tested BOP stack Held safety meeting Tested BOP stack Made up BHA no. 25 R.I.H. to 11700.0 ft Washed to 12027.0 ft Held safety meeting Took MWD survey at 12027.0 ft Pulled out of hole to 11600.0 ft Circulated at 11600.0 ft Pulled out of hole to 114.0 ft Pulled BHA Ran Drillpipe in stands to 6000.0 ft Held safety meeting Ran Drillpipe in stands to 12026.0 ft Circulated at 12026.0 ft Progress Report Facility End MPI Well 1-33A/N-24 Rig (null) Page 8 Date 16 March 99 Date/Time 25 Aug 98 11:00-12:00 12:00-12:30 12:30-13:00 13:00-15:00 15:00-16:00 16:00-18:00 18:00-18:30 18:30-19:30 19:30-23:30 23:30-00:00 00:00-01:00 O1:00-02:00 02:00-02:30 02:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-09:30 09:30-11:30 11:30-13:00 13:00-16:30 Duration 1 hr 1/2 hr 1/2 hr 2 hr 1 hr 2 hr 1/2 hr lhr 4hr 1/2 hr 1 hr lhr 1/2 hr 2 hr 1 hr 1/2 hr 1/2 hr lhr 2hr 2 hr 1-1/2 hr 3-1/2 hr Activity Mixed and pumped slurry - 16.000 bbl Reverse circulated at 11500.0 ft Pulled out of hole to 11250.0 ft Circulated at 11250.0 ft Ran Drillpipe to 11450.0 ft (2-3/8in OD) Circulated at 11450.0 ft Held safety meeting Circulated at 11450.0 ft Pulled out of hole to 1500.0 ft Tested Tubular strings - Via annulus and string Freeze protect well - 24.000 bbl of Diesel Pulled out of hole to 0.0 ft Installed Hanger plug Rigged down BOP stack Installed Xmas tree Retrieved Hanger plug Held safety meeting Installed Hanger plug Rigged down Fluid system Skid rig Rig moved 10.00 % Rig waited: Other delays BPX Endicott Production Engineering Department OPERATIONS REPORT DATE: 8/26/98 WELL N°: 1-33A/N-24 TYPE OF OPERATION: PULL BPV-TAG CEMENT BP EXPLORATION REP: J. ECKSTEIN SERVICE COMPANY: DSM-HES/TILBURY DATE/TIME OPERATIONS SUMMARY 0900 MIRU.ASSIST DSM IN PULLING BPV. 1130 RIH w/KJ, TEL, 3.625 CENT & SAMPLE BAILER. LOCATE TT @ 11167' WLM, (ELMD=I 1188'). TAG CEMENT @ 11490' WLM, (11511' CORRECTED). POOH. SAMPLE OF CEMENT. 1400 RDMO. SI=0 IA-0 OA=0 SUMMARY: Plugged back with cement following unsuccessful attempts to perform TTRD side-track. AOGCC was contacted before the TD tag. Field inspector Chuck Scheve waived the requirement for witnessing the tag because of scheduling conflict. POST RIG CEMENT BACK. RAN 3.625 CENTRALIZER AND SAMPLE BAILER. LOCATED TUBING TAIL AT 11167' WLM, (ELMD=I 1188'). TAGGED CEMENT AT 11490' WLM, (CORRECTED DEPTH=11511'). OBTAINED SAMPLE OF CEMENT. SSSV: OUT To: From: Operation: Job Id: Anchorage Production Er~gineering Murphy \ Clump 1-33 / M-23 Under-ream Cement with CTU n/a Location: Endicott Cost Code: Detail Code: 727027.2 SDTRK / PREP / CTU Summary 11/28/98 MIRU DS CTU #2. RIH with BHA #1 (Baker Tools String and 6.75" U/R) and dry tag at 11,495' CTMD, correct to 11,511'. PUH and begin underreaming with filtered slick sea water at 11,400'. Ream down to 11,590' and flag pipe using 1064 bbls water and using 40 bbls of 1.5 ppb Biozan for sweeps as required. At surface, U/R arms showed striation wear on the outside with some chipping of Metal Muncher inserts. 11/29/98 RIH with BHA #2 (same tool sting as BHA#1 with redressed U/R arms). RIH and tagged at 11,570' CTMD (~8' from flag) corrected to 11582'. Underreamed to 11,687' corrected depth (located TT with U/R) using 1629 bbls slick filtered seawater and 42 bbls 1.5 ppb Biozan sweeps as required. At surface, U/R arms showed normal wear, but was approximately 0.25" out of gauge. 11/30/98 Cut 42' of pipe. RIH with BHA #3 (same tool string as before with redressed U/R arms). U/R from 11673' CTMD to 11738' corrected CTD. Pump 3 biozan sweeps. At surface, U/R is at most 1/16' out of gauge- not much wear. 12/01-02/98 Rih with BHA #4 w/high hopes of finishing this job. Tough U/R. U/R from 11729 uncorreted CTD to 11747.6'. Best guess from flag difference from yesterday is that btm is now @ 11755'. FP well with diesel as per program. Needs one more underreamin~l pass for upcomincj whipstock set. 11/28/98 Initial Well Status Fwhp lap 0ap GIp FIp (1-35) Fit (1-35) psi psi psi psi psi °F 0 0 0 N/A 275 80 Time Operation 0700 Endicott Safety Meeting 0730 Miru DS #2, 14,500' of 1-3/4" (ctv 32.0 bbls) 0810 Pre-job safety meeting 0825 Rig up hardline 1015 PT Baker tools, leak at circ sub at 2500 psi, rig off to repair 1110 Baker back on location, rigging up tools 1115 Re-PT Baker Tools to 3000 psi - OK 1125 Put on motor and under-reamer 1148 PT backside line to well to 1-35to 500 psi 1152 PT backside line to 2000 psi - OK 1154 PT line from pump to reel to 4000 psi- OK Time Depth Rate Ctp Whp Total Remarks "1ft bpm psi psi bbls 1206 surf 0 0 Open swab and RIH, taking returns to well 1-35 1212 0 270 Pressure stabilize at FLP 1317 7000 970 270 Up weight 11.5k up, 5.5k down 1359 10760 1430 270 Gen set went down, park coil and attempt to restart, restarted - ok 1408 11235 1450 260 Up weight 19.5k Operation: 1-33 / M-23 Under-ream cement with CTU ....... Page: 2 1415 11495 1510 270 Tag bottom, puli up to 11400' CTMD=11416' corrected 1420 11416 1420 270 At 11400' CTMD, correct to 11416', line up to water 1429 11416 0.75 1810 270 0w Begin displacing MeOH from coil 1514 1640 280 32 Begin increasing pump rate 1516 2.3 3360 310 34 Begin U/R down (down weight 11.8k) 1536, 11517 3340 310 82 Down weight (10.4k down) 1538 11519 700 270 Stall #1, PUH (29k up) 1540 11470 2.2 2930 310 Resume U/R 1550 11515 2.4 3160 330 Increase rate 1556 11518 3330 320 120 Motor definitely working 1631 11531 3150 320 203 Up weight 24k, 1639 11485 2630 300 221/0b Swap to Biozan sweep 1641 11497 2.5 2640 310 5/0w Swap to water 1652 11527 3120 310 27 Biozan at drill 1731 11543 0 800 275 125 Stall #2 1732 11504 2.5 2530 320 Resume pumping 1747 11544 2690 120 Take returns to open top 1801 11550 2870 310 199/0b Back to flowline, swap to Biozan pill 1806 11553 3470 310 11/0w Back on water 1818 11557 2900 320 43 Biozan out of nozzle 1829 11600 2870 320 67 Up weight 23k 1833 11525 2600 320 77 Resume U/R down 1909 11570 2.1 2435 310 157 Wt. check 24.5k up, PUH 1912 11550 2000 110 161 Swap returns to tank 1916 11522 1880 30 171 U/R back down 1920 11568 0 560 20 179 Stall #3, Biozan at surface 1927 11567 2.2 1910 25 194 Back on bottom reaming 1932 11568 2.4 2580 310 205 Swap back to flowline 1936 11570 2.4 2600 300 215/0b Swap to Biozan 1941 11572 2.4 3130 300 lO/Ow Swap back to water 1946 11573 0 900 290 21 Stall #4 1948 11560 2.4 2800 300 Back on bottom U/R 1957 11574 0 900 290 Stall #5 1958 11560 2.4 2500 300 52 Backon bottom U/R 2001 11573 1400 260 55 Stall #6 2010 11575 2.4 450 300 78 Stall #7 2019 11576 2600 290 100 Stall #8 2044 11582 2760 300 157 Stall #9 2048 11582 2.4 2590 300 165 Turn returns to the tank 2056 11584 2380 280 183 Biozan at surface 2104 11587 2.3 2440 280 203 Turn returns back to flowline on 1-35 2109 11588 2700 285 214/0b Swap to Biozan 2111 11588 1330 285 2 Stall #10, reduce rate to get remaining Biozan out of truck, PUH 2112 11551 580 285 5/0w Swap to water, out of Biozan, RIH 2131 11590 2750 305 44 Flag pipe, ream up (23k up) 2142 11485 0 370 260 71 Park and drop 5/8' ball to open circ sub 2146 2.0 1700 280 Ball rolling, RIH 2203 11410 3.5 3315 330 106 Ball on seat, increase pump rate 2221 9510 3.2 3250 60 160 Turn returns to tank Operation: 1-33 / M-23 Under-ream cement with CTU Page: 3 2030 7750 3.4 3340 45 192 Biozan to surface 2035. 6800 1.0 3330 290 210 Resume pumping to 1-35 flowline, reduce pump rate 2039 6050 820 280 215/0m Swap to MeOH and keep hole loaded 2310 200 500 280 32 Freeze protect top 200' of well 2315 surf 0 40 40 37 Well freeze protected and bled down, close swab 2318 Rig off Baker under-reamer, motor and circ sub 2330 Under-reamer showed significant striation wear on all arms, some chipping of Metal Muncher inserts, rig back equipment for night 2400 Unit and well secured for night, IA-0, OA-0, FLP-300, FLT-60° 11/29/98 Initial Well Status Slwhp lap 0ap GIp FIp (1-35) Fit (1-35) I psi psi psi psi psi °FI 0 0 0 N/A 275 65 I Time Depth Rate Ctp Whp Total Remarks ft bpm psi psi bbls 0800 On location, rigging up 0835- PT Baker BHA to 3000 psi 0845 Put on motor and under-reamer 0900 PT all surface lines to 4000 psi - OK 0905 surf 0 0 Open swab, RIH with returns lined up to-1-35 1038 8250 580 240 Wt. check 14.5k up, 8k down 1108 11230 860 250 Wt. check 21.5k up, 11.4k down 1117 11570 810 250 Tag at 11570' CTMD (which was -8' from flag at 11590'), PUH 1123 11395 0.7 1270 270 Ow Online with water displacing MeOH from coil 1213 11404 2.4 2050 300 32 Water at motor, begin U/R 1229 11565 2.4 2610 310 71 Motor starting to work, 24k up weight 1241 11568 2.5 2500 300 95 Stall #11 1309 11573 3065 320 162 Water all the way around (9.2k down) 1325 11577 3025 320 198 At flag, correct to 11590' (-13') 1326 11590 3025 310 200 Depth corrected to 11/28 depths 1357 11600 3020 300 276 ~20 feet per hour 1433 11610 2980 320 365 ~17 feet per hour 1452 11615 2905 320 407/0b Swap to Biozan 1455 11616 3390 320 9/0w Swap back to water 1506 11618 3060 320 33 Biozan at mill 1510 11618 2850 330 43 Back ream up to 11560' 1513 11557 2630 330 52 Ream back down 1548 11624 2900 300 134 Stall #12 1556 11623 3050 300 153 Stall #13 1602 11622 2650 290 165 Turn returns to the tank 1617 11626 2800 300 202 Back to flowline 1653 11635 2.4 2780 310 284 Up weight 24.5k, down weight 11.5k 1656 11630 2580 310 291/0b Swap to Biozan 1700 11632 3150 300 10/0w Swap to water 1710 11636 2930 310 33 Biozan atmill 1729 11640 2700 310 77 Down weight 9k Operation: 1-33 / M-23 Under-ream Cement with CTU Page: 4 1805 11645 2730 310 165 Swaptotank 1813 11648 2800 30 183 Stall #14, Biozan at surface ,back ream to 11600' 1817 11600 2260 45 188 Ream backdown "1818 11647 2700 35 194 Stall #15 1821 11646 2320 310 200 Turn returns back to flowline 1851 11653 2750 310 270 Stall#16 1852 11652 2800 310 272 Stall #17 1916 11658 2750 300 326 Stall#18 1923 11651 2500 300 338 Stall #19 1926 11655 2550 300 345 Stall #20 1928 11654 2.4 2500 310 349/0b Swap to Biozan 1931 11655 2900 310 8/0w Swap to water, stall #21 (24k up weight) 1956 11660 2520 300 64 ~12 feet per hour 2039 11667 2575 50 165 Turn returns to tank 2053 11670 2370 310 200 Swap returns back to flowline 2106 11671 2.6 2580 310 233 Up weight 24.1k, back ream to 11650' 2108 11650 2580 315 237 Down weight with free spin 10.4k 2155 11680 2780 320 354/0b Swap to Biozan 2200 11680 3450 320 15/0w Swap to water 2207 11681 3260 320 32 Biozan at bit 2216 11682 2775 310 55 Flag pipe on bottom 2217 2760 310 57 Begin pulling off bottom back reaming (23k up) 2230 11250 1.0 2570 320 90 Reduce rate and locate tubing tail 2233 11183 1400 280 93 Tag tubing tail with U/R arms (actual e-line depth 5' deeper), correct c/o depth to 11,687' 2239 11250 1.8 2230 310 94 Drop 5/8" ball to open circ sub, RIH 2252 11665 3.5 3060 340 125 Circ sub open, POOH (24k up) 2305 10360 3200 290 168 Turn returns to tank 2312 9360 3010 50 190 Biozan at surface 2320 7970 1.0 980 280 216 Turn returns to flowline 2332 5700 920 270 228/0m Swap to methanol 0000 200 1.7 3600 288 32 Freeze protect top 200' of well 0006 surf 0 0 0 37 OOH, close swab, rig off tree, IA-0, OA-0, FLP-300, FLT-45°F 0100 Unit and well secured for night 11/30/98 Initial Well Status Slwhp lap 0ap GIp FIp (1-35) Fit (1-35) psi psi psi psi psi °F 0 0 0 N/A 275 5O 'Time Depth Rate Ctp Whp Total Remarks ft bpm psi psi bbls 0900 On location, rigging up 0930 Clean cement fines out of injector head chains 1000 Cut off 42' of coil, pull test Baker TC to 20k 1025 PT Baker BHA to 3000 psi - OK 1035 Put on motor and under-reamer (new motor with redressed U/R arms) 1055 PT all surface lines to 4000 psi - OK 1105 surf - 40 240 - Open swab, RIH taking returns to 1-35 Operation: 1-33 / M-23 Under-ream Cement with CTU Page: 5 1244 11,300 0.75 989 240 0w Begin displacing MeOH through motor (up weight 21.8k) 1338 11252 2.0 630 250 32 Increase rate to open arms 1344 11244 1.1 1100 250 40 Locate tubing tail 1351 11166 2+ 2090 285 47 No good locate, RIH to ream 1411 11634 2.4 2350 300 94 Flag now at 11634' CTMD 1415 11673 2.3 2430 290 102 Just starting to drill 1418 11673 2.4 2450 290 110 Stall#1 1443 11677 2.5 2900 290 168 Stall#2 1506 11680 2.5 3000 290 224 Stall #3 1512 11680 2.5 3000 290 237 Stall #4 1516 11680 2.5 3000 290 244 Stall #5 1543 11683 2.5 3050 290 311 Stall #6 1639 11693 2.5 2690 300 439/0b Swap to Biozan 1643 11694 3150 310 10/0w Back on seawater 1713 11700 2660 310 83 1725 11701 2500 300 111 Back ream up 1734 11640 2550 300 Ream back down 1740 11701 2710 300 150 Back on bottom reaming 1748 11703 2430 40 165 Turn returns to tank 1801 11706 2460 90+ 198 Turn back to flowline 1829 11710 2700 290 265 Stall #7 (24k up, 11.2k down with free spin) 1903 11714 2572 300 352/ Reset on biozan. 1908 11741 2.4 3087 300 10/ Switch back to water. 1930 11741 2.4 2572 290 75 Pull hole to tag tubing tail. 1943 11175 0.4 778 290 86 Tag tail and correct to 11188'. Rib and up rate. 2012 11728 2.4 2670 311 155 2017 11731 2.4 2680 307 165 Divert to tank. 2024 11733 2.4 2385 27 184 Biozan to surface. -. 2048 11734 2.6 2700 295 239 2100 11735 2.6 2700 306 276 2104 11736 2.5 2684 304 283/0 Switch to Biozan 2108. 11737 2.5 3150 304 10/0 Switch to Water. 2119 11738 2.5 2811 303 41 Flag pipe. Back ream 2129 11614 2.5/0 256 290 60 Dropball. 2144 11734 3.4 3173 335 87 Open circ sub. 2207 10660 3.3 3245 184 165 Take returns to the tank. 2214 10000 3.4 3032 48 191 Biozan to surface. 2240 6300 1.1 900 262 229/0 Switch to Meoh. 2317 200 0 0 0 37 Finish FP. Pooh. 0115 Stood back injector for the night. 12/01/98 Initial Well Status Slwhp lap 0ap GIp FIp (1-35) Fit (1-35) i. psi psi psi psi psi °F 0 0 0 N/A 275 50 Operation: 1-33 / M-23 Under-ream Cement with CTU Page: 6 Time Depth Rate Ctp Whp Total Remarks ft bpm psi psi bbls 0800 On location, rigging up 0930 Baker on location w/new UR blades 0953 surf min 0 0 0 PT backside to 1000 psig & lubricator to 2500 psig. Good. Rih taking returns to 1-35 flowline. 