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Home My WebLink About197-004XHVZE 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. /~.. ~L//File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: [] GraYScale, halftones, pictures, graphs, charts - Pages: [] Poor Quality Original- Pages: [] Other - Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type 'OVERSIZED .Logs of various kinds Other COMMENT~: D Scanned b~_ TO RE-SCAN Notes: Miktred-D'amtha Nathan Lowell THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03, 2001, M p I_ A T E E IA L U W N u T H IS M ARK ER C:LORI~'IFILM.DOC PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: Date: 01/21/99 RUN RECvD 97-004 DGR/EWR4-TVD 97-004 DGR/CNP/SLD-TVD 97-004 DGR/EWR4-MD 97-004 DGR/CNP/SLD-MD 97-004 7679 ~i77-7290 ~4979-7290 ~/177-12672 ~/8906-12672 ~SPERRY GRC/CNP/M~T/~.WR4 FIND~L 05/14/97 FINAL 05/14/97 FrN~L 0S/z4/9? FINAL 05/14/97 1-4 05/14/97 10-407 DAILY WELL OPS Are dry ditch samples required? Was the well cored? yes no Are well tests required? yes Well is in compliance Initial COMMENTS a"eOM~,~.~ION ~A~, ~/ )/:;'?/ ~,;¢/ 2/?/ no yes no And received? yes Analysis & description received? no Received? yes no yes no Transmittal State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 of Final Prints. Please sign and return copy to: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 17-Feb-98 Well Name ~---~- ocli MPK-43 A Services : Bluelines R/F Sepia Film Injection Profile 1 I ~,~-Ood MPK-18 A Injection Profile 1 I 0 Received by: ~ / Date Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. ri I:t I I__1__ I I~1 G S E I::! ~/I l-- I::: S WELL LOG TRANSM1TFAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - May 14, 1997 MPK-18 AK-MM-70020 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Fun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, gG, Anchorage, AK 99518 1 LDWG formatted LIS Tape with verification listing. APl#: 50-029-22733-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company D I::! I I--I__ I ~ CS ~ EEI:::! ~/I r- I:::: S WELL LOG TRANSMITTAL To: State of Alaska May 14, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPK-18 & MPK-18A, AK-MM-70020 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention oE Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way,/tG, Anchorage, AK 99518 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22733-00 2"x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22733-00 2"x 5" MD Neutron and Density Logs: 50-029-22733-00 2" x 5" TVD Neutron and Density Logs: 50-029-22733-00 MPK-lSA: q~'"']' ('~% ( 2"x 5" MD Resistivity and CJamma Ray Logs: 50-029-22733-01 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22733-01 2"x 5" MD Neutron and Density Logs: 50-029-22733-01 2" x 5" TVD Neutron and Density Logs: 50-029-22733-01 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia ~~& 1 Blueline 1 Rev. Folded Sepia _. .... · _,-' 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc, Company PLUGGING.~& LOCATION CLEA~R~-~=~CE REPORT State of Alaska · ALASKA 0IL & GAS CONSERVATION COMMISSION Review the well file, and' c~ent on plugging, well head status, _a~nd io~ca~ion clearance - provide loc. clear, code._ Well head c=t off: ~arker ~ost or plate: Locanion Clearance: NO' q7 Code · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Plug~-~liB'a~k f~¥Si¢etrc_ck WELL COMPLETION OR RECOMPLETION REPORT AND LOG F;/:''~ ,~. 1 Status of Well Classification of Service Well I--t Oil [] Gas [] Suspended [] Abandoned I--] Service ' ' 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-04 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22733 4. Location of well at surface i~¢:;;~&~ 9. Unit or Lease Name 3689' NSL, 1998' WEL, SEC. 3, T12N, Rl1 E, UM t~ Milne Point Unit At top of productive interval 10. Well Number N/A ~ MPK-18 At total depth ~11. Field and Pool 4589' NSL, 1276' EWL, SEC. 1, T12N, R11E, UM Milne Point Unit/Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 64'I ADL 375132 12. Date Spudded I 13. Date I.D. Reached I 14. Date Comp., Susp., or Aband.ll 5. Water depth, if offshore I16. No. of Completions 1/26/97 2/7/97 2/7/97 N/A MSLI One I17' T°tal Depth (MD+TVD)12672 7290 FT]I18' Plug Back Depth (MD+-I-VD)I19' Directi°nal SurveY 120' Depth where SSSV set 121' Thickness °f Permafr°st8925 4985 FTI [] Yes I--] No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, CDR/CDN, Gyro 23. CASING, L.... ^.. 0 D 1 F'_l k l ^ I CASING SETFING DEPTH HOLE I \ I ~ I I ~l t~ SIZE WT. PER FT. GRADE TOP DO'FI-OM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1 # H-40 38' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 36' 8884' 12-1/4" 2105 sx PF'E', 523 sxClass'G', 161 sxPF 'C' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A MD TVD MD TVD 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9533'-12672' P&A, 500 sx Class 'G' 8545'-9183' Kickoff plug, 300 sx Class 'G' 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-DEL GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL iGAs-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 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. BHRZ 12146' 6838' TKUP 12304' 6973' KC1 12469' 7115' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and porrect to the b~t of my knowledge Signed ChipAIvord K (--'~\~- ~'-~'~~'~ U\~'~' Title En~lineerin9 Supervisor Date OIl MPK-18 97-04 397-023 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. J NSTRUCTIONS 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. ITEI~/I 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 2?.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Performance Enquiry Report Operator BP Exploration Date 21:55, 12 Dec 97 Page 1 The analysis is from - 13:00, 04 Feb 97 - to - 13:00, 04 Feb 97 Programs in Result Table: MPK-18/18A Drill and Complete Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) MPK-18 Event 13:00, 04 Feb 97 13:00, 04 Feb 97 0 hr 0 min Obtained leak off 15.0 Hole Size MDR 8-1/2 Facility Date/Time 24 Jan 97 25 Jan 97 26 Jan 97 27 Jan 97 28 Jan 97 29 Jan 97 30 Jan 97 31 Jan 97 M Pt K Pad Progress Report Well MPK- 18~ Rig /'46.~c~r~ ~]~' Page Date Duration Activity 10:01-13:30 13:30-04:30 04:30-06:00 06:00-13:30 13:30-18:00 18:00-18:30 18:30-01:30 01:30-05:30 05:30-06:00 06:00-06:30 06:30-07:00 07:00-11:00 11:00-12:00 12:00-18:00 18:00-18:30 18:30-19:00 19:00-22:00 22:00-02:00 02:00-03:00 03:00-04:00 04:00-04:30 04:30-06:00 06:00-07:00 07:00-09:00 09:00-18:00 18:00-19:00 19:00-21:30 21:30-22:30 22:30-23:00 23:00-00:00 00:00-01:00 01:00-02:30 02:30-06:00 06:00-18:00 18:00-20:00 20:00-23:30 23:30-00:30 00:30-03:30 03:30-06:00 06:00-18:00 18:00-19:30 19:30-20:00 20:00-20:30 20:30-06:00 06:00-14:00 14:00-14:30 14:30-16:00 16:00-16:30 16:30-17:30 17:30-06:00 06:00-06:15 06:15-12:30 12:30-14:30 14:30-18:30 3-1/4 hr 15hr 1-1/2 hr 7-1/2 hr 4-1/2 hr 1/2 hr 7hr 4hr 1/2 hr 1/2 hr 1/2 hr 4 hr 1 hr 6hr 1/2 hr 1/2 hr 3hr 4hr lhr 1 hr 1/2 hr 1-1/2 hr lhr 2hr 9hr 1 hr 2-1/2 hr lhr 1/2 hr 1 hr lhr 1-1/2 hr 3-1/2 hr 12hr 2hr 3-1/2 hr lhr 3 hr 2-1/2 hr 12hr 1-1/2 hr 1/2 hr 1/2 hr 9-1/2 hr 8 hr 1/2 hr 1-1/2 hr 1/2 hr 1 hr 12-1/2 hr 1/4 hr 6-1/4 hr 2hr 4 hr Rigged down Drillfloor / Derrick Rig moved 100.00 % Rigged up Lines / Cables Rigged up Lines / Cables Rigged up Divertor Held safety meeting Rigged up Lines / Cables Made up BHA no. 1 Tested Divertor Held safety meeting Tested Flowline Drilled to 355.0 ft Made up BHA no. 1 Drilled to 1267.0 ft Held safety meeting Drilled to 1455.0 ft Repaired Top drive Drilled to 1926.0 ft Circulated at 1926.0 ft Pulled out of hole to 215.0 ft R.I.H. to 1926.0 ft Drilled to 2114.0 ft Drilled to 2357.0 ft Circulated at 2357.0 ft Drilled to 2957.0 ft Circulated at 2957.0 ft Drilled to 3130.0 ft Circulated at 3130.0 ft Drilled to 3145.0 ft Circulated at 3145.0 ft Pulled out of hole to 1082.0 ft R.I.H. to 3145.0 ft Drilled to 3448.0 ft Drilled to 4659.0 ft Circulated at 4659.0 ft Pulled out of hole to 215.0 ft Pulled BHA R.I.H. to 4659.0 ft Drilled to 4854.0 ft Drilled to 5794.0 ft Circulated at 5794.0 ft Pulled out of hole to 4570.0 ft R.I.H. to 5794.0 ft Drilled to 6542.0 ft Drilled to 7106.0 ft Circulated at 7106.0 ft Pulled out of hole to 3821.0 ft Serviced Top drive R.I.H. to 7014.0 ft Drilled to 7948.0 ft Held safety meeting Drilled to 8153.0 ft Circulated at 8153.0 ft Pulled out of hole to 215.0 ft 1 12 December 97 Facility Date/Time 01 Feb 97 02 Feb 97 03 Feb 97 04 Feb 97 05 Feb 97 M Pt K Pad Progress Report Well MPK- 1 Rig/~c~.~c,'~ Duration Activity 18:30-20:00 20:00-22:00 22:00-00:00 00:00-03:30 03:30-06:00 06:00-06:15 06:15-13:00 13:00-14:00 14:00-14:30 14:30-15:30 15:30-18:00 18:00-18:15 18:15-22:30 22:30-01:00 01:00-02:00 02:00-06:00 06:00-06:15 06:15-13:00 13:00-16:30 16:30-20:30 20:30-00:00 00:00-02:00 02:00-04:00 04:00-06:00 06:00-06:15 06:15-07:00 07:00-08:30 08:30-11:00 11:00-13:00 13:00-18:00 18:00-18:15 18:15-19:00 19:00-20:30 20:30-00:30 00:30-01:30 01:30-02:30 02:30-05:30 05:30-06:00 06:00-06:15 06:15-07:00 07:00-09:00 09:00-09:30 09:30-11:00 11:00-12:00 12:00-13:00 13:00-18:30 18:30-19:00 19:00-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-14:30 14:30-15:00 15:00-16:00 1-1/2 hr 2 hr 2hr 3-1/2 hr 2-1/2 hr 1/4 hr 6-3/4 hr lhr 1/2 hr lhr 2-1/2 hr 1/4 hr 4-1/4 hr 2-1/2 hr lhr 4hr 1/4 hr 6-3/4 hr 3-1/2 hr 4hr 3-1/2 hr 2 hr 2 hr 2hr 1/4hr 3/4 hr 1-1/2 hr 2-1/2 hr 2hr 5hr 1/4 hr 3/4 hr 1-1/2 hr 4hr 1 hr 1 hr 3 hr 1/2 hr 1/4 hr 3/4 hr 2 hr 1/2 hr 1-1/2 hr lhr 1 hr 5-1/2 hr 1/2 hr llhr 1/2 hr 1/2 hr 1/2 hr 7 hr 1/2 hr 1 hr Pulled BHA Made up BHA no. 3 Serviced Block line R.I.H. to 8153.0 ft Drilled to 8325.0 ft Held safety meeting Drilled to 8905.0 ft Circulated at 8905.0 ft Pulled out of hole to 7045.0 ft R.I.H. to 8905.0 ft Circulated at 8905.0 ft Held safety meeting Pulled out of hole to 216.0 ft Pulled BHA Rigged up Casing handling equipment Ran Casing to 2900.0 ft (9-5/8in OD) Held safety meeting Ran Casing to 8883.0 ft (9-5/8in OD) Circulated at 8883.0 ft Mixed and pumped slurry - 507.000 bbl Circulated at 2098.0 ft Mixed and pumped slurry - 441.000 bbl Rigged up Drillfloor / Derrick Removed Divertor Held safety meeting Rigged down Divertor Installed Casing spool Rigged up BOP stack Rigged up Drillfloor / Derrick Tested BOP stack Held safety meeting Serviced Bore protector Serviced Top drive Made up BHA no. 4 R.I.H. to 2080.0 ft Drilled installed equipment - DV collar R.I.H. to 7780.0 ft Tested Casing Held safety meeting Tested Casing Held drill (Stripping) R.I.H. to 8798.0 ft Drilled installed equipment - Landing collar Circulated at 8925.0 ft Performed formation integrity test Took Gyro multi-shot w/line survey Rigged down Wireline units Drilled to 10043.0 ft Held safety meeting Pulled out of hole to 8883.0 ft R.I.H. to 10043.0 ft Drilled to 10514.0 ft Cleared Flowline Pulled out of hole to 8883.0 ft Page Date 2 12 December 97 Facility M Pt K Pad Progress Report Well MPK- 18~. Rig Page 3 Date 12 