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Ima a Pro~ect Well History File Cov~Page g 1 XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. p`~Q~ - c~Q~ Well History File Identifier Organizing (done) RES N Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: gY: Maria Project Proofing gY: Maria ,~.,,~, iuuiummiiiii DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: Date: Date: Scanning Preparation BY: x30=~ Date: ~ Production Scanning R.w~~,~~ iuuiiiir~iium OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: o~. ~rnP ~miiniiiiiimuw~P ~O + ~ =TOTAL PAGES (Count does not include cover sheet)' ^ , /s/ IV V Stage 1 Page Count from Scanned File: f / ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: 3 `a / O /s/ Q I Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria .Date: /s/ IIII O III his Dint unless rescanning is required. III II I) II I Scanning is complete at t p anned III IIIIIIIIIII IIIII ReSc gY; Maria Date: Comments about this file: /s/ o~„~,~~=kea IIIIIIIIIIIIIIIII 10/6/2005 Well History File Cover Page.doc • • G. L. Alvord Allasska a Drilling Manager Drilling & Wells A.Bag Anchchorage, , AK AK 99510-0360 ConocoPhiflips Phone: 907 - 265 -6120 April 24, 2012 AOGCC APR 26 1012 Commissioner ,, �� � 333 W. 7 Ave, Suite 100 a Q U A0 Anchorage, Alaska 99501 Subject: Correction of Completion Reports for 2N -318A and 2N -305A Dear Commissioner: Attached are the corrected completion reports for 2N -318A and 2N -305A. We have recently received corrected directional surveys which requires changing a few depths on the completion reports. The corrected directional surveys are also attached. If you have any questions, please feel free to call me at anytime. Sincerely, G. L. Alvord Alaska Drilling Manager CPAI Drilling aAgeO AY 21112. GLA/skad xt aog��o� 0 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil Q Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ lb. Well Class: 20AAC 25.105 20AAC 25.110 Development 5 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: April 5, 2009 208 - 202 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 February 24, 2009 50 103 - 20349 - 01 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 6' FNL, 529' FEL, Sec. 3, T9N, RO7E, UM March 14, 2009 2N - 305A Top of Productive Horizon: 8. KB (ft above MSL): 160' RKB 15. Field /Pool(s): 2451' FSL, 614' FWL, Sec. 26, T1ON, R7E, UM GL (ft above MSL): 119' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + ND): 2548' FNL, 655' FWL, Sec. 26, T1ON, R7E, UM 10239' MD / 5440' TVD Tarn Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + ND): 16. Property Designation: Surface: x 461064 y 5912001 Zone 4 10335' MD / 5509' TVD ADL 375074, 380053 TPI: x - 462236 y - 5919731 Zone 4 11. SSSV Depth (MD + ND): 17. Land Use Permit: Total Depth: x 462278 y 5920012 Zone 4 nipple @ 489' MD / 488' TVD 4293, 4601 18. Directional Survey: Yes ❑ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1287' MD / 1249' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none 3130' MD / 2351' TVD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 41' 118' 41' 118' 24" 8 cu yds High Early 7.625" 29.7# L -80 41' 3026' 41' 2300' 9.875" 330 sx ASIII Lite, 240 sx Class G 5.5" 15.5# L -80 41' 9921' 41' 5212' 6.75" 616 sx Class G 3.5" 9.2# L -80 9696' 10335' 5058' 5509' 6.75" 110 sx Class G 24. Open to production or injection? Yes II No ❑ If Yes, list each 25. TUBING RECORD Interval open (MD +ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 9716' 9714' MD / 5092' TVD 10096 10105' MD 5337' - 5344' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10096 10105' 180194# 16/20 carbolite 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 20, 2009 gas lift oil Date of Test Hours Tested Production for OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GAS - OIL RATIO 4/25/2009 7.5 hours Test Period - -> 519 295 24 100% 821 Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 234 psi 825 24 -Hour Rate -> 1405 1154 76 not available 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 5 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. RECEIVED NONE APR 2 6 2012 RBDMS APR 2 6 2012 % ,,A ) AOGCC Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only S 1 4 -1z. - - ,J/ S c 28. 