1200 11475 0.75 810 237 0 Start displace methanol out of coil. 1248 11483 2.5 2200 265 0 Start up motor. Rih 4 fpm 1346 11725 2.3 2300 295 163 Start working on fill/cmt. 1403 11730 2,3 2542 275 204 11730.5 see flag. (7.5' from last night) 1413 11733 2.3/0 771 240 222 Stall#1. PU @11729'-25.5k. 1423 11731 2.6 2452 276 240 Back to drilling. 1432 11734 2.6/0 2155 272 273 Stall #2. 1455 11732.8 2.4 2405 272 321 Stall #3. 1506 11733.6 2.4/0 525 241 336 Stall #4. PU= 28k. Get ready for biozan. 1509 11728 2.3 2269 270 350/ On biozan. 1516 11732 2.3 2521 273 5 Stall#5. PU=26k. 1519 11732 2.3 2905 272 10/ Switch back to water. 1530 11732 2.5 3132 273 22 Biozan coming out. 1601 11736 2.5/0 562 225 111.6 Stall #6. PU= 28 k. 1616 11735 2.5 2940 263 145 Hard drilling 11735.7k.. Go to tank @ 165 bbls. 1631 11738 2.5 2568 10 180 Biozan to surface. Drills much better without any back pressure. 1645 11740 2.5 2758 270 214/ Switch to biozan. 1647 11740 2.5 3060 270 5/0 Switch to water. 1707 11742.2 2.5 507 278 49 Stall #7. PU= 27 k. 1713 11740 2/0 545 279 62 Stall #8. Sparks from rig cutting torch- hit the road. Stall 9,10,11. 1737 11738 0.2 2260 300 116 Back to drilling. 1808 11740 2.3 2460 300 165 Go to the tank. 1815 11740 2.4 2240 300 182 Biozan to surface. 1822 11741 2.4 2500 295 195 Back to flowline 1826 11742 2.4/0 677 291 205 Stall #12. 1843 11742 0 650 284 243 Stall #13. 1844 11741 0 2821 285 245 Stall #14,15 1856 11740.4 0 456 284 268 Stall #16 1910 11743 0 615 281 299 Stall #17. Water pump going out on tractor. 1916 11693 2.4 540 282 300/0 Switch to Biozan. Need to get hole clean and start FP. 1919 11700 2.4 3025 282 5/0 Switch to water. Mechanics on the way with new tractor. 2005 11731 2.4 2310 280 121 Leak has slowed down. Go to btm and wait on tractor. 2017 11742 2.3 3809 278 166 Take returns to tank. Stall #18. 2036 11744 2.3 2333 278 186 Biozan at surface. 2042 11745 2.4 2640 278 195 Back to the flowline. 2058 11734 2.4/0 495 280 232 Pump 2 methanol to FP pump. Pooh slowly while connect other tractor. 2118 11414 min 16 280 242 Come on line to PT for new pump. 2128 11414 2.4 2317 280 0 Start motor up again. 2158 11741 0 500 280 45 Stall #19 @ 11745'. 2205 11739 2.4 2174 280 61/ Switch to Biozan. 2208 11741 2.2 2694 280 5/ Back to water. 2230 11745 2.2/0 600 280 51 Stall #20 Operation: 1-33 / M-23 Under-ream Cement with CTU Page: 7 2300 11743 2.2/0 580 280 112 Stall #21 2311 11744.6 2.2/0 753 275 135 Stall #22. PU= 30 k. 2327 11744 2.2 2160 310 170 Switch to the tank. 2335 11744.1 2.4 2127 36 182 Biozan to surface. 2340 11744.4 2.4/0 2137 43 197 Stall #23. 2347 11744.2 2.4/0 700 43 210 Stall #24. Take returns down flowline again. 2356 11744.2 2.4/0 700 275 230 Stall #25. 0019 11744.1 2.5 323 317 264/0 On biozan. 0023 11744.4 2.5 2707 314 7/ Back on water. 0024 11744.5 2.4 2805 322 17 Finally make it past 11744.4'. 0033 11744.8 2.4/0 1300 280 29 Stall #26. 0046 11745 2.4 2411 325 60 0100 11746 2.4 2449 320 95 0114 11747.1 2.4/0 626 276 130 Stall #27. 0125 11747.1 2.4/0 633 282 155 0129 11745 2.4/0 633 276 160 Stall #28 0135 11745.8 2.2/0 432 23 175 0148 11747.4 2.2/0 362 30 204 11743' PU w/correction of 7.5' we have 11750.5'. 0152 11745 2.3/0 434 30 211 Stall #29 0159 11743.5 2.4 2319 327 225/ Switchto Biozan. 0211 11745.0 2.4/0 807 297 10/ Switch to water and Stall #30 takes place. 0219 11743.4 2.5 2390 335 44 0221 11742.7 1.9 1754 314 50/0 Pull up hole to back ream up to 11722'. Swap to biozan final sweep. 0229 11723 1.8 2083 313 7/ Out of biozan, switch to water. 0232 11744.4 2 2300 316 26 0252 11747 2.2 2112 320 47 0317 11747.6 2.2 2100 320 90/ Stall #32. Drop ball and chase w/10 bbls biozan and jet out of hole w/ slick water. Should have btm @ 11747.6+ 7.5:11755' 0430 5500 1.2 300 200/ Switch to 23 bbls diesel for FP. 0515 2000 1.2 300 23/ Switch to meoh to FP coil. Lay in diesel. 0600 surf 31 OOH. U/R is worn. Secure well for night. Fluid Summary 5852 Seawater w/friction reducer. 171 Biozan. 23 Diesel 145 MeOH. 6191 Total Underreamer Bottom Hole Assembly # 1,~, #3,#4 Tool String Descriptions O.D. I.D. Length Comments Baker fishing neck 2.875 1.5 0.96 Baker Check valves 2.875 1.0 1.94 Baker hydraulic disconnect 2.875 0.812 1.90 7/8' Ball Baker circulating sub 2.875 0.562 1.38 5/8' Ball Navi Drill Motor 2.875 11.50 Tandem Operation: 1-33 / M-23 Under-ream Cement with CTU Page: 8 Cross-Over 3.125 1.00 0.80 DB Under-reamer 3.625 3.80 Gauge size: 6.750" Total Length 22.28 BPX Endicott Production Engineering Department WSA- Well Operations Telex To: Endicott Production Engineering Date: From: Bundy Cost Code: Well: 1-33B / L-24 Detail Code: Operation: Pre-Rig / UR Cement December 11-12, 1998 AFE 727022 Summary Objective: Underream cement in 7 5/8' liner to a minimum TD of 11,760' md BKB. 12/11/98 RU DS #6. MU Baker BHA#1 (Underreamer). Tagged TD at 11,746' ctmd. Corrected depth to 11,758' (wlmd corrected to elmd). Underreamed to a depth of 11,770'. Pumped 35 bbl Biozan sweep. Forced to shut down when switching to water due to frozen suction line. Unable to get good circulation off bottom because ball had reached circ-sub prior to getting back on line. Decided to lay remaining Biozan in liner and POH without circulating to surface this trip. Shut down for the evening. 12/12/98 RIH with 3" jet nozzle to TD. Dry tagged approx. 5' high. Pumped 13.5 bbl pill of Biozan and jetted down to original TD. Washed liner and circulated 150% hole volume. POH. Freeze protected tubing to 500' with MeOH. Basedon depths corrected to elmd, the liner is cleaned out to a depth of 11,770' BKB. Time Operation 12/11/98 0700 DS CTU #6 on location. (14,055' of 1.75" ct, coil vol.- 32 bbls). 0730 RU on Well 1-33. 0900 BOP's flanged up. 0930 RU surface lines. 1130 Complete rig up. Inspect all lines and valves. 1230 MU lubricator. Stab on well. Pump MeOH to ensure coil is clear. Coil clear. 1245 PT surface lines, tree flange to 4000 psig - good, backside line to 2000 psig - good. (15 bbls MeOH) 1315 MU up Baker BHA. PT tools to 3000 psig- good. ( 2 bbls MeOH) 1335 MU motor and under-ream assembly. 1400 Stab injector / lubricator and PT lubricator to 4000 psig - good. (3 bbls MeOH) 1415 Bleed down and open swab (19 turns). Bled off WHP. 1420 Safety Meeting Initial Well Status SIWHP lAP OAP FLP FLT I GLP (psig) (psig) (psig) (psig) (deg F)I (psig) Shut In 1350 0 0 - - End 3-09/L.28A Clean Out Page 2 Time Depth Rate CTP WHP Stg Remarks BPM vol. 1430 surf 0 110 0 0 RIH with BHA #1 (underreamer). 1515 5200 0 70 0 0 Weight check- 10 k#. 1614 9550 0 480 0 0 Weight check - 17 k#. 1625 11500 0 680 0 0 Weight check - 20 k#. 1635 11746 0 680 0 0 Tagged down at 11,746'. PU at 11,742' and 20 k# 1640 11758 0 660 0 0 RIH, confirm tag and correct depth to 11,758' 0NLM corrected depth) 1645 11758 0 555 0 0 Trouble flooding filters. Possible ice in tank bottom. 1720 11730 0 500 0 0 Flooded filters. PUH to 11,730'. 1724 11730 1.0 1800 0 0 Start pumping seawater. Reciprocate pipe while pumping coil clear of MeOH. 1750 11650 2.5 2275 0 32 MeOH out. Increase rate. RIH underreaming. Free Spin - 2275 psig. 1802 11751 2.5 4000 0 61 Stall #1 at 11,751'. Shut down. PUH to 11,745'. 1803 11745 2.5 2280 0 63 Start pumping. RIH underreaming. 1807 11751 2.5 2335 0 75 Working on cement @ +/-14 fph. 1916 11770 2.5 2650 0 239 At target depth - 11,770'. Back- ream to 11,740' (4 cycles) 1935 11750 2.5 2420 0 288/0 Switch to Biozan. 1941 11700 2.5 2590 0 12 Shut down. Drop ball. Fix leaking seal. 1950 11700 2.5 3450 0 13 Pumping Biozan. RIH washing liner. 2000 11740 2.4 3400 0 32 Biozan at bit. 2002 11700 0 1145 0 34.5 Switch to seawater. Shut down. Cannot get prime back. Moving pipe. 2010 11620 0.4 2050 0 35 Switch to MeOH. Pump minimum rate. Working on water supply line. RIH to TD. 2020 11770 0.4 2050 0 39 Clear suction line. Switch back to seawater. Ball lands early - open circ sub. Can no longer circulate off bottom. Decide to lay in Biozan on bottom and not circulate on this trip. 2050 ' 11075 0.4 2010 0 67 Biozan out circ- sub. POH. Increase rate to 1 bpm. 2215 3700 1.0 1400 0 154/0 Switch to MeOH 2235 1500 0 30 0 33 Coil is FP. FP surface lines. Shut down. Continue POH leaving CT voidage. 2300 surf 0 0 0 At surface. Close swab (23 tums). Time Operation 2305 Break down Baker tools. 2330 Stand back injector. 2400 Secure well for the evening. 12/12/98 0700 Safety Meeting - Deadhorse 0900 On location 0930 MU BHA #2 (jet swirl nozzle). 0950 Stab lubricator. PT to 4000 psig (4 bbls MeOH). 1000 Safety Meetin~l 1020 Open swab (23 turns). Time Depth Rate CTP WHP Stg Remarks BPM vol. 1025 surf 0 0 0 0 RIH with BHA #2 (jet nozzle). 1130 6600 0 280 0 0 Weight check - 12k#. 1218 11100 2.6 2500 0 0 Start pumping to clear coil of MeOH. 1236 11100 2.1 2280 0 32/0 Coil clear. Switch to Biozan. Start RIH. 1250 11325 2.4 2650 0 13.5 Switch to water. End 3-09/L-28A Clean Out Time Depth Rate CTP WHP Stg Remarks BPM vol. 1300 11720 0 400 0 27.5 Shut down. RIH and dry tag down at 11,758'. PU at 11,750'. 1305 11750 2.5 2760 0 32 Biozan at nozzle. RIH jetting. 1307 11760 2.6 2270 0 40 Tagged down at 11,763' ctmd. PU at 11,760'. 1309 '~ 11740 2.6 2200 0 46 PU to 11,740'. Run back to TD. Tagged hard at 11,763' ctmd. Biozan out nozzle. 1313 11760 2.6 2110 0 53 PUH @ 45 fpm chasing pill up 7 5/8" liner. 1328 11170 2.6 2255 0 92 POH @ 85 fpm chasing pill up 4~" tubing. 1344 9700 2.6 2440 0 140 POH @ 135 fpm chasing pill up 4~' tubing (80%). 1415 5500 2.6 2435 0 220 Sweep out. 1452 1400 1.7 1750 0 308/0 Switch to MeOH. 1505 500 2.2 2600 0 20 Park and continue FP coil 1518 500 0 300 0 33 Shut down. POOH 1525 surf 0 10 0 36 FP surface lines. Fetch more MeOH. 1615 500 0 0 0 36 Run back in hole to 500'. Wait on MeOH. 1635 500 1.6 2915 0 36 Pump MeOH to freeze protect tubing to 500'. 1645 500 0 0 0 46 Shut down. POOH. 1654 surf 0 0 0 46 At surface. Time Operation 1700 RD DS #6. 1930 Secure well. Well is shut in. : (psig) (psig) (psig) (psig) (deg F) (psig) Shut In 0 0 0 - - BHA Summary BHA #1 (Baker-Motor/Mill) Tool String Descriptions O.D. I.D. Length Comments Baker CT Connector 2.875' 1.500" 0.96' Baker Dual Check Valves 2.875" 1.000" 1.94' Baker Hydraulic Disconnect 2.875" 0.812' 1.90' 7/8' ball Baker Circ. Sub 2.875' 0.562" 1.38' 5/8" ball Navi Drill Motor 2.875" -- 11.5' 2 7/8' (Type M1W1) DB Underreamer 3.625" -- 3.80' Open to 6.750" (drift Of 7 5/8") ~ Total Tool String 21.48' Jet Swirl Nozzle Bottom Hole Assembly # 2 Tool String Descriptions O.D. I.D. Length Comments DS ct connector. 2.00" 0.08' Cold Rolled DS dual check valves. 2.00" 1.17' Jet swirl nozzle 3.00" 0.50' 5 down, 4 around swirl. Total Length 1.75' End 3-09/L-28A Clean Out May 10, 1998 Page 4 Fluids Summary Fluids Pumped BBLS. Description 698 SW (slick) 48 Biozan 107 MeOH 853 Total Fluids Pumped BPX Endicott Production Engineering Department DATE: 12/31/98 WELL N°: 1-33b/L-24 BP EXPLORATION REP: SERVICE COMPANY: Whipstock Setting Record COST CODE: 727027.2 DETAIL CODE: Sidetrack/PREP/E LINE D. BARBA SWS (P. AIIdredge) DATE/TIME OPERATIONS SUMMARY 0930 MIRU SWS. 1045 Calibrate Highside Readout with Whipstock Ramp facing up and highside readout reading zero. Highside reading equal -20 degrees (20° L) with whipstock ramp turned twenty degrees counterclockwise looking downhole. 1115 Hold Safety Meeting. Request radio Silience. 1215 Install SSV fusible cap. SIWHP = 200 psig. WriT = na deg F. lAP - 100 psig. CAP = 0 psig. Pressure test lubricator to wellhead pressure. 1220 RIH with "7 5/8" Whipstock. CCL to Top of Ramp 10.8', Top of Ramp to RA 9.3' 1215 MAKE TIE-IN PASS from 10750' to 10650', TIED INTO SBT DATED 23-Sep-95. MAKE-7' CORRECTION. 1410 Make correlation pass from 11690' to 11500'. Make -3.75' correction. Make another pass and add a foot back. 1430 Log up, pass on depth. 1455 Log in to position and park at 11729.2' MD. The whipstock orientation 19° L( or - 19°). 1503 Set Whipstock, top at 11740' and bottom at ,-,11755.5'. Saw good indication. Wait a total of ten minutes and Icg off. 1515 Drop down to tag whipstock, found it at 11739'(note the top of the fishing neck is about one foot higher than the top of the ramp). 1520 POOH. 1645 CCH. Release radio silience. 1745 RDMO. SUMMARY: Set the Whipstock (top of ramp) at 11740' SBT depth, with a Whipstock orientation of 19 degrees Left. To: Endicott Production Engin~'ring Locabon: Endicott 1 - 33b / L - 24 From: Quesenbury Date: Jan. 10,1999 Operation: 1 - 33b / L - 24 Cost Code: 727027.2 Job Id: NA Detail Code: Sidetrack/Prep. / CTU Summary 1/14/98 RU DS #2. RIH with Baker Dimple Mill. Mill on window. Tractor engine blew. POOH while W.O. pump. Pump arrived, FP CT. Gas @ surface. SI WH Pressure increased to 3300 psi. Rig back. RU wireline to pull bottom station to kill well. 1115198 Attempt to kill well, unable to pump in; standby waiting on wireline. 1116198 Standby waiting on wireline Jan. 14, 1999 Initial Well Status Siwhp lap 0ap GIp FIp Fit psi psi psi psi psi °F 400 400 0 N/A N/A N/A Time Operation 0700 MIRU DS CTU #2, 14,350 ft. of 1-3/4" (ctv 32 bbls). 0900 Pre- Job Meeting with all Personnel. 1000 Full BOP Test. Good test. 1120 MU Baker Sidetrack milling tools. Pull test coil connector to 20K. 1200 RU hardline from well 1 -33 to well 1 - 35 for returns. Time Depth Rate Ctp Whp Stage Remarks ft bpm psi psi bbls 1400 0 .50 4000 4000 3meth PTAll. 1505 0 0 0 0 - RIH. 1605 6200 0 580 300 - Wt. Ck. =11,000#. 1645 9600 0 780 285 - Wt. Ck. = 18,000# 1710 11300 0 1800 290 - Start displacing methanol from CT. 1740 11720 1.5 1400 " 35sw 1745 11735.7 2.2 3655 295 46sw Tag. 1746 " " 3761 301 48sw Mill on window. 