December 97 Date/Time 06 Feb 97 07 Feb 97 08 Feb 97 09 Feb 97 Duration Activity 16:00-20:30 4-1/2 hr Repaired High pressure lines 20:30-21:00 1/2 hr R.I.H. to 10514.0 ft 21:00-06:00 9 hr Drilled to 11170.0 ft 06:00-06:30 1/2 hr Held safety meeting 06:30-15:00 8-1/2 hr' Drilled to 12013.0 ft 15:00-16:00 1 hr Circulated at 12013.0 ft 16:00-17:00 1 hr Pulled out of hole to 10507.0 ft 17:00-17:30 1/2 hr R.I.H. to 12013.0 ft 17:30-03:00 9-1/2 hr Drilled to 12672.0 ft 03:00-05:30 2-1/2 hr Circulated at 12672.0 ft 05:30-06:00 1/2 hr Pulled out of hole to 12000.0 ft 06:00-06:30 1/2 hr Held safety meeting 06:30-11:00 4-1/2 hr Pulled out of hole to 250.0 ft 11:00-13:00 2 hr Downloaded MWD tool 13:00-14:00 1 hr Serviced Top drive 14:00-18:00 4 hr R.I.H. to 12672.0 ft 18:00-18:30 1/2 hr Held safety meeting 18:30-19:00 1/2 hr Circulated at 12672.0 ft 19:00-20:00 1 hr Mixed and pumped slurry - 102.000 bbl 20:00-21:30 1-1/2 hr Pulled out of hole to 10798.0 ft 21:30-22:30 1 hr Circulated at 10798.0 ft 22:30-23:30 1 hr Pulled out of hole to 9533.0 ft 23:30-01:30 2 hr Pulled out of hole to 5985.0 ft 01:30-02:30 1 hr Circulated at 5985.0 ft 02:30-02:45 1/4 hr R.I.H. to 7425.0 ft 02:45-03:30 3/4 hr Circulated at 7945.0 ft 03:30-04:00 1/2 hr R.I.H. to 8883.0 ft 04:00-04:30 1/2 hr Circulated at 8883.0 ft 04:30-05:00 1/2 hr R.I.H. to 9533.0 ft 05:00-06:00 1 hr Circulated at 9533.0 ft 06:00-06:30 1/2 hr Held safety meeting 06:30-07:00 1/2 hr Circulated at 9533.0 ft 07:00-07:30 1/2 hr Pulled out of hole to 9183.0 ft 07:30-08:00 1/2 hr Mixed and pumped slurry - 56.000 bbl 08:00-09:00 1 hr Pulled out of hole to 7350.0 ft 09:00-10:00 1 hr Circulated at 7350.0 ft 10:00-13:30 3-1/2 hr Pulled out of hole to 0.0 ft 13:30-14:30 1 hr Serviced Top drive 14:30-16:30 2 hr Repaired Draw works 16:30-18:00 1-1/2 hr Serviced Block line 18:00-18:30 1/2 hr Held safety meeting 18:30-22:30 4 hr Tested BOP stack 22:30-23:00 1/2 hr Installed Wear bushing 23:00-00:30 1-1/2 hr Made up BHA no. 1 00:30-06:00 5-1/2 hr R.I.H. to 8000.0 ft 06:00-06:30 1/2 hr Held safety meeting 06:30-07:30 1 hr .... . .......... Washed to 8545.0 ft ... SPE PAGE 1 BP EXPLORATION MILNE PT / MPK-18 500292273300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/26/97 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN 8700 . 00 4921.19 4857.54 74 3 8721.49 4927.12 4863.47 73 55 8836.43 4959.40 4895.75 73 26 8947 . 31 4991 . 29 4927 . 64 73 7 9040.62 5018.68 4955.03 72 44 9135.94 5047.64 4983.99 71 54 9231.09 5077.79 5014.14 71 9 9325.69 5108.70 5045.05 70 42 9420.32 5140.41 5076.76 70 7 9513.55 5172.42 5108.77 69 42 9606.05 5204.83 5141.18 69 9697.87 5237.56 5173.91 68 9792.88 5272.00 5208.35 68 9886.28 5307.50 5243.85 66 9981.91 5346.41 5282.76 65 10073.87 5386.26 5322.61 10164.02 5427.90 5364.25 10257.96 5474.31 5410.66 10352.73 5524.28 5460.63 10446.18 5576.21 5512.56 10540.78 5630.29 5566.64 10634.00 5685.21 5621.56 10731.13 5744.81 5681.16 10827.20 5805.85 5742.20 10920.51 5867.32 5803.67 11015.47 5932.26 5868.61 11109.11 5998.44 5934.79 11202.27 6066.45 6002.80 11295.86 6137.05 6073.40 11389.98 6210.08 6146.43 f-SUN DRILLING SERVICES ANCHORAGE ALASKA DATE OF SURVEY: 020897 MWD SURVEY JOB NUMBER: AK-MM-70020 KELLY BUSHING ELEV. = 63.65 OPERATOR: BP EXPLORATION FT. 11483.82 6284.85 6221.20 11577.54 6361.18 6297.53 11671.35 6438.65 6375.00 11765.91 6517.34 6453.69 11859.85 6596.09 6532.44 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. N 85.27 E .00 474.53N 5592.56E N 84.37 E 4.06 476.39N 5613.13E N 83.16 E 1.09 488.37N 5722.79E N 85.37 E 1.93 498.98N 5828.43E N 85.87 E .65 505.80N 5917.37E 5611.66 5632.31 5742.62 5848.79 5937.96 N 81.09 E 4.86 516.10N 6007.57E N 82.91 E 1.98 528.66N 6096.92E N 81.84 E 1.17 540.52N 6185.53E N 81.61 E .65 553.35N 6273.76E N 81.42 E .49 566.27N 6360.37E 6028.74 6118.91 6208.28 6297.36 6384.83 16 57 32 46 12 N 80.44 E 1.10 579.93N 6445.92E N 79.79 E .74 594.65N 6530.43E N 79.60 E .48 610.49N 6617.55E N 78.22 E 2.34 627.10N 6702.31E N 78.33 E 1.63 644.85N 6787.83E 6471.34 6556.92 6645.21 6731.23 6818.13 63 25 61 32 59 14 57 7 55 20 N 78.23 E 1.94 661.68N 6868.97E N 80.68 E 3.19 676.33N 6947.56E N 79.37 E 2.74 690.46N 7028.00E N 81.34 E 2.85 703.97N 7107.37E N 82.09 E 2.01 715.17N 7184.24E 6900.57 6980.26 7061.72 7142.07 7219.68 54 54 52 52 51 25 49 40 47 54 N 81.05 E 1.01 726.54N 7261.01E N 82.87 E 2.69 737.09N 7335.56E N 82.41 E 1.55 746.91N 7411.62E N 82.24 E 1.83 756.82N 7485.13E N 82.78 E 1.94 765.97N 7554.71E 7297.22 7372.46 7449.13 7523.26 7593.42 45 44 41 40 38 46 16 54 9 2 N 83.67 E 2.34 774.15N 7623.49E N 81.75 E 2.17 782.54N 7689.18E N 82.40 E 2.58 791.32N 7752.20E N 83.66 E 2.08 798.79N 7813.17E N 84.17 E 2.26 805.08N 7872.19E 7662.68 7728.88 7792.47 7853.89 7913.24 36 16 34 37 34 1 33 19 32 44 N 84.06 E 1.89 810.89N 7928.57E N 83.16 E 1.85 816.93N 7982.59E N 82.44 E .77 823.56N 8035.08E N 81.28 E 1.01 830.98N 8086.99E N 82.32 E .87 838.29N 8137.67E 7969.92 8024.28 8077.17 8129.56 8180.73 SPE SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE PT / MPK-18 500292273300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/26/97 DATE OF SURVEY: 020897 MWD SURVEY JOB NUMBER: AK-MM-70020 KELLY BUSHING ELEV. = 63.65 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST 11953.05 6674.61 6610.96 32 26 N 81.78 E .45 845.23N 8187.39E 12046.68 6753.76 6690.11 32 8 N 81.39 E .39 852.55N 8236.87E 12139.97 6832.96 6769.31 31 39 N 81.41 E .52 859.92N 8285.61E 12235.52 6914.56 6850.91 31 2 N 80.96 E .68 867.54N 8334.74E 12329.79 6995.42 6931.77 30 48 N 81.33 E .33 875.00N 8382.61E VERT. SECT. 8230.90 8280.87 8330.11 8379.77 8428.16 12424.08 7076.46 7012.81 30 40 N 81.66 E .23 882.13N 8430.29E 12517.06 7156.52 7092.87 30 27 N 81.71 E .24 888.97N 8477.08E 12611.75 7238.29 7174.64 30 6 N 81.60 E .38 895.90N 8524.32E 12672.00 7290.41 7226.76 30 6 N 81.60 E .00 900.31N 8554.21E 8476.31 8523.56 8571.26 8601.45 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 8601.46 FEET AT NORTH 83 DEG. 59 MIN. EAST AT MD = 12672 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 84.07 DEG. TIE-IN SURVEY AT 8,700.00' MD PROJECTED SURVEY AT 12,672.00' MD SP[ PAGE 3 IY-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION MILNE PT / MPK-18 500292273300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/26/97 DATE OF SURVEY: 020897 JOB NUMBER: AK-MM-70020 KELLY BUSHING ELEV. = 63.65 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTAiqGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8700.00 4921.19 4857.54 474.53 N 5592.56 E 9700.00 5238.33 5174.68 595.01 N 6532.38 E 10700.00 5725.40 5661.75 743.70 N 7387.50 E 11700.00 6462.39 6398.74 825.67 N 8050.97 E 12672.00 7290.41 7226.76 900.31 N 8554.21 E 3778.81 4461.67 682.86 4974.60 512.93 5237.61 263.00 5381.59 143.98 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPt Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE PT / MPK-18 500292273300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/26/97 DATE OF SURVEY: 020897 JOB NUMBER: AK-MM-70020 KELLY BUSHING ELEV. = 63.65 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8700.00 4921.19 4857.54 474.53 N 5592.56 E 3778.81 8851.36 4963.65 4900.00 490.08 N 5737.00 E 3887.71 108.90 9187.23 5063.65 5000.00 523.47 N 6055.73 E 4123.58 235.87 9488.26 5163.65 5100.00 562.73 N 6336.91 E 4324.61 201.03 9770.06 5263.65 5200.00 606.66 N 6596.66 E 4506.41 181.80 10022.91 5363.65 5300.00 652.38 N 6824.26 E 4659.26 152.85 10236.95 5463.65 5400.00 687.18 N 7010.19 E 4773.30 114.04 10424.09 5563.65 5500.00 712.67 N 7166.24 E 4860.44 87.15 10598.24 5663.65 5600.00 733.53 N 7307.26 E 4934.59 74.14 10761.34 5763.65 5700.00 750.03 N 7435.03 E 4997.69 63.11 10915.04 5863.65 5800.00 765.46 N 7550.69 E 5051.39 53.70 11060.47 5963.65 5900.00 777.71 N 7655.54 E 5096.82 45.43 11198.50 6063.65 6000.00 790.99 N 7749.71 E 5134.85 38.03 11330.66 6163.65 6100.00 801.26 N 7835.48 E 5167.01 32.16 11457.52 6263.65 6200.00 809.28 N 7913.09 E 5193.87 26.86 11580.54 6363.65 6300.00 817.14 N 7984.28 E 5216.89 23.02 11701.52 6463.65 6400.00 825.78 N 8051.81 E 5237.87 20.98 11821.29 6563.65 6500.00 835.50 N 8117.00 E 5257.64 19.77 11940.06 6663.65 6600.00 844.23 N 8180.49 E 5276.41 18.77 12058.35 6763.65 6700.00 853.48 N 8243.01 E 5294.70 18.30 12176.02 6863.65 6800.00 862.75 N 8304.32 E 5312.37 17.67 12292.79 6963.65 6900.00 872.14 N 8363.88 E 5329.14 16.77 12409.18 7063.65 7000.00 881.03 N 8422.77 E 5345.53 16.39 12525.33 7163.65 7100.00 889.57 N 8481.23 E 5361.69 16.15 12641.06 7263.65 7200.00 898.04 N 8538.86 E 5377.41 15.73 12672.00 7290.41 7226.76 900.31 N 8554.21 E 5381.59 4.17 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS K PAD, WELL NO:MPK-18 MILNE POINT FIELD, ALASKA Gyro Multishot Survey Inside Drillpipe Survey date: 4- FEB, 1997 Job number :A0197GCE381 CONTENTS JOB NUMBER :A0197GCE381 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION , SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER- A0197GC.,E381 Tool 758 was run in WELL# MPK-18 on SCHLUMBERGER 15/32" Wireline inside drillpipe, was run without problems. SURVEY CERTIFICATION SHEET JOB NUMBER' A0197GCE381 The data for this survey and the calculations for this survey were obtained and perforrr according to standards and procedures as set forth by Gyrodata Limited, true and correct to my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the star procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the odginal data obtai~ wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: A0197GCE381 CLIENT: B.P. EXPLORATION RIG: NABORS 27E LOCATION: K PAD, FIELD, ALASKA WELL: MPK-18 LATITUDE: 70.505 N LONGITUDE: 149.3 W SURVEY DATE: 04, FEB 1997 SURVEY TYPE : GYRO MULTISHOT IN 5" DRILLPIPE DEPTH REFERENCE: 62.4' MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 8700' SURVEY TIED ONTO: NA SURVEYINTERVAL: 0-8700' APl NUMBER: 050-029-22733 TARGET DIRECTION: 84.07 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER: A0197GCE381 ' TOOL NUMBER: 758 MAXIMUM GYRO TEMPERATURE: 74.8C MAXIMUM AMBIENT TEMPERATURE: 34.3 C MAXIMUM INCLINATION: 78.5 AVERAGE AZIMUTH: 85.1 WIRELINE REZERO VALUE: N/A REZERO ERROR / K: N/A CALIBRATION USED FOR FIELD SURVEY: 1857 CALIBRATION USED FOR FINAL SURVEY: 1857 PRE JOB MASS BALANCE OFFSET CHECK: -.33 POST JOB MASS BALANCE OFFSET CHECK~: USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES -.40 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY FINAL SURVEY 8700 74.05 85.27 5611.6 474.55 5592.55 8100 74.05 85.27 5611,6 474,55 5592,55 FUNCTION TEST JOB NUMBER: A0197GCE381 5 Survey stations were collected at the measured depth shown below. The tables repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 2400 19.66 19.66 19.66 19.66 19.66 AZIMUTH M.D. ft 1 2 3 4 5 2400 83.39 83.29 83.38 83.13 83.20 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: A0197GCE381 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS P. RIMARY TOOL No. 758 GYRO SECTION DATA SECTION POWER SECTION BACKUP