'GEOLOGIC MARKERS (List all formations and encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1287 1249 needed, and submit detailed test information per 20 AAC 25.071. T -3 9928' 5217' T -2 10131' 5363' N/A Formation at total depth: T -3 30. LIST OF ATTACHMENTS see original submittal 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name G. L. Alvord Title: Alaska Drilling Manager Signature 4 � 0 Phone 265 - 6120 Date 404 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 • • 5., $j0 - y i n Philli I k Inc. Co oco s A as a c Kuparuk River Unit Kuparuk 2N Pad 2N -305A 501032034901 bP Sperry Drilling Definitive Survey Report , 17 April, 2012 f< �, P * � e HALL[BURTON Sperry Drilling . • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 2N -305 Project: Kuparuk River Unit TVD Reference: 2N -305A @ 160.45ft (D15 (41.15 +119.3)) Site: Kuparuk 2N Pad MD Reference: 2N -305A @ 160.45ft (D15 (41.15 +119.3)) Well: 2N - 305 North Reference: True Wellbore: 2N - 305A Survey Calculation Method: Minimum Curvature Design: 2N -305A Database: CPAI EDM Production Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2N - 305 Well Position +N/-5 0.00 ft Northing: 5,912,000.60 ft Latitude: 70° 10' 13.902 N , +E/ -W 0.00 ft Easting: 461,063.88 ft Longitude: 150° 18' 48.111 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 119.30ft Wellbore 2N - 305A Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( °) (°) (nT) BGGM2007 2/16/2009 21.98 80.66 57,614 Design 2N - 305A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 2,989.77 Vertical Section: Depth From (TVD) +N/-S +E/ -W Direction (ft) (ft) (ft) (°) 41.15 0.00 0.00 0.00 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 212.33 2,989.77 2N -305 IIFR (2N -305) MWD +IFR -AK- CAZ -SC MWD +IFR AK CAZ SCC 6/13/2001 12:C 3,085.92 10,300.61 2N -305A (IFR Adjusted) (2N -305A) MWD +IFR -AK- CAZ -SC MWD +IFR AK CAZ SCC 3/9/2012 12:0C 1 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N /-S +E/ -W Northing Easting DLS Section (ft) (°) ( (ft) (ft) (ft) (ft) (ft) (ft) ( °11001 (ft) Survey Tool Name 41.15 0.00 0.00 41.15 - 119.30 0.00 0.00 5,912,000.60 461,063.88 0.00 0.00 UNDEFINED 212.33 0.56 101.99 212.33 51.88 -0.17 0.82 5,912,000.42 461,064.70 0.33 -0.17 MWD +IFR -AK- CAZ -SC (1) 242.71 0.54 86.86 242.71 82.26 -0.20 1.11 5,912,000.40 461,064.99 0.48 -0.20 MWD +IFR -AK- CAZ -SC (1) 280.22 0.61 73.11 280.21 119.76 -0.13 1.47 5,912,000.46 461,065.35 0.41 -0.13 MWD +IFR -AK- CAZ -SC (1) 311.65 1.02 48.30 311.64 151.19 0.11 1.84 5,912,000.70 461,065.72 1.69 0.11 MWD +IFR -AK- CAZ -SC (1) 342.51 1.92 26.26 342.49 182.04 0.75 2.28 5,912,001.34 461,066.16 3.39 0.75 MWD +IFR -AK- CAZ -SC (1) 372.76 3.15 19.24 372.71 212.26 1.99 2.77 5,912,002.58 461,066.67 4.19 1.99 MWD +IFR -AK- CAZ -SC (1) 403.47 4.54 13.87 403.35 242.90 3.97 3.34 5,912,004.55 461,067.24 4.67 3.97 MWD +IFR -AK- CAZ -SC (1) 433.85 5.35 10.68 433.62 273.17 6.53 3.90 5,912,007.11 461,067.81 2.81 6.53 MWD +IFR -AK- CAZ -SC (1) 463.63 6.39 6.62 463.24 302.79 9.54 4.34 5,912,010.11 461,068.27 3.76 9.54 MWD +IFR -AK- CAZ -SC (1) 494.01 7.68 4.07 493.39 332.94 13.24 4.68 5,912,013.82 461,068.63 4.37 13.24 MWD +IFR -AK- CAZ -SC (1) 524.78 8.95 4.32 523.84 363.39 17.68 5.01 5,912,018.25 461,068.98 4.13 17.68 MWD +IFR -AK- CAZ -SC (1) 554.96 9.67 6.63 553.62 393.17 22.54 5.48 5,912,023.11 461,069.47 2.69 22.54 MWD +IFR -AK- CAZ -SC (1) 4/17/2012 9:31:32AM Page 2 COMPASS 2003.16 Build 69 • 0 • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 2N-305 Project: Kuparuk River Unit TVD Reference: 2N -305A @ 160.45ft (D15 (41.15 +119.3)) Site: Kuparuk 2N Pad MD Reference: 2N -305A @ 160.45ft (D15 (41.15 +119.3)) Well: 2N - 305 North Reference: True Wellbore: 2N - 305A Survey Calculation Method: Minimum Curvature Design: 2N - 305A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/ -W Northing Easting DLS Section (ft) (°) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( °11001 (ft) Survey Tool Name 585.92 9.61 7.66 584.14 423.69 27.68 6.12 5,912,028.25 461,070.14 0.59 27.68 MWD +IFR -AK- CAZ -SC (1) 617.06 10.10 8.24 614.82 454.37 32.96 6.86 5,912,033.52 461,070.91 1.61 32.96 MWD +IFR -AK- CAZ -SC (1) 646.22 10.89 9.06 643.50 483.05 38.21 7.66 5,912,038.77 461,071.74 2.76 38.21 MWD +IFR -AK- CAZ -SC (1) 678.11 11.68 10.29 674.77 514.32 44.36 8.71 5,912,044.91 461,072.82 2.59 44.36 MWD +IFR -AK- CAZ -SC (1) 707.04 12.90 11.16 703.03 542.58 50.41 9.86 5,912,050.96 461,074.00 4.27 50.41 MWD +IFR -AK- CAZ -SC (1) 739.55 14.29 11.30 734.63 574.18 57.91 11.35 5,912,058.44 461,075.53 4.28 57.91 MWD +IFR -AK- CAZ -SC (1) 830.95 15.87 13.56 822.88 662.43 81.12 16.49 5,912,081.63 461,080.79 1.84 81.12 MWD +IFR -AK- CAZ -SC (1) 891.29 16.35 13.75 880.85 720.40 97.39 20.44 5,912,097.87 461,084.82 0.80 97.39 MWD +IFR -AK- CAZ -SC (1) 940.32 18.21 14.82 927.67 767.22 111.50 24.04 5,912,111.96 461,088.49 3.85 111.50 MWD +IFR -AK- CAZ -SC (1) 1,000.26 19.51 14.81 984.39 823.94 130.23 29.00 5,912,130.67 461,093.54 2.17 130.23 MWD +IFR -AK- CAZ -SC (1) 