2010 11737.6 " 3784 302 340sw " " " 2015 11737.6 " 4042 305 350sw Stall #4. Checked friction reducer, definitely not FR we normally use. Add 2 buckets of friction reducer from Endicott Warehouse to vac truck and hook up to pump direct. Start pumping, pressures dropping and able to increase rate. Sent friction reducer back to Dowell in Deadhorse for analysis. 2138 11737.7 2.0 2308 11738.8 2.7 3042 316 761sw Out of SW on vac truck, switch to Upright 2325 " 766sw Tractor engine blew. Shut down.. 2328 " .30 75 254 POOH. Pump methanol @ minimum. DATE: Jan, 15, 1999 0115 467 .20 796 521 35meth Stop. 0125 .... 802 519 35.8 POOH @ 25fpm. Operation: Endicott 1 - 33b / L - 24 ~ Page: 2 0135 300 600 975 38meth Stop. Well flowing on us now. 0136 280 457 1200 " Pull up ASAP into lubricator. 0145 0 0 355 2000 " At Surface. Well coming on big time. Gas Bubble. Close Swab. 0146 0 0 0 0 39meth Bleed down lubricator, set back on deck, Cap BOP'S. 0230 0 0 0 0 0 SDFN. 1000 0 0 0 0 0 On Location, Pre Job Safety Meeting. 1030 0 0 0 0 0 Rig to WH. 1200 0 0 0 0 0 PT new pump & hardline. 1210 0 3.8 2450 70 Begin well kill via 4 -1/2" tubing. 1230 0 1.0 4000 0 50sw Well locked up. 1245 0 .20 3950 0 Switch to methanol to FP wellbore. 1500 0 0 " 0 25meth SD. W.O. wireline to pull bottom GLV @ 10,956 ft. MD. Final Well Status Siwhp lap 0ap GIp FIp Fit psi psi psi psi psi °F 3300 525 0 na na na Fluid Summary 766 Seawater w/friction reducer. 67 Ueoh. 833 Total IBaker Sidetrack Dimple Mill Bottom Hole Assembly # 1 Tool String Descriptions O.D. I.D. Len~lth Comments Baker CT connector 2.875 1.375 0.96 Baker check valves " 1.0 1.94 Baker Hydraulic Disconnect " 0.812 1.90 7/8" ball to disconnect. Baker Circulating Sub " 0.562 1.35 5/8" ball to open. Navi- Drill Motor " N/A 11.48 Baker Flex joint " 1.00 3.94 Baker Dimple Mill 4.530 N/A .72 Total Len~lth 22.29 BPX Endicott Production Engineering Department DATE: 1/24/99 Whipstock Setting Record WELL N°: 1-33b/L-24 BP EXPLORATION REP: D. BARBA SERVICE COMPANY: SWS (P. AIIdredge) DATE/TIME OPERATIONS SUMMARY 0830 SWS arrive 1030 Standby waiting for lubricator 1230 Lubricator arrives. Rig up 1400 Hold Safety Meeting. Request Radio Silience. 1415 Calibrate Highside Readout with Whipstock Ramp facing up and highside readout reading zero. Highside reading equal -10 degrees (10° L) with whipstock ramp turned ten degrees counterclockwise looking downhole. 1630 Waiting on adapter sleeve 1900 Sleeve arrives 1930 Re-calibrate Highside Readout 2200 Hold Safety Meeting 2100 RIH with 7 5/8" Whipstock. CCL to Top of Ramp 14.3' 2315 MAKE TIE-IN PASS from 11500' to 11680', TIED INTO SBT DATED 23-Sep-95. MAKE -9' CORRECTION. 2330 Make correlation pass from 11690' to 11500'. Make -0.5' correction. 2345 Log up, pass on depth. 1/25 0020 Log in to position and park at 11700.2' MD. The whipstock orientation 6° L( or -6°). 0025 Set Whipstock, top at 11714' and bottom at ,-,11730'. Saw good indication. Wait a total of ten minutes and Icg off. 0035 Drop down to tag whipstock, found it at 11703'. 0040 POOH. 0235 CCH. Release radio silience. 0330 RDMO. SUMMARY: Set the Whipstock (top of ramp) at 11714' SBT depth, with a Whipstock orientation of 6 degrees Left. Endicott Alaska State Plane Zone 3 Endicott MPI 1-33A/N-24 SURVEY REPORT 14 September, 1998 Your Ref: API-500292257701 Last Survey Date 20-August-98 Job# AKMWS0313 KBE- 56.00' DRILLING C;ERVIrE5 ORIGINAL BPXA PDC Survey Ref: svy501 Sperry-Sun Drilling Services Survey Report for 1-33A/N-24 Your Ref: API.500292257701 Endicott Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (ft) (°/100ft) 11700.00 36.200 110.490 9718.32 9774.32 1373.77 S 5800.79 E 5980791.73 N 264842.60 E 11781.00 36.770 111.020 9783.44 9839.44 1390.84S 5845.83 E 5980773.22 N 264887.07 E 0.804 11791.26 43.460 112.860 9791.28 9847.28 1393.32 S 5851.95 E 5980770.55 N 264893.11 E 66.215 11824.83 49.980 117.880 9814.29 9870.29 1403.83 S 5873.99 E 5980759.34 N 264914.79 E 22.254 11842.24 53.950 120.010 9825.02 9881.02 1410.47 S 5885.98 E 5980752.32 N 264926.56 E 24.753 11873.07 57.460 123.270 9842.39 9898.39 1423.84 S 5907.65 E 5980738.26 N 264947.79 E 14.348 11906.03 64.070 126.240 9858.48 9914.48 1440.24 S 5931.25 E 5980721.10 N 264970.85 E 21.538 11937.45 69.180 128.340 9870.94 9926.94 1457.72 S 5954.18 E 5980702.90 N 264993.21 E 17.381 11968.50 76.600 130.390 9880.07 9936.07 1476.53 S 5977.10 E 5980683.36 N 265015.51 E 24.715 12001.41 81.850 136.870 9886.23 9942.23 1498.83 S 6000.46 E 5980660.32 N 265038.15 E 25.066 12032.41 84.430 143.990 9889.94 9945.94 1522.54 S 6020.05 E 5980635.99 N 265056.96 E 24.273 12061.05 85.370 149.990 9892.49 9948.49 1546.45 S 6035.58 E 5980611.59 N 265071.72 E 21.123 12092.23 82.260 157.480 9895.85 9951.85 1574.23 S 6049.29 E 5980583.39 N 265084.53 E 25.878 12165.00 82.260 157.480 9905.65 9961.65 1640.83 S 6076.91E 5980515.93 N 265109.99 E 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 157.560° (True). Based upon Minimum CurvatuC-e-type calculations, at a Measured Depth of 12165.00ft., The Bottom Hole Displacement is 6294.54ft., in the Direction of 105.110° (True). Vertical Section (fi) 3484.00 3516.97 3521.60 3539.72 3550.44 3571.07 3595.24 3620.14 3646.28 3675.81 3705.20 3733.23 3764.14 3836.24 Comment Tie-on Survey Window Point Projected Survey Alaska State Plane Zone 3 Endicott MPI Continued... 14 September, 1998 - 14:29 - 2 - DrillQuest Endicott Sperry-Sun Drilling Services Survey Report for 1-33A/N-24 Your Ref: API-500292257701 Alaska State Plane Zone 3 Endicott MPI Comments Measured Depth (ft) 11700.00 11781.00 12165.00 Station Coordinates TVD Nothings Eastings (fi) (fi) (fi) 9774.32 1373.77 S 5800.79 E 9839.44 1390.84 S 5845.83 E 9961.65 1640.83 S 6076.91E Comment Tie-on Survey Window Point Projected Survey 14 September, 1998 - 14:29 - 3 - DrillQuest Endicott Alaska State Plane Zone 3 Endicott MPI 1-33A/N-24- 1-33A/PB1 RECEIVED SEP 1 7 L,8 BPXA PDC SURVEY REPORT '14 September, 1998 ORIGINAL Your Ref: API-500292257770 Last Survey Date 05-August-98 Job# AKMWS0313 KBE - 56.00' r1RILLIN[~ SERVICES Survey Ref: svy499 Sperry-Sun Drilling Services Survey Report for 1-33A/N-24 - 1.33A/PB1 Your Ref: A PI-500292257770 Endicott Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 11800.00 36.900 111.140 9798.65 9854.65 1394.94 S 5856.45 E 11815.00 37.080 111.090 9810.63 9866,63 1398.19 S 5864.87 E 11837.47 46.040 116.170 9827.43 9883.43 1404.21 S 5878.48 E 11868.89 49.870 122,020 9848.48 9904.48 1415.57 S 5898.83 E 11899.50 53.200 126.700 9867.53 9923.53 1429.11 S 5918.59 E 11931.83 58,200 124.050 9885.74 9941.74 1444.55 S 5940.37 E 11964.79 64,910 129.510 9901.44 9957.44 1461.92 S 5963.53 E 11996,39 74.080 131.280 9912.50 9968,50 1481.09 S 5986.04 E 12025,16 79,970 135.860 9918.96 9974.96 1500.41 S 6006.33 E 12059,75 81.000 145.950 9924.69 9980.69 1526.85 S 6027,81 E 12090.51 80.950 156.590 9929.53 9985.53 1553.45 S 6042.39 E 12125.53 85.290 165.690 9933.73 9989.73 1586.31 S 6053.60 E 12158.34 91,910 167,240 9934.53 9990.53 1618.18 S 6061.27 E 12187.96 89,380 167.300 9934.20 9990.20 1647.07 S 6067.80 E 12218.84 81.810 165.700 9936.57 9992.57 1676.98 S 6074.98 E 12282.00 81.810 165.700 9945.57 10001.57 1737.56 S 6090.42 E 5980768.79 N 264897.55 E 5980765.27 N 264905.87 E 5980758.82 N 264919.27 E 5980746.80 N 264939.25 E 5980732.64 N 264958.56 E 5980716,50 N 264979.83 E 5980698.40 N 265002,42 E 5980678.52 N 265024,30 E 5980658.56 N 265043,96 E 5980631.44 N 265064,58 E 5980604.38 N 265078,30 E 5980571.18 N 265088.45 E 5980539.08 N 265095.09 E 5980509.99 N 265100.68 E 5980479.86 N 265106.90 E 5980418.82 N 265120.38 E All data is in feet unless othe~vise 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 157.560° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12282.00ft., The Bottom Hole Displacement is 6333.43ft., in the Direction of 105.923° (True). Dogleg Vertical Rate Section (°/100fi) (fi) 3524.81 1.217 3531.03 42.576 3541,79 18,424 3560.06 16,171 3580.12 16.881 3602.70 25.022 3627.59 29.488 3653.90 25.681 3679.51 28.921 3712.14 34,161 3742.30 28.614 3776.95 20,722 3809.33 8.544 3838.53 25,052 3868,92 0.000 3930.80 Comment Tie-on Survey Window Point Projected Survey Alaska State Plane Zone 3 Endicott MPI Continued... 14 September, 1998 - 14:18 - 2 ~ DrillQuest Endicott Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 11800.00 9854.65 1394.94 S 5856.45 E 11815.00 9866.63 1398.19 S 5864.87 E 12282.00 10001.57 1737.56 S 6090.42 E Sperry-Sun Drilling Services Survey Report for 1-33A/N-24 - 1-33A/PB1 Your Ref: API-500292257770 Comment Tie-on Survey Window Point Projected Survey Alaska State Plane Zone 3 Endicott MPI 14 September, 1998 - 14:18 - 3 - DrillQuest STATE OF ALASKA ALASKA--~,~IL AND GAS CONSERVATION CO~MISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3217' NSL, 2114' WEL, SEC. 36, T12N, R16E, UPM At top of productive interval 1850' NSU 1610' WEL, SEC. 36, T12N, R16E, UPM At effective depth 1885' NSL, 3576' EWL, SEC. 31, T12N, R17E, UPM At total depth 1584' NSL, 3978' EWL, SEC. 31, T12N, R17E, UPM 5. Type of well: [~ Development [] Exploratory I--] Stratigraphic [--~Service 6. Datum Elevation (DF or KB) KBE = 56' 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 1-33A/N-24 9. Permit Number 98-087 10. APl Number 50-029-22577-01 1. Field and Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 12165 feet 9962' feet 11500 feet 9611' feet Length Size 91' 30" 4974' 10-3/4" 12365' 7-5/8" Plugs (measured) Junk (measured) Cemented Driven 1725 c.f. Permafrost, 690 c.f. Class 'G' 559 c.f. Class 'G' MD TVD BKB BKB 130' 130' 5013' 4390' 124O4' 1O329' Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A 13. Attachments [~ Description summary of proposal [] Detailed operations program I~ BOP sketch 4. Estimated date for commencing operation December 3, 1998 16. If proposal was verbally approved Date approved Contact Engineer Name/Number: Jeff Hupp, 564-5606 15. Status of well classifications as: [] Oil [] Gas I--I Suspended Service Prepared By Name/Number: Carol Withey, 564-4114 17. I hereby certify~hat t~he~foregoing is true and correct to the best of my knowledge Signed ~c~Y~ -~ Dav Y Title Drilling Superintendent Commission Use Only Date I Approval No.~,¢~~.~ Conditions of Approval: Notify Commission so representative may witness Plug integrity ,,,/' BOP Test ,-'/ Location clearance__ Mechanical Integrity Test__ Subsequent form r¢~:l~ 10- ~© 7 "'"" '5'~ ~y Commissioner Approved by order of the Commission Dc~L.,u W. Johnston ,' Form 10-403 Rev. 06/15/88 Submit In Triplicate _ hare. d r.v!ces Alask; r il ng To: Blair Wondzell- AOGCC From: Jeff Hupp Subject: Endicott MPI 1-33A/N-24 Abandonment Date: November 23, 1998 The MPI 133A/N-24 well was suspended awaiting future sidetrack options. The 1-33A well has been plugged with cement as required for abandonment. The well is planned to be sidetracked to a different BHL at which time a permit will be submitted. Prior to moving the rig on the well to drill MPI 133B/L-24, the cement will undereamed down to 11750' and a through tubing 7-5/8" whipstock will be set. The well will be side-tracked by milling a 3.80" window in the 7-5/8" casing. Senior Drilling Engineer TREE: '/2" ,CAMERON W 5000 psi I~T. ELEV -- 56.0' WELLHt ~: 13 5/8" 5000 psi FMC BF. ELEV : 18.7' MAX DEV = 40° AT 3742' 4-1/2", 12.6#/ft, L-80tbg . m i~,~ -- (3 8,1,3" MIN ID) I ,,u~ , [ ~:~ ~7~ ~.. 7-5~;8 PACI~'ER I 11110' g. = ~ (TIW HB-BP-T) I ~ ~ ~.. ~ 4-1/2" 'X' NIPPLE , ~ I <~ 4-1/2" 'XN' NIPPLE , ~ ~ -.... r --"' 4-1/2" WLE G , ~,~ew Style I ELMD I 11188' 17.0 ppg Cmt top @ 11660. ~ ~~ ~_~i ~ Top of P&A cmt plug @ 11511' ~~~/ ~ Tagged w/Slickline ...~-,.=!-,--.-,.-~ ~ ~.,.~.~ ~ · , Original Fiber TOC @ 11752' ~ ~~ New P~lot Hole f/11660-11770 / New Ramp f/11770-780 ~~ Window f/11780-11786' / Original Pilot Hole f/11752-805' Original Ramp 11805-816' , RI G I N A b W l N D OW M I L L E D @ 11816-20 1 2 1 1 2 ~~ -- b- .... a ': '. i iiii 1:i i .':~':ii'-ii"i'i':iiiii:'i~:~,~ .................. 17.0 ppg fiber cmt f/12276' (PB __ --\ tag) to 11780' md (22 bbls cmt) ~.::,::, :: - Original Hole @ 12282' ~ .... TI~I~=D ALONG CSG TO 11886' I 12 14' I 7-5/8", ] 12404' 29.7#/ft, _L-80 NSCC DATE REV. BY (;OMMENTS ENDICOTT WELL 1-33A/N-24 11/20/98 JLH Actual P&A APl NO' 50-029-22577-01 8/18/98 JLH Cmt Window Schematic Wi nowDiagram BP EXPLORATION, INC. STATE OF ALASKA ALASK/~rOIL AND GAS CONSERVATION CO~rMISSION 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 3217' NSL, 2114' WEL, SEC. 36, T12N, R16E, UPM At top of productive interval 1850' NSL, 1610' WEL, SEC. 36, T12N, R16E, UPM At effective depth 1885' NSL, 3576' EWL, SEC. 31, T12N, R17E, UPM At total depth 1584' NSL, 3978' EWL, SEC. 31, T12N, R17E, UPM J5. Type of well: [~ Development I~ Exploratory [] Stratigraphic [--I Service 6. Datum Elevation (DF or KB) KBE - 56' 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 1-33A/N-24 9. Permit Number 98-087 10, APl Number 50-029-22577-01 11. Field and Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 12165 feet 9962' feet 11500 feet 9611' feet Length Size 91' 30" 4974' 10-3/4" 12365' 7-5/8" Plugs (measured) Junk (measured) Cemented MD TVD BKB BKB Driven 130' 130' 1725 c.f. Permafrost, 690 c.f. Class 'G' 5013' 4390' 559 c.f. Class 'G' 12404' 10329' Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A 13. Attachments [~ Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation 15. Status of well classifications as: August 24, 1998 16. If proposal was verbally approved I-q Oil [] Gas [~ Suspended Blair Wondzell Service Name of approver ..... D~ate approved Contact Engineer Name/Number: Chris-~l/os/ 564-5089 /~ Preparod ay Namo/Numbor: 17' I ~e~:bdY certifY that ~,b' f°rCng is true/~,Pd c°rre%/~he best °f mY kn°wledge Sg ¢, /~-¢/~''' Dan Stoltz / ¢~/J//',,~.'~.'