TOOL No. 749 GYRO SECTION DATA SECTION POWER SECTION A0124 C0089 C0040 A0124 C0084 C0080 COMPUTER A0222 POWER SUPPLY PRINTER A0079 INTERFACE A0087 COMPUTER A0349 POWER SUPPLY PRINTER A0029 INTERFACE A0055 A0085 A0107 WIRELINE COMPANY: CABLE SIZE: 15/32" SCHLUMBERGER WIRELINE RUNNING GEAR 2.25" TOTAL LENGTH OF TOOL :33.5 FEET MAXIMUM O.D.: 2.25 INCHES TOTAL WEIGHT OF TOOL: 220 POUNDS A Gyr oda t a D i r e c t i ona i Survey for B.P. EXPLORATION K PAD, WELL NO. MPK-18 MILNE POINT FIELD, ALASKA Job Number: A0197GCE381 Run Date: 4-Feb-97 12:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.425000 deg. N Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 84.070 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i ona I Survey B.P. EXPLORATION K PAD, WELL NO. MPK-18 MILNE POINT FIELD, ALASKA Job Number: A0197GCE381 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 0.0 0.00 0.00 0.0 100.0 .56 19.26 100.0 199.0 .58 85.91 199.0 300.0 .69 86.51 300.0 400.0 .78 88.14 400.0 0.0 0.00 0.0 0.0 0.00 N 0.00 .2 .56 .5 19.3 .46 N .16 .9 .63 1.3 40.6 .95 N .82 2.0 .11 2.2 62.0 1.02 N 1.93 3.3 .09 3.4 71.4 1.08 N 3.21 501.0 .82 95.51 501.0 600.0 .76 98.82 600.0 701.0 .77 101.98 701.0 802.0 .85 102.47 801.9 901.0 1.22 93.22 900.9 4.7 6.0 7.3 8.7 10.4 .11 .08 .04 .08 .40 4.7 77.4 6.0 81.7 7.3 85.1 8.7 87.9 10.5 89.4 .04 N 4.62 .87 N 5.97 .62 N 7.30 .32 N 8.69 · 10 N 10.46 1002.0 1.40 100.65 1001.9 1100.0 1.37 104.63 1099.9 1201.0 1.50 102.49 1200.8 1302.0 .93 83.40 1301.8 1402.0 .86 76.69 1401.8 12.7 14.9 17.3 19.4 20.9 .25 .11 .15 .69 .12 12.8 90.8 15.1 92.7 17.6 94.2 19.7 94.3 21.2 93.3 .19 S 12.75 .70 S 15.06 1.29 S 17.52 1.49 S 19.62 1.22 S 21.16 1500.0 .88 91.53 1499.8 1600.0 .83 93.65 1599.8 1701.0 3.03 76.69 1700.7 1800.0 5.43 72.24 1799.4 1899.0 7.73 73.57 1897.8 2001.0 9.49 75.11 1998.6 2100.0 11.98 78.57 2095.9 2201.0 14.72 80.75 2194.2 2300.0 17.44 84.07 2289.3 2400.0 19.66 83.19 2384.1 22.4 23.9 27.2 34.4 45.6 60.6 78.9 102.1 129.5 161.3 .23 .06 2.22 2.45 2.33 1.74 2.59 2.76 2.90 2.25 22.7 92.7 24.1 92.7 27.4 91.2 34.5 87.6 45.6 84.0 60.7 81.6 79.1 80.5 102.4 80.4 129.7 80.8 161.5 81.4 1.07 S 22.63 1.14 S 24.12 .57 S 27.44 1.46 N 34.45 4.78 N 45.31 8.88 N 60.02 13.01 N 77.97 17.15 N 100.91 20.71 N 128.09 24.25 N 159.70 E E . E E E 2450.0 20.10 83.63 2431.1 2500.0 20.86' 83.58 2477.9 2550.0 21.23 83.67 2524.6 178.4 195.8 213.8 92 53 73 178.5 81.6 196.0 81.7 214.0 81.9 26.20 N 176.59 28.15 N 193.97 30.14 N ,211.82 A Gyr oda t a D i r e c t i ona i Survey 3.P. EXPLORATION PAD, WELL NO. MPK-18 ~ILNE POINT FIELD, ALASKA ~ob Number: A0197GCE381 Page ~EASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2601.0 22.17 84.01 2572.0 2650.0 22.97 83.94 2617.2 232.7 251.5 1.87 232.8 82.1 1.64 251.6 82.2 32.17 N 230.56 E 34.14 N 249.27 E 200.0 23.75 84.29 2663.1 2750.0 25.49 84.17 2708.6 2800.0 26.62 84.24 2753.5 2850.0 26.91 84.20 2798.1 2900.0 26.06 84.07 2842.9 271.3 292.1 314.1 336.6 358.9 I . 3 2 1 59 271.4 82.3 .47 292.2 82.5 .27 314.2 82.6 .57 336.7 82.7 .70 359.0 82.8 36.17 N 268.99 E 38.27 N 289.71 E 40.48 N 311.56 E 42.75 N 333.97 E 45.03 N 356.15 E 2950.0 26.98 83.89 2887.6 3000.0 28.91 84.07 2931.8 3050.0 29.87 84.55 2975.4 3100.0 31.13 84.85 3018.4 3151.0 32.83 84.93 3061.7 381 404 429 454 481 .2 .6 .2 .6 .6 1.84 381.3 82.9 3.88 404.7 82.9 1.97 429.3 83.0 2.54 454.6 83.1 3.33 481.6 83.2 47.37 N 378.35 E 49.82 N 401.65 E 52.25 N 426.07 E 54.60 N 451.33 E 57.00 N 478.24 E 3201.0 35.03 84.86 3103.2 3250.0 36.56 84.81 3142.9 3300.0 37.84 84.54 3182.8 3350.0 40.65 84.35 3221.5 3400.0 42.89 84.26 3258.8 509 538 568 600 633 .5 .1 .4 .0 .3 4.41 509.5 83.3 3.13 538.2 83.4 2.57 568.4 83.4 5.63 600.0 83.5 4.47 633.3 83.5 59.48 N 506.03 E 62.06 N 534.57 E 64.87 N 564.67 E 67.93 N 596.16 E 71.24 N 629.30 E 3451.0 44.29 84.42 3295.7 3500.0 45.55 84.45 3330.4 3551.0 46.90 83.52 3365.7 3601.0 48.97 82.81 3399.2 3651.0 50.65 82.67 3431.4 668 703 739 777 815 .5 .1 .9 .0 .2 2.76 668.5 83.6 2.57 703.1 83.6 2.95 739.9 83.6 4.27 777.0 83.6 3.38 815.2 83.6 74.71 N 664.29 E 78.07 N 698.72 E 81.93 N 735.34 E 86.35 N 772.19 E 91.18 N 810.08 E 3700.0 52.41 82.63 3461.9 3750.0 54.17 82.45 391.8 3801.0 55.20 82.54 3521.3 3850.0 56.48 82.73 3548.8 3900.0 57.48 83.14 3576.1 853.5 893.6 935.2 975.7 1017.6 3.58 853.6 83.5 3.55 893.6 83.5 2.01 935.2 83.4 2.64 975.8 83.4 2.12 1017.7 83.4 96.09 N 848.13 E 101.29 N 887.87 E 106.73 N 929.13 E 111.93 N 969.34 E 117.08 N 1010.94 E A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION K PAD, WELL NO. MPK-18 ~ILNE POINT FIELD, ALASKA /ob Number: A0197GCE381 Page ~EASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 3950.0 58.84 83.62 3602.4 4001.0 60.07 83.77 3628.4 4050.0 61.23 83.70 3652.4 4101.0 62.30 83.51 3676.5 4151.0 63.23 83.45 3699.4 4200.0 65.00 83.29 3720.8 4250.0 66.64 83.32 3741.2 4301.0 67.32 83.24 3761.2 4350.0 68.76 83.25 3779.5 4400.0 69.40 83.40 3797.4 1060.1 1104.0 1146.7 1191.7 1236.1 1280 1325 1372 1418 1464 .2 .8 .7 .2 .9 2.84 1060.2 83.4 2.41 1104.1 83.4 2.38 1146.8 83.4 2.13 1191.7 83.4 1.85 1236.2 83.4 3.62 1280.3 83.4 3.29 1325.9 83.4 1.33 1372.8 83.4 2.95 1418.3 83.4 1.29 1465.0 83.4 121.98 N 1053.14 E 126.80 N 1096.79 E 131.46 N 1139.25 E 136.47 N 1183.90 E 141.52 N 1228.07 E 146.61 N 1271.85 E 151.92 N 1317.16 E 157.41 N 1363.77 E 162.76 N 1408.90 E 168.19 N 1455.29 E 4450.0 70.71 83.66 3814.4 4500.0 71.25 83.75 3830.7 4550.0 71.35 83.59 3846.8 4600.0 72.61 83.73 3862.2 4651.0 73.56 83.65 3877.1 1511 1559 1606 1654 1702 .9 .1 .5 .0 .8 2.67 1512.0 83.4 1.10 1559.2 83.4 .37 1606.6 83.4 2.54 1654.1 83.4 1.86 1702.9 83.4 173.48 N 1501.99 E 178.67 N 1548.97 E 183.89 N 1596.04 E 189.14 N 1643.30 E 194.50 N 1691.80 E 4700.0 73.89 83.75 3890.8 4750.0 73.94 84.10 3904.6 4800.0 73.70 84.26 3918.6 4850.0 74.77 84.27 3932.2 4900.0 74.83 84.38 3945.3 4951.0 75.09 84.40 3958.5 5001.0 75.40 84.42 3971.2 5050.0 75.18 84.65 3983.7 5100.0 75.64 84.67 3996.3 5150.0 75.82 84.82 4008.6 1749 1797 1845 1894 1942 1991 2039 2087 2135 2184 .9 .9 .9 .1 .3 .6 .9 .3 .7 .1 .71 1750.0 83.4 .68 1798.0 83.5 .58 1846.0 83.5 2.14 1894.1 83.5 .24 1942.4 83.5 .51 1991.6 83.5 .61 2040.0 83.6 .64 2087.4 83.6 .94 2135.7 83.6 .45 2184.2 83.6 199.66 N 1738.55 E 204.75 N 1786.32 E 209.62 N 1834.09 E 214.43 N 1881.97 E 219.20 N 1929.98 E 224.01 N 1979.00 E 228.73 N 2027.12 E 233.24 N 2074.30 E 237.75 N 2122.47 E 242.19 N 2170.73 E 5200.0 77.10 84.95 4020.3 5250.0 76.26 85.28 4031.8 5300.0 76.40 85.46 4043.7 2232.7 2281.4 2330.0 .59 2232.8 83.7 .81 2281.4 83.7 .47 2330.0 83.7 246.52 N 250.66 N 254.58 N 2219.14 E 2267.62 E 2316.05 E A Gyr oda t a D i r e c t i ona i Survey B.P. EXPLOP~ATION K PAD, WELL NO. MPK-18 MILNE POINT FIELD, ALASKA Job Number: A0197GCE381 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 5351.0 76.93 85.47 4055.4 5400.0 76.78 85.45 4066.6 2379.6 1.04 2379.6 83.8 2427.3 .31 2427.3 83.8 258.51 N 2365.52 E 262.28 N 2413.08 E 5450.0 76.83 85.26 4078.0 5501.0 76.54 85.19 4089.7 5550.0 76.93 85.07 4101.0 5600.0 76.96 85.28 4112.3 5651.0 77.04 85.44 4123.7 2475.9 .39 2476.0 83.8 2525.6 .60 2525.6 83.9 2573.2 .83 2573.3 83.9 2621.9 .40 2621.9 83.9 2671.6 .34 2671.6 83.9 266.22 N 2461.60 E 270.36 N 2511.06 E 274.40 N 2558.58 E 278.50 N 2607.12 E 282.52 N 2656.65 E 5700.0 77.19 85.34 4134.7 5750.0 76.00 85.44 4146.2 5800.0 77.50 86.43 4157.7 5850.0 78.76 87.13 4168.0 5901.0 77.21 87.40 4178.6 2719.4 .38 2719.4 84.0 2768.0 2.40 2768.0 84.0 2816.6 3.57 2816.6 84.0 2865.5 2.86 2865.5 84.1 2915.3 3.08 2915.3 84.1 286.37 N 2704.26 E 290.28 N 2752.74 E 293.72 N 2801.28 E 296.47 N 2850.13 E 298.86 N 2899.96 E 5950.0 77.11 87.34 4189.5 6000.0 75.81 87.31 4201.2 6050.0 75.65 87.28 4213.5 6100.0 74.53 87.24 4226.4 6151.0 73.84 87.01 4240.3 2963.0 .23 2963.0 84.2 3011.5 2.60 3011.6 84.2 3059.9 .32 3059.9 84.3 3108.2 2.26 3108.2 84.3 3157.2 1.42 3157.2 84.4 301.05 N 2947.68 E 303.32 N 2996.24 E 305.60 N 3044.64 E 307.91 N 3092.90 E 310.38 N 3141.91 E 6200.0 75.01 87.01 4253.4 6251.0 75.12 87.10 4266.6 6301.0 75.42 87.26 4279.3 6351.0 75.91 87.22 4291.7 6400.0 74.'82 87.16 4304.1 3204.3 2.40 3204.4 84.4 3253.5 .27 3253.6 84.4 3301.8 .67 3301.9 84.5 3350.2 .97 3350.3 84.5 3397.5 2.23 3397.6 84.6 312.84 N 3189.05 E 315.37 N 3238.26 E 317.75 N 3286.56 E 320.08 N 3334.94 E 322.40 N 3382.30 E 6451.0 75.17 87.07 4317.3 6501.0 73.82 86.76 4330.6 6550.0 74.07 86.51 4344.2 6600.0 73.55 86.14 4358.1 6650.0 73.20 86.13 4372.4 3446.7 .71 3446.8 84.6 3494.8 2.77 3495.0 84.6 3541.9 .70 3542.0 84.7 3589.8 1.26 3590.0 84.7 3637.7 .71 3637.9 84.7 324.87 N 3431.49 E 327.47 N 3479.60 E 330.23 N 3526.61 E 333.31 N 3574.53 E 336.54 N 3622.33 E ~.P. EXPLORATION PAD, WELL NO. MPK-18 ~ILNE POINT FIELD, ALASKA Iob Number: A0197GCE381 A Gy r o d a t a Directional Survey Page ~EASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 6700.0 74.12 86.37 4386.5 3685.7 6751.0 73.63 86.41 4400.7 3734.6 6800.0 73.94 86.51 4414.3 3781.6 6850.0 73.86 86.56 4428.2 3829.6 6900.0 74.41 86.66 4441.9 3877.7 1.90 3685.9 84.7 .96 3734.9 84.7 .65 3781.9 84.8 .18 3829.9 84.8 1.11 3878.0 84.8 339.67 N 3670.21 E 342.76 N 3719.10 E 345.66 N 3766.06 E 348.56 N 3814.02 E 351.40 N 3862.03 E 6951.0 74.77 86.66 4455.4 7001.0 74.45 86.74 4468.7 7051.0 73.98 86.44 4482.3 7101.0 73.87 86.53 4496.1 7150.0 74.05 86.63 4509.7 3926 3974 4023 4071 4118 .8 .9 .0 .0 .1 .71 3927.1 84.8 .66 3975.3 84.8 1.11 4023.4 84.9 .29 4071.4 84.9 .42 4118.5 84.9 354.26 N 3911.11 E 357.04 N 3959.24 E 359.90 N 4007.27 E 362.85 N 4055.22 E 365.66 N 4102.23 E 7200.0 75.08 86.75 4523.0 7251.0 75.18 86.72 4536.1 7301.0 75.61 86.67 4548.7 7350.0 74.66 86.44 4561.3 7400.0 74.35 85.91 4574.6 4166 4215 4263 4311 4359 .2 .4 .8 .1 .2 2.08 4166.7 84.9 .19 4215.9 84.9 .87 4264.3 85.0 1.98 4311.6 85.0 1.18 4359.8 85.0 368.44 N 4150.35 E 371.25 N 4199.56 E 374.04 N 4247.86 E 376.89 N 4295.13 E 380.10 N 4343.21 E 7450.0 74.54 85.56 4588.0 7500.0 74.50 85.74 4601.4 7550.0 75.31 85.87 4614.4 7601.0 74.23 85.67 4627.8 7650.0 74.19 85.82 4641.1 7701.0 74.81 85.80 4654.8 7750.0 74.52 85.91 4667.7 7801.0 73.98 86.17 4681.6 7850.0 74.25 86.47 4695.0 7900.0 74.35 86.23 4708.5 4407 4455 4503 4553 4600 4649 4696 4745 4792 4840 .4 .6 .8 .0 .1 .2 .5 .5 .6 .7 . 78 4408.0 85.0 35 4456.2 85.0 63 4504.4 85.0 15 4553.6 85.0 30 4600.8 85.0 21 4649.9 85.0 62 4697.2 85.1 18 4746.2 85.1 82 4793.4 85.1 51 4841.5 85.1 383.68 N 4391.25 E 387.33 N 4439.29 E 390.86 N 4487.44 E 394.49 N 4536.51 E 397.99 N 4583.53 E 401.59 N 405.00 N 408.39 N 411.42 N 414.48 N 4632.54 E 4679.68 E. 4728.64 E 4775.68 E 4823.71 E 7950 . 0 74 . 69 86 . 15 4721.8 8001 . 0 74 . 39 86 . 04 4735 . 4 8050 . 0 74 . 99 85 . 64 4748 . 