1,065.19 20.84 14.14 1,045.33 884.88 151.91 34.59 5,912,152.32 461,099.25 2.08 151.91 MWD +IFR -AK- CAZ -SC (1) 1,128.38 22.08 13.13 1,104.14 943.69 174.38 40.03 5,912,174.76 461,104.81 2.05 174.38 MWD +IFR -AK- CAZ -SC (1) 1,197.35 24.83 12.23 1,167.41 1,006.96 201.16 46.05 5,912,201.50 461,110.96 4.02 201.16 MWD +IFR -AK- CAZ -SC (1) 1,286.31 28.04 11.71 1,247.06 1,086.61 239.90 54.25 5,912,240.20 461,119.36 3.62 239.90 MWD +IFR -AK- CAZ -SC (1) 1,349.73 29.21 11.73 1,302.72 1,142.27 269.65 60.42 5,912,269.91 461,125.68 1.84 269.65 MWD +IFR -AK- CAZ -SC (1) 1,381.28 30.65 11.54 1,330.07 1,169.62 285.07 63.60 5,912,285.31 461,128.94 4.57 285.07 MWD +IFR -AK- CAZ -SC (1) 1,444.28 32.54 10.38 1,383.73 1,223.28 317.47 69.86 5,912,317.68 461,135.37 3.15 317.47 MWD +IFR -AK- CAZ -SC (1) 1,507.69 34.94 10.03 1,436.45 1,276.00 352.13 76.10 5,912,352.30 461,141.78 3.80 352.13 MWD +IFR -AK- CAZ -SC (1) 1,571.07 38.10 9.73 1,487.38 1,326.93 389.29 82.57 5,912,389.42 461,148.44 4.99 389.29 MWD +IFR -AK- CAZ -SC (1) 1,634.09 40.48 8.91 1,536.15 1,375.70 428.66 89.02 5,912,428.76 461,155.10 3.87 428.66 MWD +IFR -AK- CAZ -SC (1) 1,697.49 42.54 8.33 1,583.63 1,423.18 470.21 95.31 5,912,470.26 461,161.60 3.31 470.21 MWD +IFR -AK- CAZ -SC (1) 1,760.30 44.46 8.25 1,629.18 1,468.73 512.99 101.55 5,912,513.01 461,168.05 3.06 512.99 MWD+IFR- AK- CAZ -SC (1) 1,823.41 45.64 8.44 1,673.77 1,513.32 557.18 108.03 5,912,557.16 461,174.76 1.88 557.18 MWD +IFR -AK- CAZ -SC (1) 1,886.25 47.44 8.35 1,716.99 1,556.54 602.30 114.69 5,912,602.24 461,181.65 2.87 602.30 MWD +IFR -AK- CAZ -SC (1) 1,952.21 49.22 7.67 1,760.84 1,600.39 651.09 121.55 5,912,650.99 461,188.77 2.81 651.09 MWD +IFR -AK- CAZ -SC (1) 2,013.13 51.33 7.16 1,799.78 1,639.33 697.55 127.59 5,912,697.42 461,195.05 3.52 697.55 MWD +IFR -AK- CAZ -SC (1) 2,076.52 53.68 6.94 1,838.36 1,677.91 747.46 133.76 5,912,747.29 461,201.47 3.72 747.46 MWD +IFR -AK- CAZ -SC (1) 2,139.95 55.90 7.13 1,874.93 1,714.48 798.89 140.11 5,912,798.68 461,208.09 3.51 798.89 MWD +IFR -AK- CAZ -SC (1) 2,203.51 57.67 6.30 1,909.74 1,749.29 851.70 146.33 5,912,851.45 461,214.57 2.99 851.70 MWD +IFR -AK- CAZ -SC (1) 2,266.46 59.09 7.27 1,942.75 1,782.30 904.93 152.66 5,912,904.64 461,221.18 2.61 904.93 MWD +IFR -AK- CAZ -SC (1) 2,328.83 60.64 6.70 1,974.06 1,813.61 958.46 159.22 5,912,958.14 461,228.01 2.61 958.46 MWD +IFR -AK- CAZ -SC (1) 2,392.25 61.13 6.73 2,004.92 1,844.47 1,013.49 165.70 5,913,013.13 461,234.77 0.77 1,013.49 MWD +IFR -AK- CAZ -SC (1) 2,455.33 61.81 5.68 2,035.05 1,874.60 1,068.59 171.69 5,913,068.18 461,241.04 1.82 1,068.59 MWD +IFR -AK- CAZ -SC (1) 2,518.48 61.88 5.68 2,064.84 1,904.39 1,123.99 177.20 5,913,123.55 461,246.84 0.11 1,123.99 MWD +IFR -AK- CAZ -SC (1) 2,582.63 62.58 5.70 2,094.73 1,934.28 1,180.47 182.82 5,913,180.00 461,252.76 1.09 1,180.47 MWD +IFR -AK- CAZ -SC (1) 2,646.20 62.75 6.20 2,123.92 1,963.47 1,236.64 188.68 5,913,236.13 461,258.90 0.75 1,236.64 MWD +IFR -AK- CAZ -SC (1) 2,709.41 62.66 5.55 2,152.91 1,992.46 1,292.51 194.43 5,913,291.97 461,264.94 0.92 1,292.51 MWD +IFR -AK- CAZ -SC (1) 2,772.71 62.78 6.23 2,181.92 2,021.47 1,348.48 200.20 5,913,347.90 461,271.00 0.97 1,348.48 MWD +IFR -AK- CAZ -SC (1) 2,835.93 62.62 6.23 2,210.92 2,050.47 1,404.32 206.30 5,913,403.71 461,277.38 0.25 1,404.32 MWD +IFR -AK- CAZ -SC (1) 2,899.05 62.36 6.04 2,240.07 2,079.62 1,459.99 212.28 5,913,459.33 461,283.65 0.49 1,459.99 MWD +IFR -AK- CAZ -SC (1) 4/17/2012 9:31:32AM Page 3 COMPASS 2003.16 Build 69 • 0 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 2N -305 Project: Kuparuk River Unit TVD Reference: 2N -305A @ 160.45ft (D15 (41.15 +119.3)) Site: Kuparuk 2N Pad MD Reference: 2N -305A © 160.45ft (D15 (41.15 +119.3)) Well: 2N - 305 North Reference: True Welibore: 2N - 305A Survey Calculation Method: Minimum Curvature Design: 2N - 305A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +NI -S +EI -W Northing Easting DLS Section (ft) ( (°) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 2,989.77 62.25 6.83 2,282.24 2,121.79 1,539.81 221.28 5,913,539.10 461,293.06 0.78 1,539.81 MWD +IFR -AK- CAZ -SC (1) 3,085.92 60.50 5.87 2,328.30 2,167.85 1,623.68 230.62 5,913,622.91 461,302.83 2.02 1,623.68 MWD +IFR -AK- CAZ -SC (2) 3,130.45 58.31 5.08 2,350.96 2,190.51 1,661.83 234.28 5,913,661.04 461,306.69 5.15 1,661.83 MWD +IFR -AK- CAZ -SC (2) 3,166.02 59.33 6.31 2,369.38 2,208.93 1,692.11 237.30 5,913,691.30 461,309.86 4.12 1,692.11 MWD +IFR -AK- CAZ -SC (2) 3,259.85 63.10 9.68 2,414.56 2,254.11 1,773.51 248.78 5,913,772.63 461,321.76 5.10 1,773.51 MWD +IFR -AK- CAZ -SC (2) 3,354.00 65.35 12.30 2,455.51 2,295.06 1,856.72 