~~'~-Title"-D dtting S~perinten dent Terrie Hubble, 564-4628 Date I^ .rova Commission Use Only Conditions of Approval: Notify Commission so representative ma.a..y witness Plug integrity c,,,-" BOP Test ¢ Location clearance Mechanical Integrity Test__ Subsequent form required 10- Approved by order of the Commi~--~i~r~°veal Copy Form 10-403 Rev. 06/15/88 Retu ~ i-~ed David W, Johnston Commissioner d rvlces rilling To: Eddie Vaughn From: Chris West MB8-1 Subject: Endicott MPI 1-33/M-23 Cement Plug This procedure is to set a cement suspension / abandonment plug Date: August 23, 1998 COMMENTS 1. The 7-5/8" x 4-1/2" production packer is a TIW permanent packer with a latched tubing seal assembly. The packer and 4-1/2" tubing will be left in place. 2. The existing perforations have already been plugged with cement. RIG OPERATIONS 1. RIH with cement stinger and' mule shoe on OEDP to as deep as possible. 2. MIRU Halliburton Cementers. 3. After a minimum of 1-1/2 wellbore volumes are pumped, reduce rate to minimize fluid volume, but it must be sufficient to prevent gas from migrating back into the wellbore; usually 1/2 BPM. Maintain enough rate to achieve positive well head pressure. Tag bottom with mule shoe and correct as needed. If depth correction is questionable, plan to err to the high side with the cement top. Batch mix 16.0 bbls of cement. Typical Halliburton kick-off cement is 17 ppg class "G" Cement. Cement volume are calculated as follows 241 feet of 3.75" hole to window 11,786 to 12,027 = 3.3 bbl 286 feet inside 7-5/8" casing above old cement plug to 11,500 = 13.1 bbl Total pumped = 16.4 bbls Connect cementer pump to drillpipe.. Pump a 5 bbls fresh water spacer ahead of cement to verify tank straps with micro motion meter. Send cement sample to lab for UCA test. Pump 16 bbls cement. Follow the cement w/5 bbls fresh water. Displace with Brine. . . . . MPI 1-33a/N-24 Abandonment Plug . . 10. 11. 12. 13. 14. Zero totalizer when cement (density increase) reaches micro motion meter. Continue to Use cementer tank straps throughout job. When cement plug is balanced, gradually pull stinger from the plug Spot the cement to 11,500' MD. PU to safety and attempt to squeeze cement with 1000 psi to reduce the amount of cement to clean out. Position mule shoe - stinger at cement top and reverse out any cement down to 11,500 feet MD. Make up/down/up washing passes through all jewelry and GLM's on the way out of the hole. After allowing cement to set up for 12 hours, pressure test cement with 2500 psi for 30 minutes. NOTE: Call the AOGCC to witness the tag. The plug will be tagged with slickline after the rig is released. Chris West Senior Drilling Engineer CC: Dan Stoltz Susan Brown Brent Voorhees DS CT supervisor (Deadhorse) SDI-133/M-23 well file SDI 1-33A/N-24 Well File Doyon 15 Rig Supervisor Attachments Proposed Schematic Lowell Crane SSD Engineering Supervisor MPI 1-33aJN-24 Abandonment Plug RT. ELEV = 56.0' BF. ELEV = 18.7' MAX DEV = 40° AT 3742' 4-1/2", 12.6#/ft, L-80tbg 17.0 ppg Cmt top @ 11500'. ~ TREE 1/2" ,CAMERON W 5000 psi WELLr .... ,D: 13 5/8" 5000 psi FMC (3.813" MIN. fD) 7-5/8" PACKER ( TIW HB-BP-T ) 4-1/2" 'X' NIPPLE (HES) (3.813" ID) 4-1/2" 'XN' NIPPLE (HES) Milled to 3.80" ID) 4-1/2" WLE G New Style 11099' 11110' 11175' 11186' 11198' 11188' 17.0 ppg Cmt top @ 11600'. Original Fiber TOC @ 11752' ~ Original Pilot Hole f/11752-805' Original Ramp 11805-816' RIGINAL WINDOW MILLED @ 11816-20' 17.0 ppg fiber cmt f/12276' (PB tag) to 11780' md (22 bbls cmt) Second Pilot Hole f/11660-11770' Second Ramp f/11770-11,780' Second Window f/11780-11786' 3.75" hole to 12,165' ....... . .................. . ..TOF @ 12t12' Original Hole @ 12282' TRACKED ALONG CSG TO 11886' PBTD 7-5/8", 112314' 29.7#/ft, L-80 NSCC I 12404' DATE [REV. BY 4/14/98 I JLH 8/18/98 I JLH 8~24~98 I CRW IOMMENTS Proposed P&A Cmt Window Schematic Abondonment Plug Schematic ENDICO'R' WELL 1-3RAIN-24 APl NE): 50-02§-22577 Winow Diaerem BP EXPLORATION, INC. MEMORANDUM State of Alaska TO: THRU: David John,~ Chairman Blair Wondzell, _dg~ P. I. Supervisor -r/',~ ,~ i~e Alaska Oil and Gas Conservation Commission DATE: July 27, 1998 FILE NO: AKHJG1FE.DOC FROM' Lou Grimald i,~'?~. SUBJECT: Petroleum Inspector BOPE Test Doyon 15 BPX well #1-33/N-24 Endicott Field PTD #98-087 Monday, July 27, 1998: I witnessed the Initial BOPE test on Doyon rig 15 which was performing a redrill on BPX well #1-33/N-24 in the Endicott field. This rig had just come out of 10 days of summer maintenance. The rig was not ready to test when I arrived due to miscommunication between the rig and Eddie Vaughn (BP rep.). All BOPE equipment was tested with no failures observed. The Gas detectors were calibrated and checked "OK" while I was there. The test time of 4 hours is somewhat long for this rig and was caused by a troublesome test plug. Charlie Billings (Driller) conducted the test today and did a outstanding job of assuring his equipment was in good shape. Paul Carey (Motorman) Stood in for part of the test, and he also performed admirably. The rig was in good shape and I saw cleaning being performed throughout the rig. The area surrounding the rig was clear and kept neat and clean. The problem with early callout is not common for this rig and Eddie assured me would not become so. SUMMARY: I witnessed the initial test of the BOPE on Doyon rig #15 which is redrilling BPX well #1-33/N-24 in the Endicott Field. There were no failures observed. Test time 4 hours. Attachments: AKHJG 1 FE.XLS CC: Steve Walls/John Raul (Shared Services Drilling) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: Doyon Rig No. 15 PTD # BPX Re p.: 1-33/N-24 Rig Rep.: Set @ Location: Sec. Weekly Other DATE: 7/27/98 98-087 Rig Ph,# 659-6770 Eddie Vaughn Jim Willingham 36 T. 12N R. 16E Meridian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve N/A Well Sign P Drl. Rig P Hazard Sec. P Test Press. P/F 250/2500 P 1 250/5,000 P 1 250/5,000 P 1 250/5,0O0 P 3 250/5,000 P 2 250/5,000 P 1 250/5, 000 P 250/5, 000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250/5,000 P 1 250/5,000 P i 250/5, 000 P 1 250/5, 000 P CHOKE MANIFOLD: No. Valves 17 No. Flanges 42 Manual Chokes 2 Hydraulic Chokes 1 Test Pressure P/F 250/5,000 P 250/5,000 Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2,900 P 1,875 P minutes 27 minutes 51 P Remote: Four Bottles 2300 Psig. sec, sec. P TEST RESULTS Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 25 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7,542 Inspector North Slope Pager No. 6,59-3607 or 3687' If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good Test. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File .':- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R. Grimaldi FI-021L fRev.12/94) Akhjglfe.xls TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 20, 1998 Lowell Crane Drilling Engineering Supervisor BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Duck Island Unit 1-33A/N-24 BP Exploration (Alaska) Inc. Permit No. 98-087 Sur Loc: 3217'NSL, 2114'WEL. Sec. 36, T12N, R16E, UM Btmhol¢ Loc. 1061'NSL, 810'WEL, Sec. 31, T12N, R17E, UM Dear Mr. Crane: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated April 30, 1998 are in effect for this revision. in Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section W/o encl Department of Environmental Conservation xv/o encl . STATE OF ALASKA ALASKA ~..~_ AND GAS CONSERVATION COrv.,:,-,~SSlON PERMIT TO DRILL 20 AAC 25.005 REVISED: 7/08/98 [~ Drill '~Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [~ Development Oil 1 a. Type of work [] Re-Entry,,-l~bl raeepen [--I Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator !5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 56' Endicott Field / Endicott Pool 3. Address 16. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 312828 4. Location of well at surface i7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3217' NSL, 2114' WEL, SEC. 36, T12N, R16E, UPM Duck Island At top of productive interval 8. Well Number Number 2S100302630-277 1850' NSL, 1610' WEL, SEC. 36, T12N, R16E, UPM 1-33A/N-24 At total depth 9. Approximate spud date Amount $200,000.00 1061' NSL, 810' WEL, SEC. 31, T12N, R17E, UPM 07/21/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL047502, 1061'I No Close Approach 4299.74 12774' MD / 10200' TVDss 16. To be completed for deviated wells 117. Anticipated pressure {see 20 AAC 25.035 (e) (2)} KickOff Depth 11829' MD Maximum HoleAngle 53° Maximum surface 3596 psig, At total depth (TVD) 9775'/4574 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.4# L-80 STL 1624' 11150' 9318' 12774' 10200' 103 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 12425 feet Plugs (measured) ~ I ~} i true vertical 10347 BKB feet Effective depth: measured 12314 feet Junk (measured) true vertical 10259 BKB feet Casing Length Size Cemented MD TVD Structural BKB BKB Conductor 91' 30" Driven 130' 130' Surface 4974' 10-3/4" 1725 c.f. Permafrost, 690 c.f. Class 'G' 5013' 4390' Intermediate Production 12365' 7-5/8" 559 c.f. Class 'G' 12404' 10329' LinerRECEIVED Perforation depth: measured 12080'-12100', 12100-12120' JUL 09 1998 true vertical (subsea) 10019'-10034', 10034'-10050' Al¢0il & GasO0ns. 60m~f~"~0[I ' Anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Jeff//H'u'pP' 564-5480C7~ ~ ~ Chris West, 564-5089 Prepared By Name/Number: Carol Withey, 564-4114 21. I hereby certify that the forgoing is true and correct to the best of my knowledge Signed ..-z ~ . ~ Lowell Cr~,rCe '%,/,~,~t,~-( ~/.4 Title Drilling__. Engineering Supervisor Date // Commission Use Only Permit Number ~// APl Number I Approval Date See cover letter ~"~.-. ~ ~' ~' ,~"o - 0 2-. ~ - 2_2-- 5 ~ ~ - ~ /I "/-~,.-~) -."~ for other requirements Conditions of Approval: Samples Required []Yes [] No Mud Log Required []Yes [~]No Hydrogen Sulfide Measures ~]Yes I--I No Directional Survey Required ,J~Yes I~ No Required Working Pressure for BOPE 1--12M; [] 3M; [~15M; I--I 1OM; [] 15M 0rigina~llgr~ed By by order of Approved By David W. Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: I1-33a/N-24 Well Plan Summary Type of Well (Producer or injector)' Producer Well Design (Conventional, slimhole, etc.): -Ir'RD SIDETRACK FSL FEL SEC TWP RNG Surface Location: 3217 2114 36 12N 16E Top of Kekiktuk: 1850 1610 36 12N 16E Target 1 Location: 1458 921 31 12N 17E Target 2 Location: 1061 810 31 12N 17E Bottom Hole Location: 1061 810 31 12N 17E I AFE Number: 1 2702 I I Rig: I DOYON 15 Estimated Start Date: July 21, 1998 Operating days to drill and 12+3 complete: Formation Markers Well Bore: Formation Tops MD TVDSS EMW RESERVOIR PRESSURE KBE -56 Max surface pressure =3596 psi TOP WEST SAK Above KOP TOP SEABEE/AYLYAK Above KOP TOP SHALE WALL/TUFFS Above KOP TOP HRZ Above KKoOpP.~,,~ BASE HRZ Above .,.. PUT RIVER Above KOP ~,;'¢~., L C U A b o v e K O P "/~,~,~O~o ~'o" KEKIKTUK- Top 3A2S 9.3 ppg Above KOP 3A1 Above KOP K2B(2900F) 11790 9775 9.0 ppg 4574psi @ 9775' TVDss K2M (2400SB) 11935 9895 KOP 11829' MD / 9822' TVDss K2A (2300F) 12287 9955 8.7 ppg 4450psi @ 9905' TVDss Target COWC 12602 10085 K1 (2000) 12774 10200 8.0 ppg 4162 psi @ 10012' TVDss Target TD 12774 10200 MPI 1-33A/N-24 1 07/09/98 Logging Program: I I Logs: MWD-GR 3.75" Hole Curve and Tangent DPC Open Hole Cased Hole: GR/Res/CNL (if needed for fluid determination) NA Casing/Tubing Proc. ram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVDSS 3.75 2.875" 6.4 L-80 STL 1624 11150/9318 12774/10200 TBG* 4.5" 12.6 13-CR NSCT 11198 38 11198/9320' Note: The existing tubing will be left in place and re-used. Cementing Program (No nner String) Hole Section Liner Size Depth Volume Cement Production 2.875" Liner from Cement from _+ 21 BBL Class 'G' 11100' to 12774' 13040' to 0.45% Halad-344 with 2.875" x 4.5" 11300' 0.2% CFR-3 tie back sleeve in 0.25#/sk Super CBL 4.5" tubing tail HR-5 as required Mud Program: Production Mud Properties: 13.75" hole section' 6% KCL/Quik-Dril Depth Density Plastic Yield Tau 0 pH Fluid Flow Rate (PPG) Viscosity Point Loss Reservoir 10.0 <10 16 - 25 5 - 6 9.0-9.3 <4 100 MPI 1-33A/N-24 2 07/09/98 Hazards/Concerns Pore pressure (_+9.3 ppg EMW) based on offset max SIBHP. Lost Circulation due to overbalance in Flow sands. Differential sticking with overbalance situation. High circulating pressures of up to 4500 psig. Close annular clearance causing swab and surge pressures. Excessive Torque to be combated with lubricant additions after testing. Maintain minimum YP of 16 #/100 sq ft WELLHEAD EQUIPMENT Casing Head: ICasing Hanger: Tubinghead: X-mas Tree: FMC 10-3/4" X 13 5/8", 5M Flange SSH FMC 7-5/8" Mandrel Hanger FMC 13 5/8",5M X 13 5/8", 5M Cameron 4-1/8",5M DIRECTIONAL STATS FOR 7 5/8" CASING ON 1-33a/L-24 Average Angle: 37° Maximum Angle 53037"@ 9570' Maximum Dogleg 4.38°/100@4057' 3.41°/100'@4157' Top of Cement 11500' (Review of bond Io~1) 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 TTRD Team Leader Jeff Hupp 654-5017 345-4501 Production Engineer Mark Sauve 564-5407 279-9049 Reservoir Engineer Klm 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 MPI 1-33A/N-24 3 07/09/98 SUMMARY PROCEDURE COMMENTS 1. The 7-5/8" 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. 3. This well will be sidetracked at app. 11,829 md. PRE-RIG OPERATIONS 1. Test 4-1/2" tbg hanger void area to 3500 psi. Test 7-5/8" packoff to 3500 psi. 2. Pressure test IA and wellhead packoff (tubing and annulus) to 3,500psi. 3. RU slickline, Pull the WL SSSV. Drift and dummy off gas lift mandrels. 4. RU and run coil tubing across perforations to PBTD at 12275'+/-, establish circulation. 5. Spot 17.0 ppg fiber cement from 12275 to 11680', pull CT to 11000' and squeeze cement if possible up to 1500 psi maximum surface pressure. 6. Jet out excess cement down to 11790'md (39' above KOP @ 11829' MD). 7. Displace well to seawater while POH w/CT. Freeze protect last 1500' of well w/diesel. 