4 4888 4938 4985 .9 .0 .2 72 4889.7 85.1 63 4938.8 85.1 44 4986.1 85.1 417.68 N 421.03 N 424.46 N 4871.79 E 4920.83 E 4967.97 E A Gyro da t a D i r e c t i on a i Survey B.P. EXPLORATION K PAD, WELL NO. MPK-18 MILNE POINT FIELD, ALASKA Job Number: A0197GCE381 Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 8101.0 75.87 85.43 4761.2 5034.6 1.77 5035.4 85.1 8151.0 74.96 85.45 4773.8 5083.0 1.80 5083.8 85.1 428.30 N 432.15 N 5017.18 E 5065.41 E 8200.0 74.30 85.47 4786.8 5130.2 1.35 5131.1 85.1 8250.0 74.56 85.39 4800.2 5178.3 .54 5179.2 85.1 8301.0 74.59 85.37 4813.8 5227.5 .06 5228.4 85.1 8351.0 74.58 85.60 4827.1 5275.7 .45 5276.6 85.1 8400.0 74.49 85.36 4840.1 5322.9 .51 5323.8 85.1 435.89 N 5112.51 E 439.73 N 5160.53 E 443.70 N 5209.53 E 447.49 N 5257.58 E 451.21 N 5304.66 E 8450.0 74.40 85.43 4853.5 5371.0 .23 5372.0 85.1 8500.0 74.51 85.44 4866.9 5419.2 .22 5420.2 85.1 8551.0 74.31 85.41 4880.6 5468.3 .39 5469.3 85.1 8601.0 74.39 85.37 4894.1 5516.4 .17 5517.4 85.1 8650.0 74.02 85.23 4907.5 5563.6 .80 5564.6 85.1 455.08 N 5352.67 E 458.92 N 5400.69 E 462.83 N 5449.66 E 466.70 N 5497.65 E 470.57 N 5544.64 E 8700.0 74.05 85.27 4921.2 5611.6 .11 5612.6 85.1 474.55 N 5592.55 E Final Station Closure: Distance: 5612.65 ft Az: 85.15 deg. A Gyr oda t a D i r e c t i ona i Survey for B.P. EXPLORATION K PAD, WELL NO. MPK-18 MILNE POINT FIELD, ALASKA ~ob Number: SUB381 Run Date: 4-Feb-97 12:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.425000 deg. N Sub-sea Correction from Vertical Reference: 62.4 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 84.070 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i ona i Survey ½.P. EXPLORATION PAD, WELL NO. MPK-18 4ILNE POINT FIELD, ALASKA Iob Number: SUB381 Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet -62.4 0.00 0.00 0.0 100.0 .57 61.27 162.4 200.0 .65 86.29 262.4 300.0 .75 87.53 362.4 400.0 .81 92.70 462.4 0.0 .7 1.6 2.8 4.2 .00 0.0 0.0 .60 1.3 32.7 .31 2.2 54.1 .10 3.4 67.9 .10 4.7 75.1 0.0 N 0.0 E .8 N .6 E 1.0 N 1.5 E 1.1 N 2.7 E 1.1 N 4.1 E 500.0 .78 97.56 562.4 600.0 .76 100.77 662.4 700.0 .82 102.28 762.4 800.0 1.08 96.82 862.4 900.0 1.33 97.74 962.4 5 6 8 9 11 .5 .8 .1 .7 .8 .09 6.0 80.1 .06 7.3 83.8 .07 8.7 86.8 .28 10.5 88.8 .31 12.8 90.3 .9 N 5.5 E .7 N 6.8 E .4 N 8.1 E .2 N 9.8 E .2 S 11.9 E 1000 1100 1200 1300 1400 .0 1.38 103.11 1062.4 .0 1.45 103.30 1162.4 .0 1.15 90.85 1262.4 .0 .89 79.34 1362.4 .0 .87 85.87 1462.4 14 16 18 20 21 .1 .4 .6 .3 .8 .16 15.1 92.0 .13 17.6 93.6 .48 19.7 94.3 .35 21.2 93.7 .19 , 22.7 92.9 .5 S 14.2 E 1.1 S 16.6 E 1.4 S 18.8 E 1.3 S 20.6 E 1.1 S 22.1 E 1500 1600 1700 1800 1900 .0 .0 .0 .0 .0 .85 92.86 1562.4 2.19 83.13 1662.4 4.53 73.91 1762.4 6.91 73.09 1862.4 8.86 74.56 1962.4 23 26 31 41 55 .3 .0 .7 .5 .2 .13 24.1 92.7 .40 27.4 91.8 .37 34.5 88.9 .37 45.6 85.3 .95 60.7 82.4 1.1 S 23.6 E .8 S 26.2 E 1.1 N 31.8 E 3.6 N 41.4 E 7.4 N 54.7 E 2000 2100 2200 2300 2400 .0 .0 .0 .0 .0 11.12 77.38 2062.4 13.83 80.05 2162.4 16.67 83.13 2262.4 19.15 83.39 2362.4 20.61 83.60 2462.4 72 94 121 154 190 .6 .6 .8 .1 .0 .30 79.1 80.9 .71 102.4 80.4 .86 129.7 80.7 .39 161.5 81.2 .33 196.0 81.7 11.6 N 71.8 E 15.8 N 93.5 E 19.7 N 120.4 E 23.4 N 152.5 E 27.5 N 188.2 E 2500 2600 2700 .0 .0 .0 21.98 83.94 2562.4 23.74 84.29 2662.4 26.68 84.23 2762.4 228 271 318 .8 .0 .6 · 64 232.8 82.0 · 59 271.4 82.3 .93 336.7 82.6 31.8 N 226.8 E 36.1 N 268.7 E 40.9 N 316.0 E A Gyro da t a D i r e c t i ona i Survey ~.P. EXPLORATION PAD, WELL NO. MPK-18 ~ILNE POINT FIELD, ALASKA Iob Number: SUB381 Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. HORIZONTAL COORDINATES feet 2800.0 26.46 2900.0 29.58 84.00 2862.4 84.41 2962.4 368.6 421.9 1.76 381.3 82.8 2.54 429.3 83.0 46.0 N 365.8 E 51.5 N 418.8 E 3000.0 32.86 3100.0 37.19 3200.0 43.03 3300.0 46.77 3400.0 52.43 84.93 3062.4 84.68 3162.4 84.27 3262.4 83.60 3362.4 82.62 3462.4 482.0 552.9 636.8 736.4 854.1 3.34 509.5 83.2 2.86 568.4 83.4 4.30 668.5 83.5 2.92 739.9 83.6 3.58 893.6 83.5 57.0 N 478.7 E 63.4 N 549.3 E 71.6 N 632.7 E 81.6 N 731.9 E 96.2 N 848.8 E 3500.0 56.98 3600.0 61.68 3700.0 67.41 3800.0 72.62 3900.0 75.18 82.93 3562.4 83.62 3662.4 83.24 3762.4 83.73 3862.4 84.40 3962.4 996. 1165. 1375. 1654. 2006. 2.38 1017.7 83.4 2.27 1191.7 83.4 1.43 1418.3 83.4 2.53 1702.9 83.4 .54 2040.0 83.5 114.5 N 990.1 E 133.5 N 1157.8 E 157.8 N 1366.7 E 189.2 N 1643.9 E 225.5 N 1993.7 E 4000.0 76.84 4100.0 78.08 4200.0 75.09 4300.0 73.45 4400.0 74.61 85.46 4062.4 2409.5 86.75 4162.4 2839.0 87.07 4262.4 3237.8 86.14 4362.4 3604.1 86.70 4462.4 3952.1 .58 2427.3 83.8 .25 2865.5 84.0 .95 3253.6 84.4 .09 3637.9 84.7 .68 3975.3 84.8 260.9 N 2395.3 E 295.0 N 2823.6 E 314.6 N 3222.6 E 334.3 N 3588.8 E 355.7 N 3936.4 E 4500.0 74.63 4600.0 74.64 4700.0 75.78 4858.8 74.05 86.39 4562.4 4315.2 1 85.86 4662.4 4677.1 85.43 4762.4 5039.2 1 85.27 4921.2 5611.6 .92 4359.8 85.0 .86 4697.2 85.1 .77 5083.8 85.1 .11 5612.6 85.1 377.2 N 4299.2 E 403.6 N 4660.4 E 428.7 N 5021.8 E 474.6 N 5592.5 E Final Station Closure: Distance: 5612.65 ft Az: 85.15 deg. CHRONOLOGICAL REPORT JOB NUMBER: A0197GCE381 02/01/97 12:00 FINISH 380 STANDBY ON SLOPE 02/O2/97 09:00 O2/O3/97 . 09:00 02/O4/97 05:30 07:45 08:30 10:30 12:00 13:15 14:00 14:45 16:30 18:00 19:00 20:30 22:30 2/05/97 17:00 CHECK TOOLS, STANDBY CHECK TOOLS, STANDBY TO LOCATION ARRIVE LOCATION MU TOOL WARM UP TOOL STANDBY RU SCHLUMBERGER PU TOOL START INRUN SURVEY SURVEY CONTINUOUS TO 8100' OUTRUN LD TOOL RTN TO ATLAS ARRIVE ATLAS PROCESS SURVEY, CHECK TOOL, RETURN TO RIG WITH RESULTS. RETURN TO ANCHORAGE STATE OF ALASKA ALASKA.. ~,iL AND GAS CONSERVATION CO;~¢MISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] 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 3689' NSL, 1998' WEL, SEC. 3, T12N, R11E At top of productive interval N/A At effective depth N/A At total depth 4589' NSL, 1277' EWL, SEC. 1, T12N, R11E 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) Plan RTE = 61.5' 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-18 9. Permit Number 97-04 10. APl Number 50-029-22733 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 12672 feet true vertical 7290 feet Effective depth: measured N/A feet true vertical N/A feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 83' 20" 8848' 9-5/8" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (Approx.) 1205 sx PF 'E', 523 sx 'G', 161 sx PF 'C' ORIGINAL MD TVD 113' 113' 8884' 4975' Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A RECEIVED FEB 7 199 ' Alaska Oil 8, Gas Cons. Commission Anchorage 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 4. Estimated date for commencing operation 02/07/97 16. If proposal was verbally approved ~.¢~- L,J o,,~. ~ ~.~-. ~ t. Name of approver Date approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Contact Engineer Name/Number: Lance Spencer, 564-5042 Prepared By Name/Number: Kathy Campoamor, 564-5122 17. I hereby certif~y_~h.~at the foregoing is true and correct to the best of my knowledge Signed RandyTh'omas ~ Title Drilling Superintendent Date Commission Use Only Conditions of Approval: Notify Commission so representative may witness I Approval N~r~ -" D~q,~) Plug integrity f Mechanical Integrity Test __ Approved by order of the Commission BOP Test Location clearance Subsequent form required 10- Ung~na~ David W. Johnston Commissioner Submitlln Tr/fplicate Form 10-403 Rev. 06/15/88 Approved Copy Returned_.. %. RECEIVED FEB ? 99'[ M P K- 18 P I u g b a c k ~aS~ Oil & (]as Cons. Commission Proposed Summary of Operations Milne Pt. Well~ MPK-18 was drilled by ~RS RIG~ 27E to a depth of 12,672' md (7,291' TVDbkb). LWD logs revealed the well was determined to be non-commercial due to high water saturation. Consequently the KUPARUK S~DS will be ~don~ and the well will be sidetracked from the sudace casing shoe. Milne Point well MP K-18Ai will be drilled to another location and be utilized as an injection well.The sudace casing, 9-5/8", 40~, L-80, BTC was set at 8,883' md/4,975' TVD while drilling MP K-18. Verbal approval was obtained from with AO303 to abandon the KUPARUK Sands and spot a SIDETRACK kickoff plug as outlined below. This verbal approval was given on in a phone conversation to L. J. Spencer with BPXA Shared Services Drilling. 1. POOH after TD Milne Pt. Well# MP K-18. 2. PU muleshoe and 1500' of 3-1/2" drillpipe. RIH on 5" drillpipe to TD at 12,672 ' md (ESTIMATED TOP KUPARUK 'D' shale 12,240' MD). Circulate and condition hole for cement plug. Spot a 94 bbl (456 sx) balanced cement plug. Slowly pull out of cement plug. At 1 5 stands above the plug rig up and circulate slowly down the drillpipe 1 drillpipe volume. MONITOR RETURNS. IF LOSING FLUID SHUTDOWN. NOTE: The estimated cement volume is equivalent to the 8-1/2" hole volume from TD to 500' above KUPARUK 'D' Shale + 30% excess. Cement Type: PREMIUM G Addititives: 0.20% HALAD 344 + 0.20% CFR3 + HR5 AS NECESSARY WT: 15.8 PPG YIELD: 1.15 FT3/SK 3. Contact AOGCC and request representitive to witness or waiver tagging of first cement plug. 4. POOH above cement and WOC then tag cement if required by AOGCC. 5. Continue POOH to 9,533' md. Spot 30 bbl high visc mud pill (weight of pill at current mud weight). Continue POOH to 9,183' md. Spot 48 bbl (250 sx) balanced cement plug. Slowly pull out of plug. At 15 stands above the plug rig up and circulate slowly down the drillpipe 1 drillpipe volume. MONITOR RETURNS. IF LOSING FLUID SHUTDOWN. POOH LD muleshoe. NOTE::The estimated cement volume is equivalent to the volume from 8683-9183' md plus excess.(300' of 8-1/2" open hole below the casing shoe plus 50% excess and 200 ft inside 9-5/8", 40# casing. The 9-5/8" shoe is at 8,883' md. Cement Type: PREMIUM G Addititives: 1% CACL2 WT: 16.0 ppg YIELD: 1.05 FT3/SK 6. Test BOPE. 7. Contact AOGCC and request representitive to witness or waiver tagging of second cement plug. 8. POOH above cement and WOC then tag cement if required by AOGCC. 9. MU bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH to 8,300' md. Begin washing and reaming until cement is tagged. Drill cement to 8,933 md. NOTE:Indicate on morning report "TAG WEIGHT". 1 0.Circulate and condition mud at 8,933' md before begin sidetrack. ! 11. Drill 8.5" hole to TD as per directional plan. 1 2. Run and Cement 7" Casing. 1 3.Test casing to 4000 psig. 14.ND BOPE and 11" drilling spool. NU tubing spool and dry hole tree and test Tree. Install the 7-1/16 work valve at the wellhead - FMC 5M GEN 5A. Test Tree. Freeze protect 9 - 5/8" x 7" csg annulus and note on morning report. Secure well. Release rig. RDMO Nabors 27E drilling rig to drill next well. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. M,E RAND TO: THRU: State 'Alaska Alaska Oil and Gas Conservation Commission David Johns~//, Chairmarf y Blair Wondzell, ~ P. i. Supervisor FROM: Chuck Scheve, &,-4 SUBJECT: Petroleum Inspector DATE: February 3, 1997 FILE NO: awqkbcee.doc BOPE Test Nabors 27E PTD # 97-04 Monday Febru.ary 3, 1997: I traveled to BPX's MPU K-18 Well being drilled by Nabors Rig 27E and witnessed the initial BOPE test on this well. As the attached AOGCC BOPE test report shows the test lasted 4 hours with one failure. The manifold pressure regulator would not hold consistent pressure, drifting between 500 psi and the necessary 1500 psi. The regulator was repaired before drilling out the surface casing on this well. Tool Pusher Richard Larkins attention to this test was greatly appreciated. The rig was clean and all related equipment appeared to be in good working order. The location though crowded was well organized. Summary: ! witnessed the initial BOPE on Nabors rig 27E drilling BPXs MPU K-18 Well test time 4 hours 1 failure. Attachment: awqkbcee.xls X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drig: X Drlg Contractor: Operator: Well Name: Casing Size: g 5/8 Test: Initial X Workover: DATE: Nabors Rig No. 27E PTD # 97-04 Rig Ph.