264.96 5,913,855.75 461,338.36 3.46 1,856.72 MWD +IFR -AK- CAZ -SC (2) 3,449.38 67.10 6.55 2,493.98 2,333.53 1,942.78 279.22 5,913,941.73 461,353.06 5.81 1,942.78 MWD +IFR -AK- CAZ -SC (2) 3,499.06 66.62 8.66 2,513.51 2,353.06 1,988.06 285.26 5,913,986.97 461,359.34 4.02 1,988.06 MWD +IFR -AK- CAZ -SC (2) 3,543.02 66.45 8.76 2,531.01 2,370.56 2,027.92 291.37 5,914,026.79 461,365.65 0.44 2,027.92 MWD +IFR -AK- CAZ -SC (2) 3,637.00 66.30 6.81 2,568.68 2,408.23 2,113.22 303.03 5,914,112.03 461,377.75 1.91 2,113.22 MWD +IFR -AK- CAZ -SC (2) 3,732.63 65.94 8.07 2,607.39 2,446.94 2,199.93 314.35 5,914,198.67 461,389.51 1.26 2,199.93 MWD +IFR -AK- CAZ -SC (2) 3,826.56 66.01 8.30 2,645.63 2,485.18 2,284.85 326.56 5,914,283.51 461,402.16 0.24 2,284.85 MWD +IFR -AK- CAZ -SC (2) I 3,921.07 66.90 10.45 2,683.39 2,522.94 2,370.32 340.68 5,914,368.91 461,416.72 2.29 2,370.32 MWD +IFR -AK- CAZ -SC (2) 4,015.51 67.07 12.25 2,720.32 2,559.87 2,455.54 357.79 5,914,454.03 461,434.26 1.76 2,455.54 MWD +IFR -AK- CAZ -SC (2) 4,110.17 67.01 11.72 2,757.24 2,596.79 2,540.80 375.89 5,914,539.18 461,452.80 0.52 2,540.80 MWD +IFR -AK- CAZ -SC (2) 4,203.74 67.65 9.79 2,793.31 2,632.86 2,625.62 392.00 5,914,623.91 461,469.34 2.02 2,625.62 MWD +IFR -AK- CAZ -SC (2) 4,298.46 66.06 9.22 2,830.54 2,670.09 2,711.52 406.38 5,914,709.72 461,484.16 1.77 2,711.52 MWD +IFR -AK- CAZ -SC (2) 4,391.75 66.20 8.58 2,868.29 2,707.84 2,795.80 419.58 5,914,793.93 461,497.79 0.65 2,795.80 MWD +IFR -AK- CAZ -SC (2) 4,486.66 66.90 8.75 2,906.06 2,745.61 2,881.88 432.70 5,914,879.93 461,511.35 0.76 2,881.88 MWD +IFR -AK- CAZ -SC (2) 4,581.70 66.76 8.04 2,943.46 2,783.01 2,968.31 445.45 5,914,966.29 461,524.55 0.70 2,968.31 MWD +IFR -AK- CAZ -SC (2) 4,676.17 65.72 7.01 2,981.52 2,821.07 3,054.03 456.78 5,915,051.94 461,536.32 1.49 3,054.03 MWD +IFR -AK- CAZ -SC (2) 4,770.72 66.00 7.27 3,020.19 2,859.74 3,139.64 467.50 5,915,137.49 461,547.48 0.39 3,139.64 MWD +IFR -AK- CAZ -SC (2) 4,864.42 65.86 7.31 3,058.40 2,897.95 3,224.50 478.36 5,915,222.28 461,558.77 0.15 3,224.50 MWD +IFR -AK- CAZ -SC (2) 4,958.59 67.02 7.19 3,096.04 2,935.59 3,310.13 489.25 5,915,307.85 461,570.11 1.24 3,310.13 MWD +IFR -AK- CAZ -SC (2) 5,053.04 66.14 7.46 3,133.58 2,973.13 3,396.09 500.30 5,915,393.74 461,581.60 0.97 3,396.09 MWD +IFR -AK- CAZ -SC (2) 5,148.29 66.56 7.01 3,171.79 3,011.34 3,482.65 511.29 5,915,480.23 461,593.03 0.62 3,482.65 MWD +IFR -AK- CAZ -SC (2) 5,241.79 66.96 6.12 3,208.69 3,048.24 3,568.00 521.11 5,915,565.52 461,603.29 0.97 3,568.00 MWD +IFR -AK- CAZ -SC (2) 5,335.51 66.34 6.82 3,245.83 3,085.38 3,653.49 530.80 5,915,650.95 461,613.42 0.95 3,653.49 MWD +IFR -AK- CAZ -SC (2) 5,430.95 66.21 7.67 3,284.23 3,123.78 3,740.17 541.82 5,915,737.56 461,624.88 0.83 3,740.17 MWD +IFR -AK- CAZ -SC (2) 5,526.15 66.19 6.89 3,322.65 3,162.20 3,826.57 552.86 5,915,823.90 461,636.37 0.75 3,826.57 MWD +IFR -AK- CAZ -SC (2) 5,619.39 65.74 6.73 3,360.63 3,200.18 3,911.12 562.96 5,915,908.39 461,646.90 0.51 3,911.12 MWD +IFR -AK- CAZ -SC (2) 5,714.43 65.48 7.71 3,399.87 3,239.42 3,996.99 573.84 5,915,994.20 461,658.22 0.98 3,996.99 MWD +IFR -AK- CAZ -SC (2) 5,808.90 65.61 8.46 3,438.98 3,278.53 4,082.13 585.93 5,916,079.26 461,670.75 0.74 4,082.13 MWD +IFR -AK- CAZ -SC (2) 5,902.91 65.46 8.61 3,477.92 3,317.47 4,166.75 598.63 5,916,163.81 461,683.88 0.22 4,166.75 MWD +IFR -AK- CAZ -SC (2) 5,995.83 66.75 11.08 3,515.56 3,355.11 4,250.45 613.16 5,916,247.42 461,698.84 2.80 4,250.45 MWD +IFR -AK- CAZ -SC (2) 6,091.10 66.33 10.37 3,553.49 3,393.04 4,336.31 629.43 5,916,333.19 461,715.55 0.81 4,336.31 MWD +IFR -AK- CAZ -SC (2) 6,185.40 66.91 9.15 3,590.91 3,430.46 4,421.62 644.10 5,916,418.41 461,730.65 1.34 4,421.62 MWD +IFR -AK- CAZ -SC (2) 6,280.07 66.05 7.34 3,628.69 3,468.24 4,507.52 656.55 5,916,504.24 461,743.55 1.97 4,507.52 MWD +IFR -AK- CAZ -SC (2) 6,374.95 66.17 7.32 3,667.11 3,506.66 4,593.56 667.62 5,916,590.21 461,755.06 0.13 4,593.56 MWD +IFR -AK- CAZ -SC (2) 6,469.86 66.63 6.67 3,705.11 3,544.66 4,679.88 678.21 5,916,676.47 461,766.09 0.79 4,679.88 MWD +IFR -AK- CAZ -SC (2) 4/17/2012 9:31:32AM Page 4 COMPASS 2003.16 Build 69 ` +0 • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 2N -305 Project: Kuparuk River Unit TVD Reference: 2N -305A @ 160.45ft (D15 (41.15 +119.3)) Site: Kuparuk 2N Pad MD Reference: 2N -305A @ 160.45ft (D15 (41.15 +119.3)) Well: 2N - 305 North Reference: True Welibore: 2N - 305A Survey Calculation Method: Minimum Curvature Design: 2N - 305A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N / -S +Ei -W Northing Fasting DLS Section (ft) (1 ( °) (ft) (ft) (ft) (ft) (ft) (ft) (1100') (ft) Survey