8. RU Slickline. Tag cement top and correct top tbg tail depth. 9. After monitoring well for no pressure, set BPV. Remove flowline, level pad, dig out cellar. RIG OPERATIONS (SUMMARY) 1. Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. 2. Check that the well is dead. Pull BPV. If not circulate well w/brine or milling fluid until dead. 3. Run TWC and test. ND the tree, and NU the BOPE. Test the BOPE and pull TWC. (1/2 day). 4. Pick up 3.80" HC pilot hole mill, 1 ° 2-7/8" bent motor, Sperry 2-7/8" directional assembly and 2-3/8" SLH-90 Drill pipe. RIH & mill XN nipple to 3.80" ID using slick seawater. Record depth of XN nipple. 6. Tag cement top. Correlate cement top to collar log. Mill Iow side pilot hole to 11819' (10' above planned KOP) using SW. . MPI 1-33A/N-24 4 07/09/98 , , . 10. 11. 12. 13. 14. 15. 16. Roll tool face 180° and mill 10 ft ramp to the casing wall @ 11829' MD. Open PBL sub and displace well to 10.0 ppg mud. POH. Pick up 3.80" HC window mill, 3° 2-7/8" motor w 1.5° bent sub, Sperry 2-7/8" directional assembly on 2-3/8" SLH-90 Drill pipe. RIH and mill window through 7-5/8" casing and 5 feet of new hole. POH. RIH w/Baker finishing mill on 3° motor assembly. Back ream window to top of pilot hole. Pick up directional assy to build and turn @ 32°/100 feet to 86° at appx 12036' MD. Drop angle to 41 ° at TD Drill ahead as specified by the rig supervisor to 12774' md (TD). POOH. (12 days) 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 11150 to 12774 MD, cement as per plan. Pump plug w/KW brine. POOH and WOC. RIH to 1500' and freeze protect well. Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. Set the BPV. ND the BOPE, and NU the tree. Turn the well over to Production. MPI 1-33A/N-24 5 07/09/98 Ak__~-Collision Scan Results Operator: Field: BP Exploration Endicott Date : Scan of existing interference data 19:12, set Search Parameters :- ~inimum Search Depth(MD): ~aximum Search Depth(MD) : Search Radius at minimum search depth: Rate of Search Radius increase: 3ubject Well Plan Description Well: 1-33A/N-24 Rig: Doyon 15 06 Jul 98 11800.00 ft 12774.19 ft 1400.00 ft 100.00 ft/1000ft : 1-33A/N-24 Wp2 Subject Well Plan Data Points MD Inc Azm North (ft) (deg) (deg) (ft) 11800.00 36.900 111.140 -1394.95 11829.00 37.251 111.051 -1401.24 11859.00 40.066 114.646 -1408.53 11900.00 49.239 128.879 -1423.85 12000.00 75.893 151.203 -1492.01 12036.79 86.268 157.596 -1524.74 12100.00 86.268 157.596 -1583.05 12131.59 86.268 157.596 -1612.19 12200.00 82.171 160.434 -1675.72 12286.85 77.000 164.121 -1757.04 12300.00 76.044 164.121 -1769.34 12400.00 68.772 164.121 -1860.96 12500.00 61.500 164.121 -1948.17 12600.00 54.228 164.121 -2029.57 12700.00 46.956 164.121 -2103.83 12774.19 41.561 164.121 -2153.61 East TVD (ft) (ft) 5856.46 9854.65 5872.77 9877.79 5890.02 9901.22 5914.22 9930.42 5968.57 9976.54 5984.22 9982.24 6008.26 9986.35 6020.27 9988.41 6044.65 9995.30 6070.66 10011.00 6074.16 10014.07 6100.22 10044.27 6125.03 10086.29 6148.18 10139.45 6169.31 10202.89 6183.47 10256.00 DLS (deg/100ft) 1.224 12.000 33.001 33.000 33.001 0.000 0.000 7.273 7.271 7.269 7.272 7.272 7.272 7.272 7.272 0.000 Subject Well Survey Programme Details: Instrument Run Type Gyrodata multishot - gyrocompassing MWD - Standard (declination corrected) Planned Depths Start End (ft) (ft) 100.00 11800.00 11829.00 15000.00 Well : 1-29/M-25 '.~ Wellbore : 1-29/~125seql Survey : Definitive WDF - Composite Survey Description : Created by procedure WDFGEN2.2 Risk Criteria : Major/Minor-New SF Relative Surface Position Uncertainty Object Well WDF Composition Details: No Instrument Run Type 1 GCT - Outrun : 0.00 (ft) Actual Depths Start End (ft) (ft, l~ 51.00 14250 .'79 Interference Detected: MAJOR Risk Output Object Well Subject Well Allow Planned Hside Rel Mininum Allowable MD SMA Unc MD SMA Unc for well Angle Azi tolerable deviation (lsd) (lsd) bias separation separation from plan (ft) (ft) (ft) (ft) (ft) (ft) (deg) (ft) (ft) 12500.00 62.60 12538.80 50.67 0.00 1106.37 344.7 148.8 268.25 12600.00 63.32 12573.11 50.69 0.00 1092.75 341.7 145.8 275.09 12700.00 64.03 12608.65 50.72 0.00 1083.99 338.7 142.8 282.02 12800.00 64.73 12645.60 50.75 0.00 1079.77 335.8 139.9 289.02 12900.00 65.41 12683.89 50.78 0.00 1079.92 333.1 137.2 297.11 13000.00 66.08 12723.43 50.83 0.00 1084.62 330.5 134.6 305.26 13100.00 66.74 12764.11 50.90 0.00 1093.71 328.1 132.3 313.37 958.84 945 06 93 6 44 932 45 932 94 938 04 94 7 54 [~ell : 1-33/M-23 .. Wellbore : 1-33/~e~'23seql ~urvey : Definitive WDF - Composite 3urvey Description : Created by procedure WDFGEN2.2 {isk Criteria : Major/Minor-New SF {elative Surface Position Uncertainty Dbject Well WDF Composition Details: Instrument Run Type Gyrodata multishot - gyrocompassing : 0.00 (ft) Actual Depths Start End (ft) (ft) 100.00 12425.'6~0 [nterference Detected: MINOR Risk Output Object Well Subject Well Allow Planned Hside Rel Mininum Allowable MD SMA Unc MD SMA Unc for well Angle Azi tolerable deviation (lsd) (lsd) bias separation separation from plan (ft) (ft) (ft) (ft) (ft) (ft) (deg) (ft) (ft) £1800.00 49.39 11800.00 49.43 0.00 0.00 0.0 111~1 282.34 £1900.00 49.88 11898.47 49.63 0.00 7.84 219.5 347.9 274.02 £2000.00 50.38 11973.32 49.92 0.00 56.43 213.1 359.3 234.88 12100.00 50.88 12016.98 50.06 0.00 131.19 211.4 5.6 206.32 12200.00 51.37 12049.31 50.13 0.00 217.35 210.9 8.5 195.76 £2300.00 51.85 12096.40 50.22 0.00 305.57 210.7 8.3 198.16 ~2400.00 52.34 12146.67 50.31 0.00 393.73 210.5 8.7 198.73 ~2425.00 52.34 12162.05 50.34 0.00 415.64 210.5 9.3 197.21 -106.13 -228 45 -135 59 -18 32 89 61 176 78 262 95 283 10 ~ell : 1-65/N-25 ~ Wellbore : 1-65/l~-~25seql ~urvey : Definitive WDF - composite , ~urvey Description : Created by procedure WDFGEN2.2 {isk Criteria : Major/Minor-New SF {elative Surface Position Uncertainty Dbject Well WDF Composition Details: : 0.00 (ft) Actual. Depths Instrument Run Type Start End (ft) (ft) Gyrodata multishot - gyrocompassing 100.00 9800.D'0 MWD - Standard (input as multishot) 9858.50 13286.00 [nterference Detected: MAJOR Risk Output Object Well Subject Well Allow Planned Hside Rel Mininum Allowable MD SMA Unc MD SMA Unc for well Angle Azi tolerable deviation (lsd) (lsd) bias separation separation from plan (ft) (ft) (ft) (ft) (ft) (ft) (deg) (ft) (ft) .1800.00 47.55 12598.44 50.71 0.00 706.67 39.3 203.4 242.29 470.03 .1900.00 48.37 12649.88 50.75 0.00 672.42 36.4 200.5 252.85 427.28 .2000.00 49.24 12700.79 50.80 0.00 643.59 32.7 196.8 263.26 390.91 .2100.00 50.17 12751.50 50.88 0.00 617.99 28.6 192.7 273.62 358.54 ?ell : 1-65/N25PH Wellbore : 1-65/~J5pHseql ~urvey : Definitive WDF - Composite ~urvey Description : Created by procedure WDFGEN2.2 lisk Criteria : Major/Minor-New SF lelative Surface Position Uncertainty )bject Well WDF Composition Details: Instrument Run Type 1 Gyrodata multishot - gyrocompassing 2 MWD - Standard (input as multishot) : 0.00 (ft). Actual Depths Start End (ft) (ft) 100.00 9900. O~0 10025.01 13414.00 nterference Detected: MAJOR Risk Output Object Well Subject Well Allow Planned Hside Rel Mininum Allowable MD SMA Unc MD SMA Unc for well Angle Azi tolerable deviation (lsd) (lsd) bias separation separation from plan (ft) (ft) (ft) (ft) (ft) (ft) (deg) (ft) (ft) 1800.00 54.65 12607.86 50.71 0.00 987.71 8.5 172.6 269.68 779.22 1900.00 55.73 12648.55 50.75 0.00 975.14 6.2 170.3 278.78 761.92 2000.00 56.86 12689.55 50.79 0.00 969.15 3.8 167.9 288.16 751.85 2100.00 58.01 12730.71 50.84 0.00 970.23 1.5 165.6 298.11 749.45 2200.00 59.19 12771.84 50.91 0.00 978.56 359.2 163.3 307.91 754.84 ':---Summary of Contents ellbore Name -29/M-25seql -33/M-23seql -65/N-25seql -65/N25PHseql Survey Type Definitive WDF - Composite Definitive WDF - Composite Definitive WDF - Composite Definitive WDF - Composite ** End of Summary Interference Yes Yes Yes Yes , TREE: '-1/2" ,CAMERON W 5000 psi RT. ELEV -- 56.0' WELU D: 13 5/8" 5000 psi FMC BF. ELEV = 18.7' / / / ~I / / MAX DEV = 40° AT 3742' i I 10-3/4", 45.5#/ft, ' I [ L-80, BTC. CSG. -~ I~---- HES 'HXO' SYLN , (3.813" MIN. ID) 1581 I ~ O · W/SSSV MIN I.D. is 2.0" 5013' J 4-1/2", 13-CR, 12.6#/ft, ~' GAS LI~MANDRELS (HES) NSCT tubing 'KB~GM' w. 1" BK' LATCH ~i NO. MD-BKB ~D-SS ¢7 3946' 3490' ~6 6122' 5238' ~5 7447' 6302' ~4 8323' 7001' ¢3 9185' 7705' ¢2 10051 8391' ¢1 10956' 9099' 4-1/2" 'X' NIPPLE (HES) ~ i~ ~ ~-- (3.813" MIN. ID) 11099' I ~ '~ ~ 7-5/8" PACKER 1 1 1 10' ( TIW HB-BP-T ) 4-1/2", 12.6~/ff, L-80 TAILPIPE ~ ~ ] I ~~ 4-1/2" 'X' NIPPLE ::-~:.;~':'~::::~:~;::'~::~::';:;~::~ (HES) (3.813" ID) ~ 11175' 3.80" Window milled 11829' off ~;~;~,, ';~',~,~:: New SWle I 11150-12774' MD ~~~~ ~ Hole angle 80-85 deg ~.o ppg cmtf, .ETD P&A'd Pe~orations 12080-120' ........................................................... ~ :~ ~,'~:.~:.~:.~'~;~;~:~:.~:,::~;~;¢~::',~ :.::~:~:.~ PBTD I 12~14' I .............. 7-5/8", ................................................................................................. 29.7~/fl, I 124n4'I~&;[ L-80 NSCC DATE REV. BY (:OMMENTS ENDI60~ WELL 1-33NN-24 7/6/98 JLH Proposed ~RD Completion APl NO'50-029- COMPLETION DIAGRAM BP EXPLORATION, INC. GAS LIFT MANDRELS (HES) 'KBMGM' w. 1" BK' LATCH NO. MD-BKB -rVD-SS #7 3946' 3490' #6 6122' 5238' #5 7447' 6302' #4 8323' 7001' #3 9185' 7705' #2 10051 8391' #1 10956' 9099' Shared Services Drilling Well' 1-33A/N-24 Wp2 Proposal Data for 1-33A/N-24 WP2 Vertical Origin: Well Horizontal Origin: Well Measurement Units: ft North Reference: True North Dogleg severity · Degrees per 100fi Vertical Section ~zimuth: 157.560° Vertical Section Description: Well Vertical Section Origin: 0.00 N,0.00 E Measured Incl. Azim. Vertical Northings Eastings Vertical Dogleg Depth Depth Section Rate 11829.00 37.251 I 11.051 9877.79 1401.23 S 5872.77 E 3536.86 11859.00 40.066 114.646 9901.21 1408.52 $ 5890.02 E 3550.18 12.000 12036.79 86.268 157.596 9982.24 1524.73 $ 5984.22 E 3693.55 33.000 12131.59 86.268 157.596 9988.41 1612.18 S 6020.27 E 3788.14 0.000 12286.85 77.000 164.121 10011.00 1757.03 S 6070,65 E 3941.25 7.272 12774.19 41.561 164.121 10256.00 2153.60 S 618~.46 E 4350.86 7.272 ,Proposal Target Summary Target Name · TVDss: TVDrkb: 1-33A/N-24 TI 9955.00 10011.00 1-33A/N-24 T2 10200.00 10256.00 Wellhead Offsets: 1757.03 $, 6070.65 E 2153.30 S, 6183.46 E Global Coordinates: 5980400.00 N, 265100.00 E 5980000.00 N, 265200.00 E SURFACE LOCATION Horizontal Coordinates: 5982351.31 N, 259088.98 E RKB Elevation: 41.50 ft Rig (EST) 14.50 ft Well (CBE) 56.00 ft RKB - AMSL Coordinate System: NAD27 Alaska State Planes, Zone 3, US Foot PLOT DAT 6-JUL-98 Approved By: PRELIMINARY -1400 KOP: Start Dir @ 12°/100ft: 11829.00ft MD, 9877.7! Dir Rate Increase @ 33.0, 11859.00ft MD, 9901.21ft End Dir, Sail @ 86.268° · 12036.79ft MD, -1600 - Start Dir @ 7.272°/100ft · 12131.59ft Mr Continue Dir @ 7.272°/100ft- 12286.85 -1800 - --~,---- -- oett-:3 ~ 529. v~q.oott _.. \ ~,. a ~_ ..no~fo~r ...... ~;~~-'~/- ~s..~ ~o -~'~ ~np: ~ -.~ase ~ ' ~ ~, K2B (24~F)- 9836.~ ~D - .... v' _ K~ (23~3 7 7~11 ~ ~D ~ 7~.00 12~4.19 MD 'o%~ ~T~2~~ ~~ 10256.~ WD 0300 t ~E~-24 ~ I I I I I tO2~.~ ~ 3500 3700 3900 41 O0 ~00 2t~.~S. OI~.4OE Scale: linch = 20~ Section ~imuth: t57.560' (Tree No~h) Ve~ical Section -2000 - -2200 - Eastings 60 0o 1-VD )982.24ft TVD 9988.41 ft 'I-VD 10011.00ffTVD Poimt tOOt t.O0 10250.00 TYD "~ 21,9$.tgO & 0183.48E 2 7/8' 12774.19 MD 10256.00 'I'VD I 5800 6000 Scale: 1inch = 20Oft Eastings Reference is True North J DrillQuest' -1400 -1600 0 Z -1800 )00 ! 6200 Sperry-Sun Drilling Services Proposal Report for 1-33A/N-24 WP2 Endicott pRELIMINARY Alaska State Plane Zone 3 Endicott MPI Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) :~ (ft) Global Coordinates Dogleg Northings Eastings Rate fit) (ft) (°/100ft) Vertical Section (ft) Comment 11829.00 37.251 111.051 9821.79 9877.79 1401.23 S 5872.77 E 11859.00 40.066 ' 114.646 9845.21 9901.21 1408.52 S 5890.02 E 11900.00 49.239 128.879 9874.42 9930.42 1423.84 S 5914.21 E 11934.70 58.051 137.984 9895.00 9951.00 1443.09 S 5934.36 E 12000.00 75.893 151.203 9920.54 9976.54 1492.00 S 5968.57 E 12036.79 86.268 157.596 9926.24 . 9982.24 1524.73 S 5984.22 E 12100.00 86.268 157.596 9930.35 9986.35 1583.04 S 6008.26 E 12131.59 86.268 157.596 9932.41 9988.41 1612.18 S 6020.27 E 12200.00 82.171 160.434 9939.30 9995.30 1675.71 S 6044.64 E 12286.85 77.000 164.121 9955.00 10011.00 1757.03 S 6070.65 E 5980761.97 N 264913.66 E 5980754.13 N 264930.67 E 12.000 5980738.04 N 264954.36 E 33.000 5980718.16 N 264973.88 E 33.000 5980668.17 N 265006.49 E 33.000 5980634.96 N 265021.08 E 33.000 5980575.90 N 265043.23 E 0.000 5980546.39 N 265054.30 E 0.000 5980482.11 N 265076.62 E 7.272 5980400.00 N 265100.00 E 7.272 12300.00 76.044 164.121 9958.07 10014.07 1769.33 S 6074.15 E 12400.00 68.772 164.121 9988.27 10044.27 1860.95 S 6100.22 E 12500.00 61.500 164.121 10030.29 10086.29 1948.16 S 6125.02 E 12600.00 54.228 164.121 10083.45 10139.45 2029.56 S 6148.18 E 12602.65 54.035 164.121 10085.00 10141.00 2031.62 S 6148.76 E 12700.00 46.956 164.121 10146.89 10202.89 2103.82 S 6169.30 E 12774.19 41.561 164.121 10200.00 10256.00 2153.60 S 6183.46 E 5980387.59 N 265103.10 E 7.272 5980295.18 N 265126.21E 7.272 5980207.21N 265148.20 E 7.272 5980125.12 N 265168.72 E 7.272 5980123.03 N 265169.24 E 7.272 5980050.21 N 265187.45 E 7.272 5980000.00 N 265200.00 E 7.272 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 157.560° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12774.19ft., The Bottom Hole Displacement is 6547.76ft., in the Direction of 109.202° (True). 