# ARCO Rep.: Pete Wilson K-18 Rig Rep.: 8,976 Location: Sec. Set @ 3 . T. Weekly Other 2/3/97 659-4373 Richard Larkin 12N R. 11E Meddian UM Test MISC. INSPECTIONS: Location Gen.: OK Well Sign OK Housekeeping: OK (Gen) DH. RIg OX PTD On Location YES , Hazard Sec. OK . Standing Order Posted YES ' , FLOOR SAFETY VALVES: Quan. Pressure Upper Kelly / IBOP 1 J 250/5,000 Lower Kelly / IBOP 1! 250/5,000 Ball Type '1 250/5,000 Inside BOP 'f ,, 250/5,000 P/F P P P , P BOP STACK: Quan. Annular Preventer 1 Pipe Rams I Lower Pipe Rams 1 Blind Rams 1 Choke Ln. Valves t HCR Valves 2 Kill Line Valves 1 Check Valve Test Press. P/F 250/3500 P 250/5,000 P 250/5,000 P 250/5,00O 250/5,000 250/5,000 P P CHOKE MANIFOLD: No. Valves 16 I No. Flanges 32 Manual Chokes 2. Hydraulic Chokes I Test Pressure 250/5,000 250/5,000 Functioned Functioned P/F P .p, ACCUMULATOR SYSTEM: System Pressure Pressure After Closure MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 17 sec. Trip Tank OK OK System Pressure Attained 2 minutes ~sec. Pit Level Indicators OK OK Blind Switch Covers: Master: OK Remote: OK Flow Indicator OK OK Nitgn. Btl's: 6 ~ 2200 PSI Meth Gas Detector OK ' OK - Psig. H2S Gas Detector OK / OK ' ., 30001 ' 1550 Number of Failures: 1 ,Test Time: 4.0 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7,542 Inspector North Slope Pager No. 659-3607 or 3687 if your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Manifold pressure regulator not functioning properly but was repaired before tn'ppin~l in hole II Distribution: odg-Well File c - Oper./Rig c- Database c - Tdp Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: W'rtnessed By: Chuck Scheve FI-021L (Rev. 12/94) AWQKBCEE.XLS · BP EXPLORATION BP Exploration (Alaska) Ino. PO Box lg6612 ^nohorage, ^lask~ 99519-6612 TELECOPY COMMUNICATIONS CENTER MESSAGE# TO: Name: J o..c., k ('"J,~ ,,.-" "{'- ~ Company: A 0 ~ C_..,C Location: Confirm # FROM: Name & Ext.: {...¢~ Departmen[: ,T'~-, II, --, ~ Mail Stop; PAGES TO FOLLOW (Do Not Include Cover Sheet) 8EOURITYOLA881FIOATION PRIVATE SECRET CONFIDENTIAL Telecopy # Confirm # For Communications Center Use Only Time In Time Sent Time Confirmed Confirmed By Operator jAN 1 6 1997 Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION Janua~ 2, 1197 Jack Hartz Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3~t92 JAN 1 6 1997 Oi! & Gas Cons, Oomm~ion, Anchorage Subject: Before Spud Changes to Approved Application for Permit to Ddll #97-04 Dear Mr. Hartz, In order to correct an errors on the permit, is it necessary to replace the directional plan, modify the surface casing seffing depth, surface cementing program, proposed depth and production casing setting depth which were approved in the Permit to Drill #9-04 on January '/4, 1997. This correspondence is submitted in order to be in compliance with AOGCC Regulation 20 ACC 25.0'/~, Changes to Drilling Permit, (a) For a propoeed change in a drilling permit ...... before the start of actual drilling operations, Several mistakes where made while preparing this permit however the surface, top of the productive interval, and ~he total depth, as reported in Item 4 of the Permit to Drill are correct. The wrong directional well plan was submitted with the application by mistake and I failed to make all the necessary corrections to the permit when the directional plan was changed before sending it. Also note, 'that the cementing program was corrected to reflect the deeper surface casing setting depth required in Directional plan 5. AS a result of these errors the following changes are requested; a. Replace directional plan with MPK-18(PS). Disregard directional plan MPK-18 (134). b. Item 15; Proposed del~th (MD and 'rVD) changed to 12764?7384'. 3. Item 18: The 9-5/8" casing setting depth, BTM MDITVD changed to 8432'/4893'. 4. Item 18: For g-5/8" casing, the surface QUANTITY OF CEMENT, that the cement type PF C cement volume be increased to 161 sacks, f 5. Item 'i8: The 7" production casing SETTING DEPTH, BTM MD/TVD changed to 12764'/7384'.' I apologize for the oversights and the inconvenience these errors may have caused to you. Thank-you for your consideration in this mater and if you have any questions or need additional information concerning this request for Before Spud Changes to Approved Application for Permit to Drill #97-04 please contact me in Anchorage at 564-5042. Respectfully Lance J. Spencer Drilling Operations Engineer Shared Services Drilling BPX , JHPt :Ll~ "~'F U:.:I: I'FP'M SHFiNI-D SI-NVIC~L,S DNILLIH.r?LA~KA ,, '~ ' :~ ALASKA ~'~' AND GAS GONSI=FIVATION PERMIT TO DRILL 20 MC 25.0O5 [] Dri[T I-'1 ~lriil 1 lb. Type ~f well I"1 ExploratOry [] Str=tlgraphic Test [] Development la, TYpeofwork i~ Re.E_ntry []Dee_pen~ I-IService I-IDe~elopment Gas [-ISingle Zone l-'lMuitiple Zone 2. Name of Operator 5. Datum Elevation (dF or KB) 10. Field and Pool BP Exploration (Alaska).lno. Plan RTE -- 61,5' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation{ Sand~ P.O. Box 196612, Anchorage, Alaska g931g-6612 ADL 375132 4. Location of well at s. urfe~' '" ~ unit or Property Name 1~-. Type Bond (See 20 AAC 23.025) 3689' N8L, 1998' WEL, SEC. 3, T12N, R11E Miine Point, Unit At top of productive interval 8. Well Nu'~'ber Number 2S100302630-277 4558' NSL, 4136~ WEL, SEC. 1, T12N, RllE MPK-18 At ~otal depth 9. Approximate sp-t~d date Amount $200,000,00 4576' NSL, ,3960' WEL, SEC. 1, T12N, R 11E 01/16197 12. Distance to ne~re~'t i~ ' 113, nearest ..... r~p0:,rty line[ Distanoi~ to well 14. Number o! acres in property' 15, Proposed depth (MI;;) a~ 'T~I~)' ^DL 0~823~, No ClOse Approach 'P--SS0 ~..~,~ ~I~MD / 7384'.'TVD .16. To be completed for deviated wells ,17. AntFcil~ated pressure [~ee zo AAC, ~S.o3s (,) KickOff Dept.h. 1400' Maximum Hole Angl.e ?~.~a' Maxlmum~u~ace 293g pslg, At~totaldeplh('rVO) 7085' I 3647 psig .18. Oasing Program Spe~ifioatlons Setting Depth Size .,Top Bottom Quantity of C,..ement Hole Casing Weight" Grade Couplin'~t'- Length MD ' TVD MD TvI~'" (,include stage data) [, 2.4" 20"' 91.1# H-40 Weld 80' , 32' ~' ' I 112'. 112'. 250 sx Arctlcset I (Appr(~x.) 12-1/4" 9-5/8" ' 40# L-El0-' ' Btrc 7...I-~;i~' ~'i~1' 31' ~¢~.~_' ,~90'2' ,~.~.~,,.~-.,~,.~,.~.~-~.-, _._8. :1/~'~.. 7" - -'~.6# L-80 .... Btm 127p~4' ,30' 30' L~-I 2.7.,3~;" ," .......... ' . 73__~7' 2693x (~SS'G' .. . __. ,,., 11 , .. _ _~ ,,.. . .i -" .... . .--- -. ,, * ,, 19. To be completed for Redrill, Re-entry, and Deepe~ Operations. ' .... i Pre,ant well ~ondltlon summ~ry , - Total depth: measured feet Plugs'(measured) true ve~cal feet Effeotive depth: measured feet Junk (.mea. a..~s, sured) , true vertical feet Casing Length Size ' ~emented MD TVD Structural Conductor Intermediate Produotion jAN 0 7 1997 Liner Anchorage Perforation depth: measured true vertical 20. Att~.hme~a , [] Filing Fee'" 0 P;'~'perty Plat t:3 I~P Sketch '- - [] I~lvert. r Sketch [] Drll~r~ Program ' -'. [] Drflfing Fluid Program ~Time ~ Depth Plot [] Refra,Gtion Anstysie [3 Seabed Report [] ~0 A.~.C,25,050 Requ~remen,~ Contact Engineer Neme/Numb~ri' Lance Spencer, 564-5042 Prepared By Nam~Vumben Kathy Campoamor, 564.~12£ 21, ISignedh'ereby ~ertif~; th~.i the~fpregoir~l[ji _ [~.~ ~1 ~/"la t~ and (~orrect to the best of m~- knowledge .. /! /- -- ~' 50- ~':~...~'..- ~_.-:~-_"~' ~ 3 /'"/~--~7 for other requirements ~_.onditions of Ap ~~e~ Recl~:~ ~.,,Yes ~ N~)-~ No-- Mud Log Required ID Yes' .,.1~ ~ ~ _F~dro.~en..gul~e_Me_'~_a_ure~, N~.Yes Directional Survey Required Yes [] No f PE' '~] ~3M; ~ SM; ID1OM; [~ 15M by order ofZj/lJ App?oved.By .... Commiss. i.oner the commission ,.,,~te _ Form 10-401 Rev, 1~-i ~ )licate ]997 Alaska 0il & Gas Cons. ~,omm,sston An~hora..qe MEMORANDUM OiL A~--iD GAS CONSERVATION COMMISSION Commissioners Petroleum Inspectors AOGCC Staff ':.lair Wondze!l~ State of Alaska December 1 6, i996 ~ .-'-". I-, ') .dOC File: c:",.nevvs,u~, ',~w96vac,~ Sbj' Coverage During Elair's Vacation 1 2/i 9/96 - 1/6/96 Senior Petroleum Enaineer Jack Hartz will assume these duties and responsibilities during my vacation. E.cco,,/ Foster. as one of the lead inspec:ors, will assume mv is! Suser'./Jsor responsibilities during my vacation. . :=~ resccc:s~c.~.;es will incluce, bu~ a,= ~,? limi~=~ t.s' rev:ev,':nc the ::c:ning -~a;(:~, sche~uiing in~oe~o~s, e'.,','~n~ a,,,~ sign-.cff :r ~:.e',d r3cor~s, resoivina cues~lons r~i~t:~ ~u ~n~-~,~QS ~c. er~:;cr.s, :ev,' :cu:smer. reviews prior to start-up, and collecting insoection group UIC ~ime sneers for Gwen. Chuck Scheve will assist Bobby in the above duties. i I hereby delegate to Bobby Foster my authority to sign Travel Authorizations landthe Juneau time sheets during my absence from 12/19/96 to 1/6t97. Bobby and Chuck will consult with and take direction from the Commissioners on questions of AOGCC Policy; they will consult with Jack Hartz on questions of engineering; and with Bob Crandall on questions of geology and log interpretation. Bobby and Chuck will work with Jack when Jack needs assistance on reviewing "Application For Sundry Approvals" or applications for "Permit To Drill" and as usual, will help everyone as best they can (normally great). There are no U1C reports required; however, please keep a copy of all MITs witnessed and non-witnessed so that I can properly enter them when I return. Thanks to all of you. TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Janualw 15. 