Tool Name 6,564.45 66.06 6.93 3,743.06 3,582.61 4,765.92 688.47 5,916,762.44 461,776.79 0.65 4,765.92 MWD +IFR -AK- CAZ -SC (2) 6,658.00 66.29 6.60 3,780.85 3,620.40 4,850.90 698.55 5,916,847.36 461,787.31 0.41 4,850.90 MWD +IFR -AK- CAZ -SC (2) 6,752.62 66.83 6.53 3,818.49 3,658.04 4,937.14 708.47 5,916,933.55 461,797.67 0.57 4,937.14 MWD +IFR -AK- CAZ -SC (2) 6,846.69 66.81 6.86 3,855.52 3,695.07 5,023.03 718.56 5,917,019.37 461,808.20 0.32 5,023.03 MWD +IFR -AK- CAZ -SC (2) 6,941.35 66.40 8.06 3,893.11 3,732.66 5,109.17 729.83 5,917,105.44 461,819.92 1.24 5,109.17 MWD +IFR -AK- CAZ -SC (2) 7,036.40 66.26 8.83 3,931.27 3,770.82 5,195.28 742.62 5,917,191.48 461,833.14 0.76 5,195.28 MWD +IFR -AK- CAZ -SC (2) 7,130.62 66.29 9.90 3,969.18 3,808.73 5,280.38 756.65 5,917,276.50 461,847.61 1.04 5,280.38 MWD +IFR -AK- CAZ -SC (2) 7,224.19 67.22 8.64 4,006.11 3,845.66 5,365.23 770.50 5,917,361.27 461,861.90 1.59 5,365.23 MWD +IFR -AK- CAZ -SC (2) 7,319.15 66.63 7.58 4,043.33 3,882.88 5,451.72 782.83 5,917,447.68 461,874.66 1.20 5,451.72 MWD +IFR -AK- CAZ -SC (2) 7,413.00 66.07 8.70 4,080.97 3,920.52 5,536.82 795.00 5,917,532.71 461,887.27 1.25 5,536.82 MWD +IFR -AK- CAZ -SC (2) 7,507.77 66.75 8.47 4,118.90 3,958.45 5,622.69 807.96 5,917,618.51 461,900.68 0.75 5,622.69 MWD +IFR -AK- CAZ -SC (2) 7,602.82 65.96 9.35 4,157.02 3,996.57 5,708.71 821.44 5,917,704.45 461,914.60 1.19 5,708.71 MWD +IFR -AK- CAZ -SC (2) 7,697.90 66.08 9.46 4,195.66 4,035.21 5,794.42 835.64 5,917,790.07 461,929.24 0.16 5,794.42 MWD +IFR -AK- CAZ -SC (2) 7,792.36 65.88 8.78 4,234.12 4,073.67 5,879.61 849.32 5,917,875.18 461,943.35 0.69 5,879.61 MWD +IFR -AK- CAZ -SC (2) 7,886.55 65.45 8.11 4,272.93 4,112.48 5,964.50 861.92 5,917,960.00 461,956.39 0.79 5,964.50 MWD +IFR -AK- CAZ -SC (2) 7,980.40 65.38 8.18 4,311.97 4,151.52 6,048.98 874.01 5,918,044.41 461,968.91 0.10 6,048.98 MWD +IFR -AK- CAZ -SC (2) 8,075.40 65.94 8.34 4,351.13 4,190.68 6,134.64 886.45 5,918,129.99 461,981.79 0.61 6,134.64 MWD +IFR -AK- CAZ -SC (2) 8,168.69 66.75 10.90 4,388.56 4,228.11 6,218.87 900.73 5,918,214.15 461,996.50 2.66 6,218.87 MWD +IFR -AK- CAZ -SC (2) 8,263.15 66.14 10.54 4,426.31 4,265.86 6,303.95 916.84 5,918,299.13 462,013.05 0.73 6,303.95 MWD +IFR -AK- CAZ -SC (2) 8,357.49 66.56 10.60 4,464.16 4,303.71 6,388.90 932.69 5,918,383.99 462,029.33 0.45 6,388.90 MWD +IFR -AK- CAZ -SC (2) 8,451.83 66.95 9.26 4,501.39 4,340.94 6,474.28 947.64 5,918,469.29 462,044.72 1.37 6,474.28 MWD +IFR -AK- CAZ -SC (2) 8,546.01 65.99 5.34 4,539.00 4,378.55 6,559.91 958.61 5,918,554.84 462,056.14 3.95 6,559.91 MWD +IFR -AK- CAZ -SC (2) 8,640.10 65.74 5.74 4,577.47 4,417.02 6,645.37 966.90 5,918,640.26 462,064.86 0.47 6,645.37 MWD +IFR -AK- CAZ -SC (2) 8,735.08 65.86 7.16 4,616.41 4,455.96 6,731.45 976.64 5,918,726.28 462,075.04 1.37 6,731.45 MWD +IFR -AK- CAZ -SC (2) 8,827.86 65.34 8.10 4,654.74 4,494.29 6,815.20 987.85 5,918,809.95 462,086.68 1.08 6,815.20 MWD +IFR -AK- CAZ -SC (2) 8,923.39 64.94 9.30 4,694.90 4,534.45 6,900.88 1,000.96 5,918,895.56 462,100.23 1.21 6,900.88 MWD +IFR -AK- CAZ -SC (2) 9,018.46 65.47 9.84 4,734.77 4,574.32 6,985.98 1,015.31 5,918,980.58 462,115.02 0.76 6,985.98 MWD +IFR -AK- CAZ -SC (2) 9,112.10 66.37 9.44 4,772.98 4,612.53 7,070.26 1,029.63 5,919,064.78 462,129.77 1.04 7,070.26 MWD +IFR -AK- CAZ -SC (2) 9,207.25 66.48 8.68 4,811.03 4,650.58 7,156.38 1,043.36 5,919,150.82 462,143.94 0.74 7,156.38 MWD +IFR -AK- CAZ -SC (2) 9,300.90 64.44 7.81 4,849.93 4,689.48 7,240.69 1,055.58 5,919,235.05 462,156.59 2.34 7,240.69 MWD +IFR -AK- CAZ -SC (2) 9,395.55 62.99 7.65 4,891.84 4,731.39 7,324.78 1,067.00 5,919,319.07 462,168.44 1.54 7,324.78 MWD +IFR -AK- CAZ -SC (2) 9,490.13 58.57 7.43 4,938.00 4,777.55 7,406.59 1,077.83 5,919,400.82 462,179.69 4.68 7,406.59 MWD +IFR -AK- CAZ -SC (2) 9,584.88 54.64 10.77 4,990.15 4,829.70 7,484.67 1,090.28 5,919,478.83 462,192.55 5.08 7,484.67 MWD +IFR -AK- CAZ -SC (2) 9,629.88 53.01 10.68 5,016.71 4,856.26 7,520.36 1,097.04 5,919,514.48 462,199.49 3.63 7,520.36 MWD +IFR -AK- CAZ -SC (2) 9,678.61 51.06 9.90 5,046.69 4,886.24 7,558.16 1,103.91 5,919,552.24 462,206.55 4.20 7,558.16 MWD +IFR -AK- CAZ -SC (2) 9,747.71 47.70 8.95 5,091.67 4,931.22 7,609.89 1,112.51 5,919,603.92 462,215.41 4.97 7,609.89 MWD +IFR -AK- CAZ -SC (2) 9,841.95 45.36 8.84 5,156.50 4,996.05 7,677.46 1,123.08 5,919,671.42 462,226.33 2.48 7,677.46 MWD +IFR -AK- CAZ -SC (2) 9,937.86 44.52 8.62 5,224.39 5,063.94 7,744.42 1,133.36 5,919,738.32 462,236.96 0.89 7,744.42 MWD +IFR -AK- CAZ -SC (2) 10,031.07 44.23 8.41 5,291.01 5,130.56 7,808.89 1,143.02 5,919,802.73 462,246.94 0.35 7,808.89 MWD +IFR -AK- CAZ -SC (2) 10,064.84 44.01 8.46 5,315.26 5,154.81 7,832.14 1,146.47 5,919,825.97 462,250.51 0.66 7,832.14 MWD +IFR -AK- CAZ -SC (2) 4/17/2012 9:31:32AM Page 5 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 2N-305 Project: Kuparuk River Unit TVD Reference: 2N -305A @ 160.45ft (D15 (41.15 +119.3)) Site: Kuparuk 2N Pad MD Reference: 2N -305A @ 160.45ft (D15 (41.15 +119.3)) Well: 2N - 305 North Reference: True Wellbore: 2N - 305A Survey Calculation Method: Minimum Curvature Design: 2N - 305A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N / -S +Ei -W Northing Easting DLS Section (ft) (1 (1 (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 10,159.61 44.02 8.94 5,383.41 5,222.96 7,897.23 1,156.43 5,919,891.00 462,260.81 0.35 7,897.23 MWD +IFR -AK- CAZ -SC (2) 10,192.04 43.83 8.59 5,406.77 5,246.32 7,919.47 1,159.85 5,919,913.22 462,264.35 0.95 7,919.47 MWD +IFR -AK- CAZ -SC (2) 10,286.16 44.81 7.50 5,474.11 5,313.66 7,984.58 1,169.05 5,919,978.27 462,273.88 1.32 7,984.58 MWD +IFR -AK- CAZ -SC (2) 10,300.61 44.85 6.81 5,484.35 5,323.90 7,994.68 1,170.32 5,919,988.37 462,275.20 3.38 7,994.68 MWD +IFR -AK- CAZ -SC (2) 10,335.00 44.85 6.81 5,508.74 5,348.29 8,018.77 1,173.20 5,920,012.44 462,278.20 0.00 8,018.77 PROJECTED to TD 4/17/2012 9:31:32AM Page 6 COMPASS 2003.16 Build 69 DATA SUBMITTAL COMPLIANCE REPORT 3/15/2010 Permit to Drill 2082020 Well Name/No. KUPARUK RIV U TARN 2N-305A Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20349-01-00 MD 10335 TVD 5509 Completion Date 4/3/2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATIDN Types Electric or Other Logs Run: GR / RES, NEU /DEN (data taken from Logs Portion of Master Well Data Maint Well Log Information: S Log/ Electr Data Digital Dataset Log Log Run Interval OH / gyp meairrmi IYUIIIUCI name JI.GIC nIC41q ryV JCdR JIU~ Vfl ReliC1VCU <rV111111C11W pt Report: Final Well R Open 4/6/2009 End of Well Report, Tab of 1 Cont, Equip & Crew, Well Data, Geo Data, Drill Data, Daily Reps D C 17786 Report: Final Well R Open 4/6/2009 End of Well Report, Tab of Cont, Equip & Crew, Well Data, Geo Data, Drill Data, Daily Reps with mud logs in PDS graphics og Mud Log 2 Col 2925 10335 Open 4/6/2009 MD Formation Log Log Mud Log 2 CoI 2925 5510 Open 4/6/2009 ND Formation Log Log Mud Log 2 Col 2925 10335 Open 4/6/2009 MD LWD Combo log Log Mud Log 2 Col 2925 5510 Open 4/6/2009 TVD LWD Combo Log og Mud Log 2 Col 2925 10335 Open 4/6/2009 MD Gas Ratio og Mud Log 2 Col 2925 5510 Open 4/6/2009 TVD Gas Ratio og Mud Log 2 Col 2925 10335 Open 4/6/2009 MD Drilling Dynamics og Mud Log 2 Col 2925 5510 Open 4/6/2009 TVD Drilling Dynamics og Mud Log 2 Col 2925 10335 Open 4/6/2009 MD FIT Gas Log pt LIS Verification 3072 10335 Open 4/23/2009 LIS Veri, GR, RPD, RPS, RPM, RPX, ROP, FET C Lis 17913~duction/Resistivity 3072 10335 Open 4/23/2009 LIS Veri, GR, RPD, RPS, RPM, RPX, ROP, FET DATA SUBMITTAL COMPLIANCE REPORT 3/15/2010 Permit to Drill 2082020 Well Name/No. KUPARUK RIV U TARN 2N-305A Operator CONOCOPHILLIPS ALASKA INC MD 10335 TVD 5509 Completion Date 4!3!2009 Completion Status 1-OIL Current Status 1-OIL API No. 50-103-20349-01-00 UIC N D C 17914~uction/Resistivity 3130 10335 Open 4/23/2009 EWR Logs in PDS, CGM ' and EMF graphics og Induction/Resistivity 25 Col 3130 10335 Open 4/23/2009 MD ROP, EWR, DGR 16- Mar-2009 Log Induction/Resistivity 25 Col 3130 5508 Open 4/23/2009 TVD EWR, DGR 16-Mar- i 2009 ~ -- Well CoresJSamples Information: Name ADDITIONAL INFORMA~TI~ON Well Cored? Y Chips Received? .X-f#-- Analysis Y'71~- Received? Comments: Compliance Reviewed By: Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Formation Tops Y / N Date: ~ ~ ~~~ ~ ~ C ConocoPhillips April 28, 2009 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2N-305A Dear Commissioner: G. L. Alvord Alaska Drilling Manager Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 APR ~ ~ 2~Q~ Alaska Oi0 has r~anso ~ot~ission Anchorage ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Kuparuk well 2N-305A. If you have any questions regarding this matter, please contact me at 265-6120 or Mike Greener at 263-4820. Sincerely, /~ ~. ~,~ G. L. Alvord Alaska Drilling Manager CPAI Drilling GLA/skad ~-tea STATE OF ALASKA ~ APR 2 8 2009 ALASKA OIL AND GAS CONSERVATION COMMISSIOI~~~ska Oil & Gas Cons. Commissiof: WELL COMPLETION OR RECOMPLETION REPORT AM,~hdr~G 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development ^/ Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. C} 5. Date Comp., Susp., Q p~r~ ~~ ~ ~.