3536.86 3550.18 3573.58 3599.06 3657.32 3693.55 3756.62 3788.14 3856.16 3941.25 3953.95 4048.59 4138.67 4222.73 4224.87 4299.44 4350.86 KOP ' Start Dir @ 12°/100ft· 11829.00ft MD, 9877.79ft TVD Dir Rate Increase @ 33.000°/100ft' 11859.00ft MD, 9901.21ft 'I-VD K2M (2400SB) End Dir, Sail @ 86.268° · 12036.79ft MD, 9982.24ft TVD Start Dir @ 7.272°/100ft :'12131.59ft MD, 9988.41ft 'I'VD Continue Dir @ 7.272°/100ft· 12286.85ft MD, 10011.00ft TVD TKa2A (2300F) rget: 1-33'A/N-24 T1, Geological COWC Total Depth - 12774.19ft MD, 10256.00ft 'I-VD 2 7/8" Liher Target: 1-33A/N-24 T2, Geological 6 July, 1998 - 9:02 - 1 - DrillQuest Sperry-Sun ' Driiling Services Proposal Report for 1-33A/N-24 WP2 Endicott Alaska State Plane Zone 3 Endicott MPI Measured Vertical Depth Incl. Azim. Depth Northings Eastings (ft) (ft) (ft) (ft) Vertical Dogleg Section Rate (fi) (°/100ft) 11829.00 37.251 111.051 9877.79 1401.23 S 5872.77 E 11859.00 40.066 114.646 9901.21 1408.52 S 5890.02 E 12036.79 86.268 157.596 9982.24 1524.73 S 5984.22 E 12131.59 86.268 157.596 9988.41 1612.18 S 6020.27 E 12286.85 77.000 164.121 10011.00 1757.03 S 6070.65 E 12774.19 41.561 164.121 10256.00 2153.60 S 6183.46 E 3536.86 3550.18 12.000 3693.55 33.000 3788.14 0.000 3941.25 7.272 4350.86 7.272 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 157.560° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12774.19ft., The Bottom Hole Displacement is 6547.76ft., in the Direction of 109.202° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (~) (~) (~) (~) 11829,00 9877.79 1401.23 S 5872.77 E 11859.00 9901.21 1408,52 S 5890,02 E 12036,79 9982,24 1524,73 S 5984,22 E 12131.59 9988,41 1612,18 S 6020.27 E 12286.85 10011.00 1757.03 S 6070,65 E 12774,19 10256.00 2153,60 S 6183,46 E Comment KOP: Start Dir @ 12°/100ft: 11829.00ft MD, 9877.79ft TVD Dir Rate Increase @ 33.000°/100ft: 11859.00ft MD, 9901.21ft TVD End Dir, Sail @ 86.268°: 12036.79ft MD, 9982.24fl TVD Stad Dir @ 7.272°/100ft: 12131.59ft MD, 9988.41ft TVD Continue Dir @ 7.272°/100ft: 12286.85ft MD, 10011.00ft TVD Total Depth '12774.19ffMD, 10256.00~TVD Forma~on Tops Measured Vertical Sub-Sea Depth Depth Depth (~) (~) (~) 11934.70 9951.00 9895.00 12286.85 10011,00 9955.00 12602,65 10141,00 10085,00 Northings (ft) 1443.09 S 1757.03 S 2031.62 S Eastings Formation Name (ft) 5934.36 E K2M (2400SB) 6070.65 E K2A (2300F) 6148.76 E COWC Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> To Measured Vertical Depth Depth (ft) (ft) <Run-TD> <Run-TD> Casing Detail 2 7/8" Liner pp,,F.L! MtNAP,.Y Targets associated with this wellpath Target Name 1-33A/N-24 T1 1-33A/N-24 T2 Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 10011.00 1757.03 $ 6070,65 E 10256.00 2153,60 S 6183.46 E Target Shape Point Point Target Type Geological Geological 6 July, 1998.9:02 - 1 - DrillQuest 5631 Silverado Way #G Anchorage, Alaska 99518 (907) 563-3256 Fax (907) 563-7252 Shared Services Drilling Jeff Hupp PRELIMINARY left, The above mentioned well has been scanned using standard anti-collision methods via DEAP. Approved Well Close Approach Review 1-33A/N-24 WP2 The scan was performed with the following parameters: Start Scan Inspection Zone End Scan Inspection Zone Starting Scan Radius Rate of Radius Increase (per 1000') 11,800.00 ' 12,774.19' 1,400.00 ' 100.00' Anti-Collision Scan summary: At the planned KOP the Starting Scan Radius is 710' larger than DEAP's default settings of 100' Start Scan Radius increasing at 50' per 1000 'MD for a new-drill well scan, thus DEAP's defaults would be equal to 690' at the Start Scan Inspection Zone as stated above. These numbers are used to produce a final scan radius of 1497.419' which is 758.7095' larger than DEAP's default value of 738.7095' Scan Parameters Comments: At this enlarged radius the following wells were detected during the scan (Based on closest 'Allowable Deviation from Plan9: Note: this list may not include all the wells detected, only those of which are of concern or may effect Tolerance Line drawing! Comparison Sublec.t Well Planned Well Well; Deoth Seperatlon ~ I'- WellPlan MD} IPoint so Point} 1-33/M-23 11800.00 'MD 0.00 ' 1-33/M-23 11973.32 'MD 56.43 ' 1-33/M-23 12049.31 'MD 217.35 1-65/N-25 12751.50 'MD 617.99 ' Relative ,Mlowabl~ Azimuth Deviation t7'C Directioq } [Am~roJ~ TL 111.10 ° -106.13 ' 359.30 o -135.59 8.50 ° 89.61 Shut-in Reoulred? fSeoeration n~e~) No; Oril~inal Wellbore No; Ori~Lnal Wellbore No; Original Wellbore 192.70 ° 358.54 ' No Status Shut-In (Minor) Shut-In (Minor) Shut-In (Minor) Flowing (Major; Tolerance Plot required: NO Close Approach Comments: Close Approach S,c/gn~Pe~rm~d-fiby: ' Checked by: Approved by: Date: 6-Jul-98 Date: Date: ! Shared Services Approval: Date: 1-33An24wp2,xls _ AWD Proximity Review 7/6/98 WELL PERMIT CHECKLIST FIELD & POOL ____2..~_2.-(3,/,c~O ADMINISTRATION COMPANY INIT CLASS WELL NAME/-..~.~ ,,~,/~-/. - ~,//?/ PROGRAM: exp [] devy redrl~ serv [] wellbore seg Il ama. disposal para reqll 7 GEOL AREA <~)'?,C~ UNIT# //d") .4'./' c~ __,.~ ON/OFF SHORE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~"-'O~-C> psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y N GEOLOGY APPR DAT~ 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N /- 31. Data presented on potential overpressure zones ....... ~Y .. 32. Seismic analysis of shallow gas zones ............. ~ N ~~.L 33. Seabed condition survey (if off-shore) ............. ,/'Y NY N 34. Con, tact,nam, e/phon,e.for weekly progress repods ....... / Y N lexploratory onwj ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan / (A) will contain waste in a suitable receiving zone; ....... Y N //3r (B) T~lls~fta~?taminate freshwater; or cause drilling waste.., yy (C) will not impair mechanical integrity of the well used for disposal;,//Y' N (D) will not damage producing formation or impair recovery from a,-" Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: DWJ. ~--EE W----?//~ RNC JDH ,~ - co Comments/Instructions: M:cheklist rev 05~29~98 dlf: C :\rnsoffico,\wordiar'l\diar~a\cl']ecM i,":t TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 30, 1998 Steve Shultz Drilling Enginccring Supervisor BP Exploration (Alaska), Inc. POBox 196612 Anchorage, AK 995 l 9-6612 Rtz Duck Island 1-33A/L-24 BP Exploration (Alaska), Inc. Permit No. 98-87 Sur. Loc. 3217'NSL. 2114'WEL, Scc. 36. T12N. R16E. UM Btmnholc Loc. 3115'NSL, 897'WEL. Scc. 31, Ti2N. R17E. UM Dcar Mr. Shultz: Encloscd is thc approvcd application for permit to rcdrill thc abovc rcfcrcnccd well. The permit to rcdrill does not cxcmpt you from obtaining additional pcrmits rcquired by law from other governmcntal agcncics? and docs not authorize conducting drilling operations until all other rcquircd pcrmitting dctcrminations are made. Blowout prevention cquipmcnt (BOPE) must be tcstcd in accordance with 20 AAC 25 035. Sufficicnt noticc (approximatcly 24 hours) must be given to allow a rcprcscntativc of thc Commission to witncss a test of BOPE installed prior to drilling new holc. Noticc may be given . specter on thc North Slopc pager at 659-3607. David W. J6h~ston Chairman ~ BY ORDER OF THE COMMISSION dlf/Enclosures CC~ Dcpamncnt of Fish &Gamc. Habitat Section w/o cncl. Dcpartmcnt of Environmcntal Conscrvation w/o cncl. STATE OF ALASKA ALASKA,--=-~L AND GAS CONSERVATION COi'~,41SSlON PERMIT TO DRILL 20 AAC 25.005 :la. Type of ~rk [--I Drill I~Redrill lb. Typeofwell [-I Exploratory [-I Stratigraphic Test I~ Development Oil; '~ I--I Re-Entry [] Deepen []Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Op~ator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploratior~(Alaska) Inc. Plan KBE - 56' Endicott Field / En/di~ott Pool '3. Address 2,~ 6. Property Designation~ ///' P.O. Box 19661 nchorage, Alaska 99519-6612 ADL312828 ~' 4. Location of well at su-~ace 7. Unit or Property Name 11. Type Ben. See 20 AAC 25.025) 3217' NSL, 2114' WI~, SEC. 36, T12N, R16E, UM Duck Island At top of productive intei~al 8. WellNumber ~p:~aer ~8100302630-277 1882' NSL, 1194' WEL,'~EC. 31, T12N, R17E, UM 1-33A/L-24 Attotal depth ~ 9. Approximate spud date /Amount $200,000.00 3115' NSL, 897' WEL, SEO~31, T12N, R17E, UM 05/05/98 / 12. Distance to nearest property lin~ 13. Distance to nearest well 14. Number of acres in property'! 15. Proposed depth (MD and TVD) ADL047502, 3115'r~ No Close Approach 4299.74/"~ 13040' MD / 10030' TVDss 16. To be completed for de, viated w~ls 17. Anticipated pressure {s~20 AAC 25.035 (e)(2)} Kick Off Depth 11505 MD I~aximum Hole Angle 53° Maximum surface 373,~ psig, At total depth (-I-VD) 9695' / 4700 psig 118. CaS;gzeProgram Speci~,ations Setting Deptf),/ Top //' Bottom Quantity of Cement Hole Casing Weight Grade O~upling Length MD TVD //MD TVD (include stage data) 3-3/4" 2-7/8" 6.4 L-80 '~TL 1890' 11150' 9318' //13040' 10030' 100 sx Class 'G' / / 19. To be completed for ReOrill, Re-entry, and Deepe~,,~Operations. / Present well condition summary ~ / Total depth: measured 12425 feet P~gs (myasured) true vertical 10347 BKB feet ~ ~ ~'' ' Effecbve depth measured 12314 feet Junun/~mmeasured) true vertical 10259 BKB feet J/ \easure Casing Length Size ~ ~ Cemented MD Structural ~ ~ BKB BKB Conductor 91' 3~" Driven % 130' 130' Surface 4974' 1/0-3/4"1725 c.f.~P~ermafrost, 690 c.f. Class 'G' 5013' 4390' Intermediate ~ ,rnO drUCt,on 1 404' 103 9' Perforation depth: measureO/2080'-;21_O_O',_i~1_~-;21.~'- ...... L.~¢ l i::~ t J\,J Pt L true v~al (subsea) 10019'-l(J(JLs4', ~u_u;~4'-~uu~u' 20. Attachments [] Filing Fe~ ~P~3~rty Plat [] BOP Sketch II DN, erter Sketch [] Drilling Program [] Drillin¢luid Program []Time vs Depth Plot [] Refraction Analysis [] Se~,~d Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Numb/ Jeff Hupp, 564-5480 Chris West, 564-5089 Prepared Name/Number: Carol Withey, 564-4114 21. I hereby certi/,fyyt the r going i ue a d correct to the best of my knowledge~ (~~, ~ ( sor' o~ //'~.~/~ ~' Signed Ste,e~n~tz Title Drilling Engineering Supervi Date Commission Use Only Permit Numl~r APl Number Ap, proval Date,,~ I See cover letter ("/¢~'~ O 4~ 7 50- ~ ~ ~- ~ ~.~ 7' 7 - O ( ,,/¢' °~¢,~;)-'~ ~~ for other requirements Conditi.et~s of Approval: Samples Required []Yes .[~No Mud Log Required ~Y, es Hydrogen Sulfide Measures [~Yes [-INo Directional Survey Required l~'¥es EINo Required Working Pressure for BOPE []2M; []3M; I~,5M; [] 10M; Other: OrJg,nal ~.-~..., by order of ,,,, .,~,~.~ ~;;;~. .... ~ ~ ";'~ -') Commissioner the commission Date " Approved By Fire,iH ~ ,.-.~. ....... '~i'l Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: I1-33a/L-24 Well Plan Summary Type of Well (Producer or injector): Producer Well Design (Conventional, slimhole, etc.)' -I-I-RD SIDETRACK FSL FEL SEC TWP RNG Surface Location: 3217 2114 36 12N 16E Top of Kekiktuk: 1882 1194 31 12N 17E Target 1 Location: 2436 998 31 12N 17E Target 2 Location' 3059 905 31 12N 17E Bottom Hole Location' 3115 897 31 12N 17E I AFE Number: 172~027 I Rig' ]DOYON 15 I Estimated Start Date: May 5, 1998 Operating days to drill and complete: 12+3 Formation Markers Well Bore: Formation Tops MD TVDSS EMW RESERVOIR PRESSURE KBE -56 Max surface pressure :3730 psi TOP WEST SAK Above KOP TOP SEABEE/AYLYAK Above KOP TOP SHALE WALL/TUFFS 8955 Above KOP TOP HRZ 11414 9475 KOP 11505' MD / 9560' TVDss BASE HRZ 11656 9680 PUT RIVER 11656 9680 LCU 11676 9695 KEKIKTUK - Top 3A2S 11676 9695 9.3 ppg 4700psi @ 9695 TVDss 3A1 11759 9755 K2B(2900F) 11790 9775 9.0 ppg 4550 @ 9775' TVDss K2M (2400SB) 12033 9870 K2A (2300F) 12309 9905 8.7 ppg 4450psi @ 9905' TVDss Target CGOC 12633 9960 K1 (2000) 12935 10012 8.0 ppg 4162 psi @ 10012' TVDss Target TD 13040 10030 COWC Below Planned TVD of Target MPI 1-33A/1-24 1 04/22/98 Logg ing Program: ,: ? i' ! ? / Logs: MWD-GR 3.75" Hole Curve and Tangent DPC Open Hole Cased Hole: GR/Res/CNL (if needed for fluid determination) NA Casing/Tubinc. Proc. ram: Hole Csg/ Wt/Ft Grade Corm Length Top Btm Size Tbg O.D. MD/TVD MD/TVDSS 3.75 2.875" 6.4 L-80 STL 1890 11150/9318 13040/10030 TBG* 4.5" 12.6 13-CR NSCT 11198 38 11198/9320' Note' The existinc, tubing will be left in place and re-used. Cementing Program (No inner String) Hole Section Liner Size Depth Volume Cement Production 2.875" Liner from Cement from + 21 BBL Class 'G' 11100' to 13040' 13040' to 100 sx 0.45% Halad-344 with 2.875" x 4.5" 11300' 0,2% CFR-3 tie back sleeve in 0.25#/sk Super CBL 4.5" tubing tail HR-5 as required Mud Program: 13.75" hole section' 6% KCL/Gem Production Mud Properties: Depth Density Plastic Yield Tau 0 pH Fluid Flow Rate (PPG) Viscosity Point Loss Reservoir 10.0 <10 16 - 25 5 - 6 8.5 - 9.0 <4 100 Hazards/Concerns Mud weight is based on drilling HRZ shale interval Pore pressure (+9.3 ppg EMW) based on offset max SlBHP. Lost Circulation due to overbalance in Flow sands. Differential sticking with overbalance situation. High circulating pressures of up to 4500 psig. Close annular clearance causing swab and surge pressures. Excessive Torque to be combated with lubricant additions after testing. Maintain minimum YP of 16 #/100 sq ft MPI 1-33A/1-24 2 04/23/98 WELLHEAD EQUIPMENT Casing Head: Casing Hanger: Tubinghead: X-mas Tree: FMC 10-3/4" X 13 5/8", 5M Flange SSH FMC 7-5/8" Mandrel Hanger FMC 13 5/8",5M X 13 5/8", 5M Cameron 4-1/8",5M DIRECTIONAL STATS FOR 7 5/8" CASING ON 1-33a/L-24 Average Angle: 37° Maximum Angle 53° 37" @ 9570' Maximum Dogleg 4.38°/100@4057' 3.41 °/100' @4157' Top of Cement 11500' (Review of bond log) Contacts Office Home Paqer 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 TTRD Team Leader Jeff Hupp 654-5017 345-4501 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 MPI 1-33A/1-24 3 04/22/98 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. 3. This well will be sidetracked at app. 11,500 md. PRE-RIG OPERATIONS 1. Test 4-1/2" tbg hanger void area to 3500 psi. Test 7-5/8" packoff to 3500 psi. 2. Pressure test IA and wellhead packoff (tubing and annulus) to 3,500psi. 3. RU slickline, Pull the WL SSSV. Drift and dummy off gas lift mandrels. 