1997 Tin] Schoficld Senior Drilling Enginccr BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Milne Point Unit MPK-I 8 BP Exploration (Alaska) Inc. Permit No.: 97-04 Sur. Loc.: 3689'NSL. 1998'WEL, Sec. 03, TI2N. RI IE. UM Btmholc Loc: 4576'NSL. 3960'WEL, Scc. 01, T12N. RI IE. UM Dear Mr. Schoficld: Enclosed is thc approvcd application for pcrmit to drill thc abovc rcfcrcnccd v~-cll. The permit to drill docs not CXClnpt you from obtaining additional permits rcquircd by law from other governmental agcncics, and docs not authorize conducting drilling opcrations until all othcr required pcrmitting dctcmfinations arc made. Blowout prevention cquipmcnt (BOPE) must bc tcstcd in accordance with 20 AAC 25.035. Sufficient noticc (approximatcly 24 hours) of thc BOPE tcst pcrformcd before drilling below the surface casing shoc must bc givcn so that a rcprcscntativc of thc Commission ma:5' witness the test. Notice mavbc givcn bv contacting thc Commission pctroleum ficld inspector on the North Slope pagcr at 659-3607. dlf/enclosures CC; l)¢partn]¢nt of Fish & (lame. llabitat Section w o encl. Department ol'Envinomment Conscrvatmn w ~ cncl STATE OF ALASKA ALASKA L,,b AND GAS CONSERVATION COrvi,vllSSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil ila. Typeofwork I-IRe-Entry [-IDeepen~ []Service I-IDevelopment Gas []Single Zone I-IMultiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 61.5' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 375132 i4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3689' NSL, 1998' WEL, SEC. 3, T12N, R11E Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 4558' NSL, 4136' WEL, SEC. 1, T12N, R11E MPK-18 Attotal depth 9. Approximate spud date Amount $200,000.00 4576' NSL, 3960' WEL, SEC. 1, T12N, R11E 01/16/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028233, 704'I No Close Approach 2560 12734' MD / 7384' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 1400' Maximum Hole Angle 74.13 o Maximum surface 2939 psig, At total depth (TVD) 7085' / 3647 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 1~,2' ¢.~1~2~ 250 sx Arcticset I (Approx.) 12.1/4" 9-5/8" 40# L-80 Btrc 7177' 31' 31' ~'~,~__.e~'~~/. 1886sxPF'E',523sx'G',~I?~I~sxPF'C'.150sxPF'E' 8-1/2" 7" 26# L-80 Btrc 12704' 30' 30' ~ ~ 269 sx Class 'G' I ¢.. ~ 19. To be completed for Redrill, Re-entry, and Deepen Operations. ¢2.¢,.¢~. ~,, ~¢~.,~V- Present well condition summary ~' Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production ~t,~,~ ~_.~ i V ~,,D Liner ORIGINAL Perforation depth: measured AJ~81 0il & Gas Cons. Commission true vertical 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: Lance Spencer, $64-$042 Prepared By Name/Number: Kathy Campoamor, $64-$122 21.1 hereby certify that th~f.oregoin, g ts tr~,, and correct to the best of my knowledge Signed~ ~)~h~"~ //~/~"~7 ~ Title Senior Drilling Engineer Date Tim Schofield ~/~(1~ ...... ~_~- ,/c-~~/~C°mmissi°n use Only PermitN"umber I APINumber I ApprovalDate I Seecoverletter ?~-<~ ~, 50- O ~.,~'-, ~-~ ~ '~ ,.~ //~"/'~-~ ~'y for other requirements Conditions of Approval: Samples Required [] Yes ,~No Mud Log Required [] Yes .~¢No Hydrogen Sulfide Measures I-IY~s .~No Directional Survey Required /~Yes [] No Required Working Pressure for BOPE [] 2M; []3M; J~ 5M; [] 10M; [] 15-~ Other: by order of //¢/~ Approved By Original Signed 9y Commissioner the commission Date/ Form 10-401 Rev. 12-01-85 Subn r Triplicate Shared Services Drilling Contact: Lance J. Spencer Well Name' IMP K-18 Well Plan Summary 564-5042 I Type of Well (producer or injector): I Kuparuk Producer Surface Location: 3689 NSL 1998 WEL Sec. 03 T12N RllE UM., AK Kuparuk Target 4558 NSL 4136 WEL Sec. 01 T12N R11E UM., AK Location: Bottom Hole 4576 NSL 3960 WEL Sec. 01 T12N R11E UM., AK Location: I AFE Number: 1337056 I I Rig: I Nabors 27-E I Date: complete' 14 IMD: 112'734'I ITVD: 7'357'Ibkb IKBE: 160'9I IWell Design (conventional, slimhole, I Milne Point Ultra Slimhole Longstring 9- etc.)' 1 5/8", 40# Surface X 7", 26# Longstring Formation Markers: Formation Tops MD TVD (bkb) Pore Pressure (EMW,15si) Base Permafrost 1 863 1 862 8.4 ppg, 813 psi NA 7404 4612 8.4 ppg, 2014 psi O~ 7 91 6 475 2 8.4 ppg, 2075 psi CB 81 53 481 7 8.4 ppg, 2154 psi BaseOB 8282 4852 8.4 ppg, 2169 psi Top HRZ I 1 71 9 6 48 2 8.6 ppg, 2899 psi Base HRZ I 1936 6667 8.6 ppg, 2981 psi TKLB 12011 6732 9.0 ppg, 3151 psi TKUP/UD 12179 6877 9.9 ppg, 3540 psi TKC1/T'ARGET 12410 7077 9.9 ppg, 3643 psi TKB7 1 2479 71 37 9.9 ppg, 3674 psi Total Depth ___12734 7357 9.9 ppg, 3801 psi Casinq/Tubing Prol'ram' Hol~, ~sg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btrc 7177 31/31 7207/4902 8-1/2" 7" 26# L-80 btrc 12704 30/30 12734/7357 The internal yield pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the Kup sand at + 7085 TVDSS In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of +7085 TVDSS. The maximum anticipated surface pressure in this case is 2939 psi assuming a reservoir pressure of 3647 psi, well below the internal yield pressure rating of the 7" casing. Note 1: If necessary the surface casing setting depth will be adjusted and will be set above the Schrader Bluff if the gas hydrates are severe. If the drilling mud weights of 10.5 ppg or higher are required to control gas hydrates immediately contact the Drilling Superintendent before drilling ahead into the Schrader Bluff. Milne Point-Pad Well K-18 (Kup) Pg 1 2:06 PM 12/31/96 Shared Services Drilling Contact: Lance J. Spencer I Name: IMP K-18 Well Plan Summary 564-5042 I Type of Well (producer or injector): I Kuparuk Producer Surface Location: 3689 NSL 1998 WEL Sec. 03 T12N R11E UM., AK Kuparuk Target 4558 NSL 4136 WEL Sec. 01 T12N R11E UM., AK Location: Bottom Hole 4576 NSL 3960 WEL Sec. 01 T12N R11E UM., AK Location: I AFE Number: 1337056 I I Rig: I Nabors 27-E I 14 IMD' 112'734' ITVD: 17'357' Ibkb KBE: 60.9I Well Design (conventional, slimhole, I Milne Point Ultra Slimhole Longstring 9- etc.)'I 5/8", 40# Surface X 7", 26# Longstring Formation Markers: Formation Tops MD TVD (bkb) Pore Pressure (EMW,Psi) Base Permafrost 1863 1862 8.4 ppg, 813 psi NA 7404 461 2 8.4 ppg, 2014 psi CA 7 91 6 475 2 8.4 ppg, 2075 psi CB 8153 4817 8.4 ppg, 2154 psi BaseOB 8282 4852 8.4 ppg, 2169 psi T. opHRZ 11719 6482 8.6 ppg, 2899 psi Base HRZ 1 1 936 6 66 7 8.6 ppg, 2981 psi TKLB 12011 6732 9.0 ppg, 3151 psi TKUP/UD 12179 6877 9.9 ppg, 3540 psi TKC1/TARGET 12410 7077 9.9 ppg, 3643 psi TKB7 12479 7137 9.9 ppg, 3674 psi Total Depth _+12734 7357 9.9 ppg, 3801 psi Casinq/'rubing Pro! ram'. Hol~ C-sg/ 'Wt/Ft Grade Conn Length Top Btm Size Tb~] O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 1 12/1 1 2 12 1/4" 9-5/8" 40# L-80 btrc 7177 31/31 7207/4902 8-1/2" 7" 26# L-80 btrc 12704 30/30 12734/7357 The internal yield pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the Kup sand at _+ 7085 TVDSS In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of _+7085 TVDSS. The maximum anticipated surface pressure in this case is 2939 psi assuming a reservoir pressure of 3647 psi, well below the internal yield pressure rating of the 7" casing. Note 1: If necessary the surface casing setting depth will be adjusted and will be set above the Schrader Bluff if the gas hydrates are severe. If the drilling mud weights of 10.5 ppg or higher are required to control gas hydrates immediately contact the Drilling Superintendent before drilling ahead into the Schrader Bluff. Milne Point -Pad Well K-18 (Kup) Pg 1 2:11 PM 12/31/96 Logging Program: Open Hole Logs: Surface Intermediate Final Cased Hole Logs: Mud Logging None MWD Directional LWD (GR/EWR4/ROP) from surface to TD of surface hole. Real Time N/A MWD Directional from 9-5/8 shoe and LWD GR/EWR4/CNP/SLD/ROP) from surface shoe to TD. Real Time N/A Mud Loggers and samples are NOT required. MWD GR: EWR4: CNP: SLD: ROP: Directional: Inclination and Azimuth Gamma Ray Electromagnetic Wave Resistivity 4 (Four Depths of Investigation) Compensated Neutron Porosity Stabilized Litho Density Rate of penetration Mudloggers are NOT required for this well. Mud Program: Special design considerations Special attention should be given to, gravel, clay, hydrate, and coal intervals in the surface hole. Running gravel, sticky clays below the permafrost, gas gut mud due to hydrate formation, excessive fill on connections, tight coal sections and stuck pipe have been encountered in previous surface holes on K-Pad. Prior to spudding a complete review of the K-Pad drilling hazards is required. Preventative measures such as more frequent short trips, viscosity and mud weight control, Iow mud temperatures, controlled drilling rates, and lower flow rates should be employed to mitigate problems and lost time in the surface hole. HYDRATES Hydrates are present on K-Pad and must be managed safely. Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 100 1 5 8 1 0 9 8 to to to to to to to 10.2 or 50 35 15 30 10 15 less I LSND Production Mud Properties: I freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 10.5 50 1 5 1 0 20 9.5 4-5 Well Control' Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, ~l:~~r will be installed and is capable of handling maximum potential surface pressures. JAN 0 5 1997 Diverter, BOPE and drilling fluid system schematics on file with AOGCC. .Alaska 0il & Gas Cons. Commission Directional. Anchorage KOP: 1400' Maximum Hole Angle: 74.13° Close Approach Well: (No Shut Ins) All wells may remain flowing while drilling K-18. Milne Point -Pad Well K-18 (Kup) Pg 2 2:11 PM 12/31/96 Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluids Handling: All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations 1. The base of the Permafrost for all wells located in the Milne Point Unit is _+1,850' TVD. Aquifers in the Milne Point Unit have been exempted from Class !1 injection activities by the ~ by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 2. There are _+12 wells on Milne Pt. 'K' Pad. There may be additional unidentified wells within one quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. 3. The wastes to be disposed of during drilling operations can be defined as "DRILLING WASTES". 4. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. Milne Point-Pad Well K-18 (Kup) Pg 3 2:11 PM 12/31/96 MP K-18 (Kup) Proposed Summary of Operations , . Review Pre-Spud Checklist RP-Surface Hole VI.0 pages 1-3. prior to spud. Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5A Wellhead on conductor as well as a nipple to aid in performing potential wellhead stability cement job. Prepare location for rig move. 3. MIRU Nabors 27E drilling rig. Review RP-Surface Hole V1.0 pages 1-3. prior to spud. , NU and test 20" Diverter system. Ensure the diverter is as per AOGCCspecifications and is approved by an AOGCC supervisior. Build Spud Mud. o Drill a 12-1/4" surface hole as per directional plan. Advise Rig Team to proceed with Extreme Caution prior to and while drilling the hydrate interval. Run MWD-Directional and LWD-GR/EWR4/ROP from surface to 12-1/4" TD. Review RP-Surface Hole VI.0 pages 1-3. prior to spud . Run and cement 9-5/8" casing. Complete the surface casing cementing check list.' 7. ND.20" Diverter, NU and Test 13-5/8" BOP- . MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/EWR4/CNP/SLD/ROP). RIH, Drill out Float Equipment and 20' of new formation. Perform LO to a minimum of 12.5 ppg as per Recommended Practices Manual. Record pressure versus cumulative volume for LOT test for the well file. , Drill 8.5" hole to TD as per directional plan. Sufficient footage should be drilled leaving a minimum of 150' of production rat hole between the base of the Kuparuk Sand and PBTD. 10. Run and Cement 7" Casing. Insure that a short joint is run in the 7" casing approximately three joints above the top of the Kuparuk.. Displace cement with 8.4 ppg source water and enough diesel to cover from the base of permafrost to surface (+- 2 1 0 0' MD). 