~`~ l orAband.: ~~ 7April , 2009 12. Permit to Drill Number: 208-202 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: February 24, 2009 ~ 13. API Number: 50-103-20349-01 4a. Location of Well (Governmental Section): Surface: 6' FNL, 529' FEL, Sec. 3, T9N, R7E, UM ° 7. Date TD Reached: March 14, 2009 14. Well Name and Number: 2N-305A • Top of Productive Horizon: 2448' FSL, 639' FWL, Sec. 26, T10N, R7E, UM 8. KB (ft above MSL): 160' RKB Ground (ft MSL): 119' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 2551' FNL, 681' FWL, Sec. 26, T10N, R7E, UM 9. Plug Back Depth (MD + ND): 10239' MD / 5440' ND Tarn Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 461064: y- 5912001 Zone- 4 10. Total Depth (MD + ND): 10335' MD / 5509' ND 16. Property Designation: ~-` .9L-1x1375074, 380053 ~ 5~ TPI: x- 462261 y- 5919728 Zone- 4 Total Depth: x- 462304 - 5920009 Zone- 4 11. SSSV Depth (MD + ND): landing nipple @ 489' MD / 488' TVD 1 . Land Use Permit t c 4293, 4601 ~ ~ 18. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): approx. 1249' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): '~ ~ cop of window @ 3tao• GR/RES, Neu/Dens ~//d01/ ~-x/,30. s%yd 1-3~ ~ ~~ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE CEMENTING RECORD AMOUNT CASING SIZE Wl". PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 41' 118' 41' 118' 24" 8 cu yds High Early 7.625" 29.7# L-80 41' 3026' 41' 2296' 9.875" 330 sx AS III Lite, 240 sx Class G 5.5" 15.5# L-80 41' 9921' 3717' 5213' 6.75" 616 sx Class G ~ 3.5" 9.2# L-80 9696' 10335' 5058' 5509' 6.75" 110 sx Class G 23. Open to production or injection? Yes / No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top 8 Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET entire liner is slotted except for the following blank intervals: 3.5" 9716' 9714' 10095'-10105' MD 5337'-5344' ND 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10095'-10105' 180194# 16/20 carbolite 26. PRODUCTION TEST Date First Production April 20, 2009 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 4/25/2009 Hours Tested 7.5 hours Production for Test Period --> OIL-BBL 519 GAS-MCF 295 WATER-BBL 24 CHOKE SIZE 100% GAS-OIL RATIO 821 Flow Tubing 23a psi Casing Pressure 825 ~~ Calculated 2a-Hour Rate -> OIL-BBL 1405 ~ GAS-MCF 1154 WATER-BBL 76 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No / Sidewall Cores Acquired? Yes ^ No / If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. •°°a {7y' _..7p~~ pg 4 MLR IJ NONE t ,.a,,.~~~- f r~J °f/ Form 10-407 Revised 2/2007 vr,~GIIdAL CONTINUED ON REVERSE SIDE( ~ ~~~~~~ ~~ ~/~~G 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost -Top ground Surface ground Surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1287' 1249' needed, and submit detailed test information per 20 AAC 25.071. T-3 9928' 521 T T-2 10131' 5363' N/A Formation at total depth: T-3 30. LIST OF ATTACHMENTS. Summary of Daily Operations, Directional Survey e,~r~e er 263-4820 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mik e/ Printed Name G. L. Alvord Title: Alaska Drilling Manager 9 ~ a ~ .. ~ Signature Phone ~S, G ~~ Date INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Afaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion),' so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 " '~ KUP ~ 2N-305A ~Of1QCC1~'1lI~I~JS I ~ Well_Attributes _ Max Angle $ MD jTD ° ~ K(s ~ Wellbore APl/UWI Field Name ( ) MD(NKB) Act Btrn (HKB) Well Status Prodllnj Type Intl ( ( _ 501032034901 TARN PARTICIPATING ' PRODUCING 6765 4,203.74 10,335.0 AREA nt H2S (ppm) Date 'Annotation Entl Date KB-Grd ft ~~. Ri Release Date ( I 41 .64 ~ 93/20/2009 O _ eAC nfig S~~ Oen~a/g9~2oo5 }:2250 Pryf - n D ( 1 Date End a - _ _-- __ _ l Last Tag SLM I 10h1 88.0 ~ 4/141 2009 ( 4/19/2009 ET CK (Rev Re orc NEW S D CaSing $trln S Casing Description String 0... ',String ID .. . Top (HKB) Set Depth (f... Set Depth (ND) ... String Wt..'String ... String Top Thrtl CONDUCTOR 16 15.062 0.0 118.0 118.0 ~ 62.50 H-00 WELDED cn ton str .. str 9 P 9 I'~ 9 P( 1 P ( P 9 ~Strmg ... String Top Thrd n f... set D Tn s D) $e RANGER, 37- 758 i ;r, SURFACE 6-750 7 i 29.0 L80 _ BTCM 23014 3,025 34.5 F Casing Description String 0... String ID .. . Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... (String Top Thrd - " _-_ ;: INTERMEDIATE 51/2 4.900 39.4 9,920] 5,212.1 15.50 L-80 Hyd 563 _ - '~ Casing Description String 0... String ID .. . Top (ftKB) Set Depih (f... Set Depih (ND) ... String Wt... String ... ji String Top Thrd WINDOW 51/2 4.000 3.130.0 3,140.0 2,355.7 Casing Description String 0... String ID . . Top (ftKB) Set Depih (f... Set Depth (ND) ... String Wt... Str g ... String Top Thrtl J '~ LINER 3112 2.992 _ Hydril 511 9,696.6 10,335-0 5,508.7 9.20 - L 80- I Liner Details -, Top Depth', __ _ CONDUCTOR.