4. RU and run coil tubing across perforations to PBTD at 12275'+/-, establish circulation. 5. Spot neat 17.0 ppg cement from 12275 to 11700', pull CT to 11000' and squeeze cement if possible up to 1500 psi maximum surface pressure. POOH. 6. Clean out excess neat cement down to 11700' md. Spot fiber cement f/11700-11360'. Jet out excess cement down to 11470'md (35' above KOP @ 11505' MD). 7. Displace well to seawater while POH w/CT. Freeze protect last 1500' of well w/diesel. 8. RU Slickline. Tag cement top and correct top tbg tail depth. 9. After monitoring well for no pressure, set BPV. Remove flowline, level pad, dig out cellar. RIG OPERATIONS (SUMMARY) 1. Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. 2. Check that the well is dead. Pull BPV. If not circulate well w/brine or milling fluid until dead. 3. Run TWC and test. ND the tree, and NU the BOPE. Test the BOPE and pull TWC. (1/2 day). 4. Pick up 3.80" HC pilot hole mill, 1 ° 2-7/8" bent motor, Sperry 2-7/8" directional assembly and 2-3/8" SLH-90 Drill pipe. 5. RIH & mill XN nipple to 3.80" ID using slick seawater. Record depth of XN nipple. MPI 1-33A/1-24 4 04/22/98 o . , . 10. 11. 12. 13. 14. 15. 16. Tag cement top. Correlate cement top to collar Icg. Mill Iow side pilot hole to 10495' (10' above planned KOP) using SW. Roll tool face 180° and mill 10 ft ramp to the casing wall. Open PBL sub and displace well to 10.0 ppg 6% KCI % GEM mud. POH. Pick up 3.80" HC window mill, 3° 2-7/8" motor w 1.5° bent sub, Sperry 2-7/8" directional assembly on 2-3/8" SLH~90 Drill pipe. RIH and mill window through 7-5/8" casing and 5 feet of new hole. Do a FIT to 12.0 PPG EMW. POH. RIH w/Baker finishing mill on 3° motor assembly. Back ream window to top of pilot hole. Pick up to turn and build @ 17°/100 feet to 92° at appx 12,523' MD. Drop angle to 78°. Drill ahead as specified by the rig supervisor to 13,143. POOH. (12 days) 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 13,143 MD, cement as per plan. Pump plug w/ KW brine. POOH and WOC. RIH to 1500' and freeze protect well. Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. Set the BPV. ND the BOPE, and NU the tree. Turn the well over to Production. MPI 1-33A/1-24 5 04/22/98 MPI Well 1-33A/L24 (Wp1) Surface and Downhole Locations Section Line Ties 4/22/98 NW Sec36 T12N R16E Umiat X=255990.65 Y=5984514.54 o~ SW Sec 36 T12N R16E Umiat X=255822.36 Y=5979237.41 528O 91 °50'48" NW Sec 31 T12N R17E Umiat NE Sec 36 T12N R16E Umiat X=261267.72 Y=5984344.40 '1-33A/L-24 Surface Location X=:259088.98 Y=5982351,31 5280 91 °50'47" 2114 o~ SW Sec 31 T12N R17E Umiat SE Sec 36 T12N R16E Umiat X=261099.45 Y=5979067.29 4862 91 °48'28" NE Sec 31 T12N R17E Umiat X=266126.82 Y=5984191.03 1~33A/L~24. T2 X=265160,00 Y=5982000,00 '1-33A/L-24 T1 X=265050.00 Y=598'1380,00 1-33A/L-24 Top Of Kek X=264839.16 Y=5980833,13 4884 91 °48'28" 1~33A/L 24. TD X=2651'7 ,00 Y=59820 6.36 o SE Sec 31 T12N R17E Umiat X=265980.58 Y=5978913.24 SPERRY-SUN FAX NO, 49075635754 -~_: P, 03 Shared Services Drilling 1-33ALL-24 Wp1 DrillQuesf PROPOSAL TARGET SUMMARY Tar§at blame: TVD..qSTVDRKB: Wellhead OIl'$els: Global Coordir, ate$: 1.33gU24 T1 9910.009966.00 770.14 S, 5~8g. 17 E 59B~ 380.00 N, 265050.00 E ',.33ML-24 T2 10020.00 10076.0{3 1 $5.92 S, 8079.18 E 5982000.00 N, 265160.00 E SURFACE LOCATION I PLOT DATE: 20-APR,.98 t Eleval~: 41.50 fl R~ {ES~ C~ordhsla 5ys[em:NA027 A~ Slate P~nes, I Z~o 3, US F~t [ I Proposal Data for 1-33aji.-24 Wp1 , varticlal Origin: Hortzontal Origin: Well M~uremenl Urits: N,~rth Reference:True Nodh vDorg Severity: Oegree~ per lOOft ertic_~.l ,q eclion ,kzirnulh: 17.658" Verlical Sec{ion Oescriplion: Wetl Verlic.~l SOClion Origin: 0.{30 N,0.00 E Measured Incl. Azim, Vertical Nodhlngs Eaatlllga Vertical Depth Dspth Section Pale 11505.ffi 35.145110,065 rJ6t 5.87 1334,13 S 5694.27 E 456.00 11545.0037.74510.t.2679~18.0~ 1340.90 $ 5711.01 E 456.45 12.0(10 1202852 8~-711 g.677 9925A0 10~6.98 g 5942.32 E 766.74 12309.3l82flll 8.671 0961.03 811.64 $ 59~.M E 1041.86 1234Z55 80.091 8,218 9966,00 779.14 g 5989.17 g 1074.29 1~81.77 g0.09l 821g 10076.00 155.925 60~9.18 E 1695.45 0.~ 13039.~ggO.091 8.218 10086.00 ~9.27 $ 608736 F-. 1751,92 O,t"~ -200 - -400 - -600 - ~ -8oo - Scale; linch = 20Oft Eastings 54~0 56100 58100 60100 62~00 2 7/8" Liner - TTRD/TD 13039.88 MD 10086,00 TVD Target 2 10078,00 fl/O +- 10 l~&92 8, 8079. l$ g End Dir, Sail @ 80.091°: 12342.55[t MD, 9966.00fl Start DIr @ 8.000°/100ft · 12309,32ft MD, 9961.03fi £-241'ar~g l 90aa. th9 ?'YO +- 1o' TI/D 779.145,~9~g. 17~ .1000 End DIr, Sail @ 82.71¢ ' 12028,52fl MD, 9925,40ft -1200 9900.0( KOP ' Start Dir @ 12.000~/100fl ' 11505.00ft MD, 9615.87fl T~D -1400 '-I o Dir Rate Increase @ lq. 000/100ft · 11545,00ft MD~ 9648.06ft TVD I I 5400 5600 Scale: linch = 20Oft I 5800 Eastings 6000 6200 Referencels True No~h tYO - -200 - -400 - -600 - -800 --t000 -4200 - -1400 Shared Services Drilling 1-33ALL-24 Wp1 I DrillQuest' PROPOSAL TARGET SUMMARY TVDSS TVDRKB: Wellhead Differs: GIob~ Coo~ltnates: 9910.009966.00 779.14 S. 5989,17 E 5981380.00 N, 2650$0.O0 E 10020.00 10076.O0 155.9Z S, c-:O79.18 E 5902000.00 N, 265160.00 E SURFACE LOCATION I PLOT DATE: 20-APR-98 Coord~e, te Syatam: NAD'Z7 Alask~ Slate Pianos. It Zone 3, US Foot It / 9700 9900 1 ol OO I Propos_~al Data for 1-33a/L-24 Wp1 Vertical Origin: Well Ho~ontal Origin: Well Me..3aureq~rd Uni'~s: ft North Releco4'x~e: TnJe North Veft~'d SeCtiofl Azimuth: 17. 56= Veatc~ Section Dec~dplio~ Well VerUca] Sectk~ Odgln: o.oO N.O.00 E Measured If mi. Azim., Vertical Northing~ Easflf~gG VerticalDogleg Depth Oepth Section Rate H[505,0035.145t 10.0~ 9615.87 1334.135 5694,27 E 4~.~ tl~5,~ 37.745103267 9~8.~ l~.~S 57 LT.01 E4~.45 12.~ t20~,52 8~711 8.677 ~.~ 1086.98 s 5~Z.32 E 7~.74 123~32 82.711 8.677 ~1,03 8tt.~ S 59~E t~t~ 0.~ [~255 ~.~ 8.218 ~,~ 7~9.t4 S 59~.17 E t074-~ 1~8137 80.~1 8.2t~ l~7&~ ~55.92 ~ ~79.18 E 1~5.~ 0.~ 1~39,88 ~0.~1 8~ta 1~86.~ ~27S ~87.~ E 1751.92 0.~ [ I. k .~, _ ~ ~ ___ ~~- ~7~.~ ~ ~.~: :: _~__: :_: ..... ~,~ ...... ~A/- ~8//.oo ~D _ _ _ _ _ _ _ _ - - ........... ........... . , _ . . ~ ...... ~~ ................ ~ ~ ............... K2M (2400XBI FLrD- 9926.~ ~D ~ 4 ~ t 126~.~ ~ ~/(~ooo~ - ~o~.oo ~a ] r Z~Z8~ ~O +- tO'~ 13039.88 MD [J ' I i I i 1 I~5~2S.~79. I8E I 10086.00 ~D 500 700 900 t ~ 00 1300 ~ 500 1700 Scale: ~inch = 200ff Ve~ica] Sectio~ Section Aimuth: 17.658° (Tree No~h) Endicott Measured Depth (ft) 11505.00 11545.00 11600.00 11656.37 11675.96 11700.00 11759.33 11790,09 11800.00 11900,00 12000,00 12028,52 12033,22 12100,00 12200.00 12300.00 12309.07 12309.32 12342.55 12400.00 12500.00 12600,00 12633.11 12700.00 12800.00 12900.00 12935.28 12981.77 13000.00 I3039.88 Incl. 35.145 37.745 37.461 39.435 40,607 42.344 47.791 51.125 52,258 64,838 78.660 82.7I 1 82.711 82,711 82.711 82.711 82.711 82.711 80.091 80.091 80.091 80.091 80.091 80,091 80,091 80.091 80,091 80,091 80.091 80.091 Azim. 110.065 103.267 87.014 70.97O 65.799 59.811 46.802 40.982 39.226 24.057 11.874 8,677 8.677 8.677 8.677 8.677 8.677 8.677 8.218 8.218 8.218 8.218 8.218 8.218 8.218 8.218 8.218 8.218 8.218 8.218 Sub-Sea Depth (ft) 9559.87 9592.06 9635.74 9680.00 9695.00 9713.02 9755.00 9775.00 9781.14 9833.44 9864.79 9869.40 9870.00 9878.47 9891.16 9903.85 9905.00 9905.03 9910.00 9919.89 9937.09 9954.30 9960.00 9971.51 9988.72 1O0O5.93 10012.00 10020.00 10023.14 10030.00 Sperry-Sun Drilling Services Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 9615.87 9648.06 9691.74 9736.00 9751,00 9769,O2 9811.00 9831.00 9837.14 9889.44 9920.79 9925.40 9926.00 9934.47 9947.16 9959.85 9961.00 9961.03 9966.00 9975.89 9993.09 10010.30 10016.00 10027.51 10044.72 10061.93 10068.00 10076.00 10079.14 10086.00 Proposal Report for 1-33alL-24 Wp1 1334.13 S 5694.27 E 1340.90 S 5717.01 E 1343.89 S 5750,18 E 1337.15 S 5784.32 E 1332.50 S 5796.02 E 1325.22 S 5810.16 E 1300.06 S 5843.55 E 1283.21S 5859,72 E 1277.26 S 5864.72E 1204.71 S 5908.54 E 1114.67 S 5937.31 E 1086.98 S 5942.32 E 1082.38 S 5943.03 E 1016.89 S 5953,02 E 918,84 S 5967.98 E 820.78 S 5982.95 E 811.88 S 5984.30 E 811.64 S 5984.34 E 779.14 S 5989.17 E 723.13 S 5997.26 E 625.64 S 6011.34 E 528,14 S 6025,42 E 495,86 S 6030,08 E 430,64 S 6039,50 E 333,15 S 6053,58 E 235.65 S 6067,66 E 201.25 S 6072.63 E 155.92 S 6079.18 E 138.15 S 6081.74 E 99.27 S 6087.36 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fi) (fi) (°/lOOft) (ft) 5980834.78 N 264737.41 E 456.00 5980827.29 N 264759.92 E 12.000 456.45 5980823.22 N 264792.98 E 18.000 463.65 5980828.87 N 264827.32 E 18,000 480.44 5980833.13 N 264839.16 E 18.000 488.41 5980839.96 N 264853.52E 18.000 499.64 5980864.03 N 264887.70 E 18.000 533.74 5980880.35 N 264904.41 E 18.000 554.71 5980886.14 N 264909.60 E 18.000 561.89 5980957.24 N 264955.73 E 18.000 644,31 5981046.31N 264987.38 E 18.000 738.84 5981073.82 N 264993.28 E 18,000 766.74 5981078_40 N 264994.13 E 0.000 771,34 5981143,53 N 265006,22 E 0,000 836.77 5981241.06 N 265024.33 E 0.000 934.75 5981338.58 N 265042.44 E 0,000 1032.73 5981347.43 N 265044.09 E 0.000 1041.62 5981347.67N 265044.13 E 0.000 1041.86 5981380.00 N 265050.00 E 8,000 1074.29 5981435.72 N 265059.89 E 0,000 1130.11 5981532.71N 265077.09 E 0.000 1227.29 5981629.71 N 265094.30 E 0.000 1324.46 5981661.82 N 265100.00 E 0.000 1356.64 5981726,70 N 265111,51 £ 0.000 1421.64 5981823,69 N 265128.72 E 0.000 1518.81 5981920.69 N 265145.93 E 0.000 1615.98 5981954.91 N 265152.00 E 0.000 1650.27 5982000,00 N 265160.00 E 0.000 1695.45 5982017.68 N 265163.14 E 0.000 1713.16 5982056,36 N 265170.00 E 0.000 1751.92 Alaska State Plane Zone 3 Endicott MPI Comment KoP - Start Dir @ 12.000°/100ft' 11505.00ff MD, 9615.87ft TVD Dir Rate Increase @ 18.000°/100ff' 11545.00ft MD, 9648.06ft TVD BHRZ./TPTR LCU/3A2S 3A1 K2B (2900F) End Dir, Salt @ 82.710° - 12028.52ft MD, 9925.40ft TVD K2M (2400SB) FLT'D K2A (2300F) Stad Dir @ 8.000°/100ft- 12309.32ff MD, 9961.03ft TVD End D[r, Sail @ 80.091 °: 12342.55ff MD, 9966.00ft TVD Target: L-24 Target 1, Geological CGOC K1 (2000) Target: L-24 Target 2, Geological Total Depth · 13039.88ft MD, 10086.00ft TVD 2 7/8" Liner TTRD Continued... z 0 ~n ~nrfl. lg,ql~ ~ 11:37 - 1- DrillOuest Sperry-Sun Drilling Services Proposal Report for 1-33alL-24 Wp1 Endicott Ail 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 17.658° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13039.88ft., The Bottom Hole Displacement is 6088.17ft., in the Direction of 90.934° (True). Alaska State Plane Zone 3 Endicott MPI x DrillOuest -2- NON 11:31 ~N SPERRY-SUN ~L~E~KP~ F~× NO, '9075635754 ,~ , Sperry-Sun Drilling Services Proposal Report for 1-33a/L-24 Wp ~ P, 06 Endicott Alaska State Plane Zone 3 Endicott MPi Measured Vertical Vertical Depth Incl. Azim. Depth Northings Eastings Section (ft) (ft) (ft) (ft) (ft) 11505.00 35,145 110,065 9615.87 1334,13 S 5694.27 E 11545,00 37.745 103.267 9648.06 1340.90 S 5717.01 E 12028,52 82,711 8.677 9925.40 1086.98 S 5942.32 E 12309.32 82,711 8.677 9961.03 811,64 $ 5984.34 E 12342.55 80,091 8.218 9966.00 779.14 S 5989,17 E 12981,77 80.091 8.218 10076.00 155.92 S 6079.18 E 13039,88 80,091 8.218 10086,00 99.27 S 6087.36 E Dogleg Rate (°/100ft) 456.00 . 456,45 12.000 766.74 18.000 1041,86 0.000 1074.29 8,000 1695,45 0.000 1751.92 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 17,658° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13039,88ft., The Bottom Hole Displacement is 6088.17ft., in the Direction of 90.934° (True). Comments Measured Depth 11505,00 11545.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 9615.87 1334,13 S 5694.27 E 9648.06 1340.90 S 5717,01 E 12028.52 9925.40 1086.99 S 5942,32 E 12309.32 9961,03 811.64 S 5984,34 E 12342,55 9966.00 779,15 S 5989.17 E 13039.88 10086.00 99,27 S 6087,36 E Comment KOP: Start Dir @ 12.000°/100ft: 11505.00fl MD, 9615.87ft TVD Dir Rate Increase @ 18.000°/100ft: 11545.00ft MD, 9648.06ft TVD End Dir, Sail @ 82.710°: 12028.52ft MD, 9925.40ft TVD Stad Dir @ 8,000°/lO0ft: 12309.32ft MD, 9961.03ft TVD End Dir, Sail @ 80.091°: 12342.55ft MD, 9966.00ft TVD Total Depth: 13039.88ft MD, 10086.00ft TVD Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Nothings Eastings Formation Name (fi) (fi) (ft) ~t) (fi) 11656,37 9736,00 9680.00 1337.15 s 5784,32 E BHRZ/TPTR 11675,96 9751.00 9695,00 1332.50 S 5796.02 E LCU/3A2S 11759,33 9811,00 9755.00 1300.06 S 5843,55 E 3A1 11790,09 9831,00 9775,00 1283,21S 5859,72 E K2B (2900F) 12033,22 9926,00 9870,00 1082,38 S 5943.03 E K2M (2400SB) FLT'D 12309.07 9961,00 9905,00 811.88 S 5984,30 E K2A (2300F) 12633.11 10016.00 9960.00 495,86 S 6030,08 E CGOC 12935.28 10068,00 10012.00 201,25 S 6072,63 E K1 (2000) Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surf&ce> To Measured Vertical Depth Depth (ft) (ft) <Run.TD> <Run-TD> Casing Detail 2 7/8" Liner- TTRD Continued,., ~P~-20-98 tqONl1:31 SPERRY-SUN RLRSKR FR× NO, ~q075635754 Sperry-Sun Drilling Services Proposal Report for 1-33a/L.24 Wp1 P, O? Endicott Alaska State Plane Zone 3 Endicott MP! Targets associated with this wellpath Target Name L-24 Polygon L-24 Target 1 L-24 Target 2 Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 9966,00 761,56 S 5913.56 E 9966.00 779.14 S 5989.17 E 10076.00 155.92 S 6079.18 E Target Target Shape Type Polygon Geological Point Geological Point Geological · 2, DriliOuest ,qPR-20-98 NON 11:32 AN SPERRY-SUN aLASKA FAX NO, "-q-075635754 Sperry-Sun Drilling Services i=roposal Data- 1-33a/L-24 P, 08 PR-20-98, NON 11 ,qFl SPERRY-SUN tqLfiSKfi FPi× NO, -9075635754 P, 09 5631 Silverado Way #G Anchorage, Alaska 99518 (907) 863-3256 Fax (907) 563-7252 Shared Services Drilling Chris West The above mentioned well has been scanned using standard anti-collision methods via DEAP. '['he scan wa~ performed with thc following paxameters: Start Scan Inspection Zone End Scan Inspection Zone Starting Scan Radius Rate of Radius Incl~ase (l~r 10009 .