1 1. Test casing to 3500 psig. 12. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. Milne Point-Pad Well K-18 (Kup) Pg 4 2:11 PM 12/31/96 DRILLING HAZARDS AND RISKS: HYDRATES Every well on K-Pad to date has encountered hydrates while drilling the surface hole. Severly gas cut mud, excessive connection gas, flow on connections and other problems can occur while during the surface hole on K-Pad and are directly attributed to gas hydrates. In addition problems can develop as a result of measures designed to lessen to effects gas. It is important to recognize what problems might develop while fighting gas hydrates and have plans in place to mininimize them. Plans should be made in advance prior to spudding the surface hole to midigate to potential risks and minimize the nonproductive time involved in managing hydrates. The measures are necessary to lessen to effects of gas hydrates: Increased mud weights Low drilling fluid temperatures Reduced ROP's for control drill rates Controled ciriculating and drilling fuild rates Note: If necessary the surface casing setting depth will be adjusted and will be set above the Schrader Bluff if gas hydrates are severe. If the drilling mud weights of 10.5 ppg or higher are required to control gas hydrates immediately contact the Drilling Superintendent before drilling ahead into the Schrader Bluff. Close Approaches There are no close approaches associated with the drilling of MP K-18 however tolerance lines should be carefully monitored and deviations from the proposed wellpath minimized.. Water Injection Currently no water injection wells are present on MP K-Pad Annular Injection Annular injection is not permitted on K-Pad. A total of 19,608 bbls has be~n injected into the K- 17 annulus. Gas Injection Currently no gas injection wells are present on K-Pad Lost Circulation' K-05 experienced lost circulation while drilling the 12-1/4" surface hole at 2250 Md. K-02 K-05 experienced losses while circulating to condition mud while running 7" csg .K-0,~ experienced lost circulation while cementing 7" csg. In every instance losses were minimized by reducing flow rates and conditioning the mud. Stuck Pipe Potential; Running gravels (K-17, K-38), sticky clays (K-02, K-05, K-38, K-39) and coal sections(K- 17) presented tight hole and bridging in (K-17, K-25, K-38),and stuck pipe (K-17 ) while driling the 12 1-4" surface hole. Excessive amounts of reaming were required wile drilling K- 17 and K-25). While running 9-5/8" casing the flowing problems experienced: K-05, hole packing off, tight hole and bridging K-2, K-39. The 9-5/8" casing was stuck in K-05. These problems in some instances were greatly exagerated because of measures taken to manage the gas hydrate problems. Increased torque and drag have been experienced after drilling into Kuparuk so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Formation Pressure: KUPARUKSAND 7085' TVD 3600 PS! 9.9 PPG EMW The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the Kuparuk B7 sand at +_ 7085 TVDSS. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of +_7085 TVDSS. The maximum anticipated surface pressure is 2939 psi in this case assuming a reservoir pressure of 3647 psi,The maximum expected pore pressure for this well is 9.9 ppg EMW at the OWC - OIL WATER CONTACTis 3,647 psi @ 7085' TVDss. There has been injection in this region from MP K- 17, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point K-Pad Data Sheet prepared by Pete Van Dusen for information on K pad and review recent wells drilled on K Pad. Milne Point-Pad Well K-18 (Kup) Pg 5 2:11 PM 12/31/96 MP K-18 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON TWO STAGE CEMENT PROGRAM: ES Cementer located at 2002' MD (2000' TVDbkb). Casing Size: 9-5/8" Circ. Temp 60 deg F at 2840' TVDSS. First Stage: Lead and Tail slurries are pumped in the first stage. RECIPROCATION of the CASING STRING is required while cementing during the first stage. Incorporate FLOCELE "Cello-Flakes" in the First Stage Cement slurries. SPACER' 70 bbls NSCI weighted 1 ppg higher than current mud weight. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: 0.25#/sk Flocele WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.55 gal/sk APPROX NO SACKS: 945 THICKENING TIME: Greater than 4 hrs at 50° F. First Stage Lead Cement Volume = Interval 2002-7038' md The estimated first stage lead cement volume is equivalent to the annular volume calculated from the ES Cementer @ 2002' md to 7038 which is 100' Tvd above the Schrader NA Top at 7404' md+ TAIL CEMENT TYPE: ADDITIVES: 30% EXCESS. Premium G 2.0% CaCl2 +.15#/sk Flocele WEIGHT: 15.8 ppg JAN 0 ~ 1997 Alaska (:hl & Gas Cons. Commission YIELD:1.15 ft3/sx MIX V~t~~.0 gal/sk APPROX #SACKS: 523 THICKENING TIME: Greater than 4 hrs at 50° F. FLUID LOSS: 100-150 cc FREE WATER: 0 First StageTail Cement Volume= Interval 7038-8432' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from 100' TVD above the Schrader NA Top @ 7038'md to surface TD at 8432' md plus 30% Excess + the shoe joint volume. Second Stage: Lead and Tail slurries are also pumped in the-second stage. MAKE SURE THAT THE SECOND STAGE LEAD CEMENT IS CIRCULATED TO SURFACE BEFORE PUMPING SECND STAGE TAIL. The objective of the Second Stage of the cement program is to make sure cement is circulated to surface. Preparations should be made to continue pumping cement until such time as cement returns are observed at the surface. This volume will likely exceed the annular capacity and the 250% estimated excess. Additional cement should be on hand before the job starts so excess volume should be ordered. LEAD CEMENT TYPE' Type E Permafrost Second Stage Lead Cement Volume = MAKE SURE THAT THE SECOND STAGE LEAD CEMENT IS CIRCULATED TO SURFACE BEFORE PUMPING SECND STAGE TAIL. Milne Point -Pad Well K-18 (Kup) Pg 6 2:11 PM 12/31/96 The estimated second stage lead cement volume is equivalent to the annular volume calculated from the Base of the Permafrost located @ 1863' md to surface plus 250% excess. SPACER: 75 bbls Water LEAD CEMENTTYPE: Type E Permafrost ADDITIVES: None WEIGHT: APPROX NO SACKS: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.55 gal/sk 9 4 1 THICKENING TIME: Greater than 4 hrs at 50° F. Caution: Do not incorporate FLOCELE "Cello-Flakes" in the Second stage cement slurry. TAIL CEMENT TYPE: Permafrost C Second Stage Taft Cement Volume = 1863-2002' md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer @ 2002' md (2 0 0 0' Tvd)to the Base of the Permafrost located @ 1863' md plus 250% excess. SPACER: 75 bbls Water TAIL CEMENT TYPE: Type E ADDITIVES: None WEIGHT: Permafrost 15.6 ppg YIELD: 0.95 ft3/sx MIX WATER: 3.68 gal/sk 6 0 THICKENING TIME: Greater than 4 hrs at 50° F. APPROX NO SACKS: Caution: Do not incorporate FLOCELE "Cello-Flakes" in the Second stage cement slurry. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: The WELLHEAD STABILITY CEMENT WILL BE PUMPED IF THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. The wellhead stability cement volume is 150 sacks. It will be pumped if necessary to provide support to the wellhead MIX WATER: 11.63 gal/sk ADDITIVES: None WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx APPROX NO SACKS: 150 CENTRALIZER PLACEMENT: 1. Install one(l) Straight Blade TURBULATOR Centralizers per joint of 9-5/8" casing on bottom 10 joints of casing (required). 2. Install one(l) Straight Blade TURBULATOR Centralizers per joint of 9-5/8" casing on from 2000-2500 feet joints of casing (required). Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacedmud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. SURFACE CEMENT VOLUME: The objective of the Surface Cement is to insure that cement is circulated to surface. Cement shall be pumped until such time as cement is circulated to surface. Arrangements should be made to insure that sufficient cement is available so that continuous cementing can occur uninterrupted until cement is circulated to surface. Milne Point-Pad Well K-18 (Kup) Pg 7 2:11 PM 12/31/96 Dye shall be introduced into the weighted spacer before the first stage and into the water before the second stage in order to obtain an estimate of annular capacity to that additional cement can supplied if required and adequate excess has been pumped. Once an adequate volume of cement has been circulated to surface immediately begin displacement. The estimated for the float shoe is approximately 80' md of 9-5/8", 40#casing or two joints of casing. MP K-18 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON One STAGE I CEMENT JOB: From TD to 1000' above KUPARUK INTERVAL: CIRC. TEMP: 140° F SPACER: BHST 170° F at 7040' TVDSS. 20 bbls fresh water 70 bbls NSCI mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX # SACKS: FLUID LOSS: 0.2% CFR-3, 0.1% HR-5, 0.45% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER:_5.q gal/sk 269 SACKS THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: . . 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the from 120' below to 1 20' above any potential hydrocarbon bearing sands. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. -Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: o Single stage cement volume is calculated to cover 1000 FT MD above the highest potential KUPARUK(TKUPD) production sand + 30% excess. Milne Point-Pad Well K-18 (Kup) Pg 8 2:11 PM 12/31/96 FOR UDY ONLY . w~ 'o. O0 o. O0 . e'. DO o. OO -62.4~ ~P/~l~ ~/100 1~00. OO 0'. O0 ': O.OO l~O0. 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Well located proper distance from dflg unit boundaw .... 't 6. Well locaZed proper distance from o~er we~ ........ 7. Sufficient acreage a'caJlable in dri~ng unit. .......... 8. If deviated, is welibore plat included .............. 9. Operator only affected party .................. 10. Operator has appropriate bond in force ............ 11. Permit c~n be issued without conservation order ...... 12_ Permit c~n be issued without administrate approval .... 13. Can permit be approved before 15-day wait. ........ APPR --G~=OL.oGY ...... GEOLAREA N N N N N N N N N N N N 14. Conductor string provided .................. ,~ N 15. Surface ca, rig protects ali known USDWs ......... ~t,..~ N 16. CMT vol adequate to circulate on conductor & surf csg . . . 17. CMT vol adequate to lJeqn long s~'ing to surf ~ ...... 18. CMT will c=ver all known productive horizons. ........ ~ N 19. Casing designs adequate for C, T, B & ~ ..... ~.~ N 20. Adequate tankage or reserve pit. ............... ~ N 21. If a r~ddll, has a 10-403 for abndnmnt been approved .... 22. Adequate wellbore separation proposed ........... .(~ N 23. If diverter required, is it adequate ................ (.~ N 24. Drilling fluid program scherr~tic & equip list adequate .... ¢,.Y.) N 25. BOPEs adequate ........................ (~) N 26. BOPE press radng adequate; test to ..~--~ ~ psig.~ N 27. Choke ma.qifold complies w/APl RP-53 (May 84) ....... 