~ t,505.90' 13,039.88' 1,300.00 ' 100.00 ' Approved Well Close Approach Review 1-33A/L-24 Wp1 Anti-Collision Scmt summary: At thc planned KOP the Starting Scan Radius is 624.75' larger thaa~ DEAP's default settings of 100' Start Scan Radius hlcre,~htg at 50' per 11300 'MD for a new-drill well scan, thus DEAP's defaults would, be equal to 675,25' atthe Start Scan h~pection Zone as stated above. These numbers are used to produce a final scan radius of 1453,488' which ks 701,494' larger bart DEAFs default value of 751,994' Scan Parameters Comments: lit I · ' ' I I I I I IL ! , Il · I m I · I · At this enlarged radius the following wells were detected during the scan (B~ed on etosest '^uo,~ble Deviation from Plan'): Note: this list may not include all the wells detected, only thoso of which axe o1' concern or may effect Toleral~ce Line drawing! Colnpndson Sublect Well ~ R,latlve Allowable Well: Deoth $~eratigl~ Azimuth De~vla flon ('= g~l.ht~ Suer) ('~ Well P~s MD} ~ Pol.;l ~ D~} [Avoror 1-~3~-23 11598.38 '~ 10,27 ' 204,80 * -257,03 ' _ _. 1-33~-23 11750,43 ~D t~,73 ' 179,10 ~ -129,20 ' , 1-33~-23 11834.21 ~D 256.98 ' 170.10" 65.35 ' 1-65~-25 11530.36'MD 993,19 ' ~ 710.07 ' No 1-65~-25PH t 1517.96'MD 1256.57 ' 160,00 ~ 1000.54 ' S~uMn Re~fl~red? ($e~eration nol~ No. Original Wellbore No, Original Wellboro No. Original Wellbore as Te.*ted Shut-In Shut-in Shut-In Flowing Flowing Tolerance Plot required: NO Close Approach Comments: Close Appr99fih Scan Pe~s~rmeF1/by:' . . Approved by: Date: Date: ?,g .. Date: i Shared Services Approval: il Illl I I I __ -- l ii · l, Date: Im F! I I_L_ I [M CS S ~: I~! g I I-- I:::: S WELL LOG TRANSMITTAL To: State of Alaska March 19, 1998 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Drive. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - 1-33A / PB 1, AK-MW-80313 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22577-70 2 3 ,999 Gas .~ns. Commission 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company · WELL PERMIT CHECKLIST COMPANY__]~ FIELD & POOl. _._ ~, ~ ~)_.[' .(._~. ~ ....... INI1 CLASS ADMINISTRATION WEI.I. NAME J- 3 -2cL PROGRAM:exp[]dev,,~redrll~serv[]wellboresegl ann disposal par;, re(l,, / - ~,~_~_,~ (___ GEOL AREA. ,.: C/ 1,~, _. tlNIf# / O z.,,,,' ...~-C~ ON/OFF SIIORF 0 L/"~. I't'[[~il fee attached I e~ s(, ~LJnlbef apll~ol)[lale LJrUque well name and nLJrnbe[ Well Iocaled ir'~ a defined pool ...... Well Iocaled proper dislance bom drilling unil boundary VVell located proper distance from other wells . St]fficient acreage available in drilling unit If deviated is wellbore plat included !) Operator only affected parly. I() (~pelnlol tlas al)l)~op~lale bolld itl lorce I 1 I'ellilit can be issued witl~oul conservation ordel 12 t'erl~lil can be issued wilhoul administ~alive apploval 1:~ (:;~ l~(:Irr~ll t)e approved before 15-day wail REMARKS CYaN N 14 (.~(,I/(JLICIOI Str~ng provided 15 St~rlace casing protects all knowi~ USDWs lf; (;MI vol adeqtiale Io ci~(;tHale on conduclol & SUll CS~I 17 CMI vol adequate Io lie-in long siring Io stHf csg 18 (;MI will cove~ all known produclive horizons... 19 Casing designs adequate for C. ~. B & permafrost 20 Adeqt~ale tankage or rese~e pit ........... 2 I I1 a ~e-d~ill. has a 10-403 for abandonmenl been approved. 22 Ade:itiate wellbo~e sepa~alion proposed . . 23 If dWerler required, does il meel regulalions 24 [)lilhng fhJi(t program schenlalic g eqt~ip hst a(leqtiale 25 [3()f'E r,. dc.) llley rneel regulatio~l 20 BC..)f'E pless rating appropriate' test Io ~~ pslg .............................. 27 Choke manifold complies w/APl RP-53 (May 84) . 28 Work will occur without operation shutdown. ,. 2fl I~; luese~me of II:.S gas probable. 30 I"ernnl can be issue(t w/o hydrogen sulfide measures 31 [)ala pfesenled on polenlial overpresstne zones 32 Se~slmc analysis (~ sh~ 33 Seat~ed co~y (~fFsho~e) . . APPR DA'Ir: , :~~e/phorm for we.eklyprogress reports _~.. ~2 ~;' I;~/~ ¢)~ l'e~plorglo~ only] Y N Y N GEOl C)GY ENGINEERING COMMISSION DWJ__.~ RNC "-'" co gBTL Comments/Instructions' 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 Fri Mar 19 10:43:24 1999 Reel Header Service name ............. LISTPE Date ..................... 99/03/19 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 ..................... 99/03/19 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 ENDICOTT MPI Iv~'D/MAD nOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERJtTOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 20 AK-MW-80313 K. ALLEN E. VAUGHN 1-33A/N-24 500292257701 BP EXPLORATION (ALA~) , INC. SPERRY-SUN DRILLING SERVICES 19-MJkR-99 MWD RUN 21- AK-MW-80313 K. ALLEN E. VAUGHN 36 12N 16E 3217 2114 RECEIVED 2 1999 .00 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 56.00 14.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.625 11790.0 3.958 11198.0 12164.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 9 THROUGH 26 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GIEGER-MUELLER TUBE TYPE DETECTORS (SOLAR 175). MWD RUNS 10,11,12 AND 20 INCLUDED PRESSURE WHILE DRILLING (PWD) GAUGES. 3. MWD RUN 9-19, AND 23-26 MADE NO FOOTAGE AND ARE NOT PRESENTED. 4. DEPTH SHIFTING OF MWD DATA IS WAIVED AS PER THE E-MAIL FROM D. DOUGLAS FOR E. GOEBEL ON 3/16/99. 5. MWD RUNS 20 AND 21 REPRESENT WELL 1-33A/N-24 WITH API#: 50-029-22577-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12165'MD, 9962'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/19 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 11766.5 12135.5 ROP 11795.5 12164.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH EQUIVALENT UNSHIFTED DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 20 11796.0 11864.0 21 11864.0 12165.0 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 11766.5 12164.5 11965.5 797 11766.5 GR 4.95 175.03 18.7548 739 11766.5 ROP 0.46 54.62 19.2811 739 11795.5 Last Reading 12164.5 12135.5 12164.5 First Reading For Entire File .......... 11766.5 Last Reading For Entire File ........... 12164.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File ~eader Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/19 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: 20 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11766 . 5 11835 . 5 ROP 11795 . 5 11864 . 0 $ LOG HEADER DATA DATE LOGGED: 18-AUG- 98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: GM 1.22 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 11864.0 TOP LOG INTERVAL (FT) : 11796.0 BOTTOM LOG INTERVAL (FT) : 11864.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 36.2 MAXIMUM ANGLE: 50.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 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: INSITE 3.2 / ISC 5.07 TM3.29/.41 DM3.07/.13 TOOL NUMBER SOLAR GM 82764 3.750 3.8 QUIK DRIL N 10.00 52.0 9.1 4.4 .000 .000 .000 .000 76.1 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 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 20 API 4 1 68 4 2 ROP MWD 20 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11766.5 11864 11815.2 196 11766.5 GR 7.98 175.03 35.0043 139 11766.5 ROP 0.46 42.94 9.48123 138 11795.5 Last Reading 11864 11835.5 11864 First Reading For Entire File .......... 11766.5 Last Reading For Entire File ........... 11864 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/19 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 ....... 99/03/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 21 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11836.0 ROP 11864.5 $ 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 12135.5 12164.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 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 TEMPER3kTURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 20-AUG-98 INSITE 3.2 / ISC 5.07 TM3.29/.41 DM3.07/. 13 MEMORY 12165.0 11864.0 12165.0 54.0 85.4 TOOL NUMBER SOLAR GM 74165 3.750 3.8 QUIK DRIL N 10.00 52.0 9.2 5.2 .000 .000 .000 .000 76.4 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 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 21 API 4 1 68 4 2 ROP MWD 21 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11836 12164.5 12000.2 658 11836 GR 4.95 97.06 14.9903 600 11836 ROP 1.09 54.62 21.5314 601 11864.5 Last Reading 12164.5 12135.5 12164.5 First Reading For Entire File .......... 11836 Last Reading For Entire File ........... 12164.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape ~railer Service name ............. LISTPE Date ..................... 99/03/19 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 ..................... 99/03/19 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 Thu Mar 18 14:45:00 1999 Reel Header Service name ............. LISTPE Date ..................... 99/03/18 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 ..................... 99/03/18 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 ENDICOTT MPI 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: FWd: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 5 AK-MW- 80313 E. CRIBBS E. VAUGHN 1-33A/PB1 500292257770 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 18-MAR-99 MWD RUN 8 AK-MW- 80313 E. CRIBBS E. VAUGHN 36 12N 16E 3217 2114 RECEIVED I~,~.AR 2 5 1999 Al~im ~ & Gas Oons. Commi~ion .00 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 56.00 14.50 OPEN HOLE CAS ING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7. 625 11781.0 3 . 750 12282 . 0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 MADE NO FOOTAGE AND IS NOT PRESENTED. 3. MWD RUNS 2 THROUGH 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE TYPE DETECTORS (SOLAR 175). ALL RUNS ARE FOR CLEANOUT AND MILLING AND ARE NOT PRESENTED. 4. MWD RUNS 5-8 ARE DIRECTIONAL WITH DGR (SOLAR 175), AND PRESSURE WHILE DRILLING (PWD). RUNS 6 AND 7 MADE NO FOOTAGE AND ARE NOT PRESENTED. 5. MWD RUN 8 DATA IS REALTIME PULSED DATA; THE TOOL WAS LOST IN HOLE. 6. MWD RUN 9 WAS A FISHING RUN AND IS NOT PRESENTED. 7. DEPTH SHIFTING OF MWD DATA IS WAIVED AS PER THE E MAIL FROM D. DOUGLAS FOR E. GOEBEL OF BP EXPLORATION (ALASKA), INC. ON 3/16/99. THIS DATA IS CONSID- ERED PDC. 8. MWD RUNS 5 AND 8 REPRESENT WELL 1-33A/PB1 WITH API#: 50-029-22577-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12282'MD, 10002'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/18 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 11795.0 ROP 11815.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: 12252.0 12281.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 5 11815.0 12132.0 8 12132.0 12282.0 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 11795 12281 12038 973 11795 GR 6.76 168.39 63.725 915 11795 ROP 0.44 1248.08 20.4739 932 11815.5 Last Reading 12281 12252 12281 First Reading For Entire File .......... 11795 Last Reading For Entire File ........... 12281 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Da~e of Generation ....... 99/03/18 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 ....... 99/03/18 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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11795.0 12104.0 ROP 11815.5 12132.0 $ LOG HEADER DATA DATE LOGGED: 02-AUG-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: GM 1.22 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 12132.0 TOP LOG INTERVAL (FT) : 11815.0 BOTTOM LOG INTERVAL (FT) : 12132.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 46.0 MAXIMUM ANGLE: 81.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 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: INSITE 3.2 / ISC 5.07 TM3.29/.41 DM3.07/.13 TOOL NUMBER SOLAR GM 82764 3.800 3.8 QUICK-DRIL 10.00 47.0 9.0 MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTP~ATE AT MT: MUD CA/rE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STAArDOFF (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 4.0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 API 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 71.1 First Name Min Max Mean Nsam Reading DEPT 11795 12132 11963.5 675 11795 GR 6.76 168.02 54.0093 619 11795 ROP 1.65 1248.08 24.7279 634 11815.5 Last Reading 12132 12104 12132 First Reading For Entire File .......... 11795 Last Reading For Entire File ........... 12132 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/18 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 ....... 99/03/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12104 . 5 12252 . 0 ROP 12133 . 5 12281.0 $ LOG HEADER DATA DATE LOGGED: 05 -AUG- 98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: GM 1.22 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 12282.0 TOP LOG INTERVAL (FT) : 12132.0 BOTTOM LOG INTERVAL (FT) : 12282.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 85.3 MAXIMUM ANGLE: 91.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 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: INSITE 3.2 / ISC 5.07 TM3.29/.41 DM3.07/.13 TOOL NUMBER SOLAR GM 78655 3.800 3.8 QUICK-DRIL 10.00 49.0 8.9 MIlD 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) : REMILRKS: $ 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 3.8 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 API 4 1 68 4 2 ROP MWD 8 FT/H 4 1 68 8 3 73.9 First Name Min Max Mean Nsam Reading DEPT 12104.5 12281 12192.8 354 12104.5 GR 17.11 168.39 84.0424 296 12104.5 ROP 0.44 36.22 11.4723 296 12133.5 Last Reading 12281 12252 12281 First Reading For Entire File .......... 12104.5 Last Reading For Entire File ........... 12281 File Trailer Service name ............. 'STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Da~e of Generation ....... 99/03/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/03/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 99/03/18 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