28. Work will ocour wiU'~out operation shutdown .......... /(.~ N 29. Is presence of H2S gas probable .............. ~ N 30. Permit ca~ be issued w/o hydrogen sulfide measures ..... Y N~ ~,¢ J 31. Data. presented on potendal overpressure zones ....... Y/~ ~/"f..,"', ,~,, 32_ Seismic analysis of'shallow gas zones ............ ~ .N. 33. Seabed condition survey (if off-shore) .......... .,,/'.. Y N 34. Co~ name/phone for weekly progre..~ repo~,.../'... Y N Jexptoratory omyj GEOLOGY: ENGINEERING: COMMISSION: DWJ JDH ~ JDN TAB PROGRAM: exp [] de.~il~reddl [] serv [] wellbore seg [] ann. disposal para req Fl -'*-'?/~ O UNIT# //,~' 2¢¢ ON/OFF SHORE._~.~_. i i REMARKS 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 tl~is category of information. Sperry-Sun Drilling Services LIS Scan Utility Wed May 07 16:47:15 1997 Reel Header Service name ............. LISTPE Date ..................... 97/05/07 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/05/07 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-M~-70020 A. PIEPER P. WILSON 500292273300 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 07-MAY-97 MWD RUN 2 AK-MM-70020 G. TOBIAS P. WILSON MWD RUN 3 AK-MM-70020 G. TOBIAS P. WILSON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) MWD RUN 4 AK-M~-70020 G. TOBIAS J. PYRON 3 12N liE 3689 1998 KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .00 63.70 29.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 12.250 9.625 8883.0 8.500 12672.0 1. ALL DEPTHS ARE MEASURED DEPTHS(MD), UNLESS OTHERWISE NOTED. 2. WELL MPK-18, IS REPRESENTED BY RUNS 1, 2, 3, AND 4. 3. RUNS 1, 2, AND 3, ARE DIRECTIONAL WITH GAMMA RAY (DGR/SGRC), AND ELECTROMAGNETIC WAVE 4-PHASE RESISTIVITY(EWR4). 4. RUN 4 IS DIRECTIONAL WITH GAMMA RAY(SGRC), ELECTROMAGNETIC WAVE 4-PHASE RESISTIVITY(EWR4), COMPENSATED NEUTRON POROSITY(CNP/SPSF), AND STABILIZED LITHO-DENSITY(SLD/SBDC). 5. ALL GAMMA RAY DATA IS ACQUIRED WITH DUAL GAMMA RAY / GEIGER MUELLER TYPE DETECTORS AND IS DENOTED DGR/SGRC. 6. MPK-18, WAS DRILLED TO TOTAL DEPTH(TD) AT 12672' MD(7291' TVD), PRIOR TO BEING PLUGGED BACK TO 8925' MD(4986' TVD), AND SIDETRACKED. SROP: SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC: SMOOTHED GAMMA RAY COMBINED SEXP: SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY(EXTRA SHALLOW SPACING) SESP: SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY(SHALLOW SPACING) SEMP: SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY(MEDIUM SPACING) SEDP: SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY(DEEP SPACING) SFXE: SMOOTHED FORMATION EXPOSURE TIME(RESISTIVITY SENSOR) SFPE: SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR SBDC: SMOOTHED BULK DENSITY-COMPENSATED SCOR: SMOOTHED STAND OFF CORRECTION SPSF: SMOOTHED COMPENSATED NEUTRON POROSITY(SANDSTONE MATRIX-FIXED HOLE SIZE) SNNA: SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES SNFA: SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR LOG PROCESSING: HOLE SIZE: 8.5" MUD FILTRATE SALINITY: 700 ppm MUD WEIGHT: 9.2 - 10.2 ppg FORMATION WATER SALINITY: 14545 ppm FLUID DENSITY: 1.0 g/cc MATRIX DENSITY: 2.65 g/cc LITHOLOGY: S~qDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START GR 121 RPD 131 RPM 131 RPS 131.5 RPX 131.5 FET 177.0 ROP 178.0 FCNT 8768.5 NCNT -8768.5 NPHI 8768.5 DRHO 8871.0 RHOB 8871.0 PEF 8872.0 $ DEPTH .5 .5 .5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) GR 120.5 8829.0 8830.0 8849.0 8875.0 12672.0 BASELINE DEPTH 121 5 8830 0 8832 5 8848 0 887O 5 12667 5 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: STOP DEPTH 12600.0 12580.5 12580.5 12580.5 12580.5 12580.5 12667.0 12554.5 12554.5 12554.5 12589.0 12589.0 12589.5 EQUIVALENT UNSHIFTED DEPTH -- Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 1 177.0 4659.0 2 4659.0 8153.0 3 8153.0 8906.0 4 8906.0 12672.0 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD AAPI 4 1 68 ROP MWD FT/H 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 PEF MWD BARN 4 1 68 RHOB MWD G/CC 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CTS/ 4 1 68 FCNT MWD CTS/ 4 1 68 DRHO MWD G/CC 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean Nsam DEPT 121.5 12667 6394.25 25092 GR 11.6657 252.362 65.1183 24958 ROP 6.0629 847.403 182.614 24977 RPX 0.1572 2000 7.36983 24899 RPS -999.005 432.522 9.71016 24899 RPM 0.05 2000 17.6034 24899 RPD 0.0563 2000 16.0494 24899 FET -999.005 79.2461 1.22145 24808 PEF 1.6535 13.4826 2.56428 7436 RHOB 1.5167 3.0353 2.36189 7437 NPHI 17.3625 81.7622 43.0354 7573 NCNT 2108.74 3688 2640.01 7573 FCNT 404 939 608.916 7573 DRHO -0.223 0.376 0.0594073 7437 First Reading 121.5 121.5 178 131.5 131.5 131.5 131.5 177 8872 8871 8768.5 8768.5 8768.5 8871 Last Reading 12667 12600 12667 12580.5 12580.5 12580.5 12580.5 12580.5 12589.5 12589 12554.5 12554.5 12554.5 12589 First Reading For Entire File .......... 121.5 Last Reading For Entire File ........... 12667 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/07 Maximum Physical Records.65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE STAHRT DEPTH STOP DEPTH GR 120.5 4603.5 RPD 130.5 4613.0 RPM 130.5 4613.0 RPS 130.5 4613.0 RPX 130.5 4613.5 FET 176.0 4613.0 ROP 177.0 4659.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE A/ND 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): 28-JAN-97 ISC 4.96 CIM 5.46 MEMORY 4659.0 177.0 4659.0 .4 72.2 TOOL NUMBER P0628CGR8 P0628CGR8 12.250 12.3 SPUD 10.20 69.0 9.2 900 12.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.000 2.600 2.700 3.200 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHM~ 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 40.6 Name DEPT GR RPX RPS RPM RPD ROP FET Min 120.5 11 6657 0 1572 0 1658 0 1171 0 0563 9 7199 -999.005 First Max Mean Nsam Reading 4659.5 2390 9079 120.5 105.204 52.874 8967 120.5 153.627 13.9599 8967 130.5 432.522 20.7275 8966 130.5 2000 38.308 8966 130.5 2000 30.0971 8966 130.5 847.403 215.802 8966 177 6.1687 0.475579 8875 176 Last Reading 4659.5 4603.5 4613.5 4613 4613 4613 4659.5 4613 First Reading For Entire File .......... 120.5 Last Reading For Entire File ........... 4659.5 ~ile Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4600.0 8092.5 FET 4609.5 8102.5 RPD 4609.5 8102.5 RPM 4609.5 8102.5 RPS 4609.5 8102.5 RPX 4609.5 8102.5 ROP 4661.0 8153.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE ~qD CASING DATA OPEN HOLE BIT SIZE (IN): 31-JAN-97 ISC 4.96 CIM 5.46 MEMORY 8153.0 4659.0 8153.0 73.8 77.3 TOOL NUMBER P0628CGR8 P0628CGR8 12.250 DRILLER'S CASING DEPTH (FT) : 12.3 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHM14) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 SPUD 10.20 56.0 8.7 8OO 7.6 3.000 2.308 2.700 3.100 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 2 AAPI 4 1 RPX MWD 2 OHMM 4 1 RPS MWD 2 OHMM 4 1 RPM MWD 2 OHM~ 4 1 RPD MWD 2 OHMS4 4 1 ROP lV~D 2 FT/H 4 1 FET MWD 2 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 48.3 Name Min Max Mean DEPT 4600 8153 6376.5 GR 15.1012 99.9694 53.012 RPX 0.8716 34.7577 3.71933 R?S 0.887 51.2221 4.22522 RPM 0.9042 2000 9.54391 RPD 0.9377 2000 9.67308 ROP 6.0629 630.255 147.724 FET 0.1896 10.1082 0.949919 First Last Nsam Reading Reading 7107 4600 8153 6986 4600 8092.5 6987 4609.5 8102.5 6987 4609.5 8102.5 6987 4609.5 8102.5 6987 4609.5 8102.5 6985 4661 8153 6987 4609.5 8102.5 First Reading For Entire File .......... 4600 Last Reading For Entire File ........... 8153 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7984.5 8848.0 FET 7993.0 8858.5 RPD 7993.0 8858.5 RPM 7993.0 8858.5 RPS 7993.0 8858.5 RPX 7993.0 8858.5 ROP 8041.0 8906.0 $ LOG HEADER DATA DATE LOGGED: 01-FEB-97 SOFTWARE SURFACE SOFTWARE VERSION: ISC 4.96 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 8906.0 TOP LOG INTERVAL (FT) : 8153.0 BOTTOM LOG INTERVAL (FT): 8906.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 73.4 MAXIMUM ~GLE: 75.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMH) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: I~UD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER P0628CGR8 P0628CGR8 12.250 12.3 SPUD 10.20 70.0 8.9 7O0 7.2 2.700 2.508 1.800 2.900 42.8 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 RPX MWD 3 OHMM 4 1 68 8 3 RPS MWD 3 OHM>4 4 1 68 12 4 RPM MWD 3 OHMM 4 1 68 16 5 RPD MWD 3 OHMM 4 1 68 20 6 ROP MWD 3 FT/H 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8 First Last Name Min Max Mean Nsam DEPT 7984.5 8906 8445.25 1844 GR 32.3111 101.192 65.8931 1728 RPX 1.3761 16.0886 3.16014 1732 RPS 1.3805 19.1153 3.42659 1732 RPM 1.4176 20.1855 3.6815 1732 RPD 1.5206 15.8289 3.79794 1732 ROP 12.5932 1010.99 206.513 1731 FET 0.1761 18.0955 3.589 1732 Reading 7984.5 7984.5 7993 7993 7993 7993 8041 7993 Reading 8906 8848 8858.5 8858.5 8858.5 8858.5 8906 8858.5 First Reading For Entire File .......... 7984.5 Last Reading For Entire File ........... 8906 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUN/WARY VENDOR TOOL CODE FCNT NCNT NPHI RPD FET RPM RPS RPX GR DRHO RHOB PEF ROP 4 .5000 START DEPTH 8767 5 8767 5 8767 5 8791 5 8792 5 8792 5 8792 5 8792 5 8813 0 8875.5 8875.5 8876.5 8879.5 STOP DEPTH 12559 0 12559 0 12559 0 12585 0 12585 0 12585 0 12585.0 12585.0 12604.5 12593.5 12593.5 12594.0 12671.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABI. LITHO DENSITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined 07-FEB-97 ISC 4.96 CIM 5.46 MEMORY 12672.0 8906.0 12672.0 30.1 73.1 TOOL NUMBER P0639CRDGP6 P0639CRDGP6 P0639CRDGP6 P0639CRDGP6 8.500 8.5 PAC/GEL 10.20 54.0 9.4 700 4.8 2.300 1.506 1.500 2.500 60.6 Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEFT FT 4 1 68 GR MWD 4 AAPI 4 1 68 RPX MWD 4 OHM~ 4 1 68 RPS MWD 4 OHMM 4 1 68 RPM MWD 4 OHMM 4 1 68 RPD MWD 4 OHMM 4 1 68 NPHI MWD 4 P.U. 4 1 68 ROP MWD 4 FT/H 4 1 68 FET MWD 4 HOUR 4 1 68 FCNT MWD 4 CTS/ 4 1 68 NCNT MWD 4 CTS/ 4 1 68 RHOB MWD 4 G/CC 4 1 68 DRHO MWD 4 G/CC 4 1 68 PEF MWD 4 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean Nsam DEFT 8767.5 12671.5 10719.5 7809 GR 30.1792 252.362 90.1245 7584 RPX 1.0058 2000 3.68383 7586 RPS -999.005 17.0433 2.87036 7586 RPM 0.05 16.8848 3.07784 7586 RPD 0.2945 2000 18.3407 7588 NPHI 17.3625 81.7622 43.0611 7584 ROP 9.9035 643.359 183.712 7585 FET 0.3895 79.3357 3.58401 7586 FCNT 404 939 608.638 7584 NCNT 2108.74 3688 2639.58 7584 RHOB 1.5167 3.0353 2.36189 7437 DRHO -0.223 0.376 0.0594073 7437 PEF 1.6535 13.4826 2.56428 7436 First Reading 8767.5 8813 8792.5 8792.5 8792.5 8791.5 8767.5 8879.5 8792.5 8767.5 8767.5 8875.5 8875.5 8876.5 Last Reading 12671.5 12604.5 12585 12585 12585 12585 12559 12671.5 12585 12559 12559 12593.5 12593.5 12594 First Reading For Entire File .......... 8767.5 Last Reading For Entire File ........... 12671.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF T~pe Trailer Service name ............. LISTPE Date ..................... 97/05/07 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 97/05/07 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File