- (ND) Top Intl 0'118 Top (ftKB) ~'~ (HKB) (°) Item Descnpti on comment ID (in) 9,696.6 5.058.1 48.97 SBE , ZXP extension (4 65" OD / 4.12" ID) 4.120 ~ 9,714.0 5,069.3 48.54 PACKER ~ Baker "HR" ZXP Liner Top Packer (4.67" OD / 3.00" ID) 3.000 NIPPLE. 490------ s ~ 9,722.4 5,074.8 48.33 HANGER - - - Baker Flex Lock Liner Hanger (4.51" OD / 2.98" ID) 2.980 I 9,732.4 5,081.5 48.08 XO (Crossover Sub 3-1/2" SL-HT box x Hyoril 511 pin (4.26 OD / 2.92" ID) 2.992 suRFAce. --- Tubing Strings 34-3,026 Tubin Description Strin 0... Strin ID .. _ _ _ . To ftKB Se[Da th f... Set Oepth ND Strin Wt... Str Strin To Thrtl g ) ~~~ 1 p TUBING 3 12 2-992 IBT-M 9 30 L 80 9,716-0 5,070.6 37.2 wwoow. C l ti D t il 3,130-3,140 om e on e a s _. i '. Top Depth ~ ND ( ) Top Intl ~ ~ 'i " Top (ftKB) _(HKB) _ _ (°) Item Descnpti - on Comment _ _ _ ' ID (in) Gns uFT, _ -_ ^- 07 HANGER 37 2 37 2 -0 5" Gen V Tubing Hanger (BTM (Pup jt = 2.51') 3.500 3 3.230 . . . . _ 490.1 489.5 7.52 NIPPLE 3-5" D Nipple No-Go Profle 2.750 I __ __ - - ' ~ 9,609.2 5,004.5 53.84 SLEEVE-C -___._ -.- -_.- 2.812 35" Baker CMU Sliding Sleeve (4 18" OD x 2.812" DS Profile) 9,660.0 5,035.2 51.81 NIPPLE I - 3.5" Camco 2 75" "XN" Nipple (EUE Srd) 2.625 GAS LIFT,__ ___ - -'~~- ~ 9,698.5 5,059.3 48.92 LOCATOR ,. Baker 3.5" Locator OD (4.50" x 2.98" ID) 2.980 6,199 ~~ 9,710.4 5,067.0 48.63 SEAL ASSY Baker Bullet Seal Assembly (OD 4.10" x 2.95" ID) 2.980 Perforations & Slots snnt Top (ND) Btm (ND) Dens ' Top (ftKB) Btm (HKBIj (ftKB) (ftKB) Zone Date (sn,,. Type Comment 10,095 10,1051 5,336.9 5,344.1 T-2 Bermuda, 4/3/2009 6.0 IPERF 25" HSD HJ 2506RDX, 60 deg GAS UFT. _. _-_ - 2N-305A ~ phase 8,536 Stimulations & Treatments e tt em o I Min Top Max Btm Top Depth Depth Depth Depth (ND) (FVD) '~. ' (HKB) (ftKB) (ftKB) (ftKe) ~- T 1. Date Comment YPB GAS LIFT, _____ 9,559 - . - - - ~.~ 10,095.01 10,105.0 5,336.9 5,344.1 - _ ' --__. ___.. _-.. _.- -_ FRAC 4/5/2009 Dumped T2 Bermuda sand, fret, to completion I ~ placed a total of 180194# with # 10 PPA, 16/20 _ Carbolite to tormatioq 106%ofjob placed with an additional 112 bbl of 10 ppa pumped. Flushed 87 bbls with 50 bbls freeze protect included. Usetl 2104 bbls of SW and 90 bbls of diesel. Estimated SLEEVE-c, BHP=3449 psi 10 min SIP = 1657 psi. 9.609 Notes: General & Safety _ _ - -- , End Dale Annotation 4/19/2009 NOTE: View schematic w/Alaska Schematic9.0 NIPPLE. 9,660 ~. LOCATOR, 9,698 ~ S EAL ASSY. --- -- , !t'.:~.-~: ,1, 9,710 Mandrel Details '~. Top Depth Top ~ Pod ~ (rVD) Intl OD Valve Latch Size TRO Run St '. Top (ftKB) (HKB) () M k Model (inl Serv Type Type (in) (ps) Run Date Comm... 1 3,229 9 2 400.4 61 90 Camco jKBG 2-9 1 GAS LIFT DMY BTM 0 000 0 0 3!18/2009 __- KBG-2-9 1 GAS LIFT DMY BTM 0000 00 3/1812009 2 6,1988 3,595.5 6595 Camco NTERMEDwTE, ( __ _ _ Camco KBG-2-9 1 GAS LIFT DMY BTM 0 000 0 0 3178/2009 535 5 4 534 7 66 02 3 8 3s-s s21 , . , ! 4 9,559 4 4,975.8 55.69~Camco KBG-2-9 1 GAS LIFT iOV BTM 0 313 0 0 4/14!2009 IPERF. -. _ _ _ _ 1 -_ 10,095-10.105 FRAC, 10,095 - ^ LINER, 9.697-10,335 10,335 2.N-305~~ IDETR_:~I~ =~ ire" C~itttco'D~' Nipple~k•f 2.e:; ~" Id C~Go Profile ~it.'~1!~' D1ID Topset 5-1/~" C asin~ _ 7 ~ ~~ ~u ?# L_}gin ~rn 3,U}~' I',rID 12,2!?,' Tip D icieharlc F~~?F ~~tt ~'eltlrlit. l'; em ~1t Kr? plug un to17 ~ YetffirieY C ~~ng cmt. retuir~er ~,4i i0' It'IL~ CTL.TU'I# T~~e. '~~ ettir,~D eF~th iI'~'IDl 'vT a14~ e T;rf_~e 2 g>F,~.T?_G r;,l!~T' Dumrn~~ 4 h~b~:2-!~ 1 Tt 8tiio"e ~",liditig S1ee;Fe ~.$bJ" ~ 7.D. .}pE4'1;i1 ~.~le~rallre ~; rn_~plin~: T~ , n5-:~ lr'~" C:A+IU :_li~_iitigtilee;Te;='J?.313" D S Fr,afil e t; clo:;e ci 1' ositi Ox%~ ~c=ai 9,60"' ItrIT'i J 5,010' TTY D :~ng cmt retainer { it, r.. _- _' 15._~~L.-U '~,Ji-5' P,;ID 15,21 U' TVLi P erfs i ~:~ 9 "~~' - x."'34' ,~ 10,3':i'._' I'.+ID 15,e~79' T~'D 1~" ~:amco'D' Nipple w1 ~,u59' Pt,'ID ! x,031' TTd D Liner H axe er'~-. F' acl:er >:.: ~~'~ 9,69ii' I'.+ID 15,0=1c~' Tt'D , -112" HT~~~ril -,~~ 1 ~.~~ set.~`~~! _:+,921' I'~;ID ; ~,,'%„TGTD 3-l r?" H?; ~ri1 511 9 3# linrx setf~?,~ 10,35' IvID ~ 5,47' TVD ~ ~ 2N-305 SIDETR.~CK I~ I s 'Fi" Cs:nc~'D~'Nig~plr. +.,•.•' ~.~,_"Nu-~:oFxc&ile st 4R~'MD Topset ~-'/" Casing -3.~8" 29 7fi L-80 (ai s,U25' NID 1 2,296' T'dD Sidetrack KOF GL Nfii Time „ - aettine Death MlD)~~ ~S~al-n Type ,~.µ~~~_d off cemerS ~ 1 IiBG2-9 3,229' Dummy E9 (W 3,130' ~nD } 2 KBG2-9 6,198' D,xnmti y ~ 3 KEG2-9 8,534' Dummy 4 KBG"2-9 1Jt above Sli&ng'leev ~ ..~ a sev r 3- ti" v =, ti, L-&], IBTt.7 ~=.~f 3 865" O.D. S"pedal Cle arsnce C em erG. KO plot, ~r. couplings Wp of retsine~ "-~.~ TOC on5-'h" Cssing cmt reGtinez \ a +,t 5,500' MD 3,4UU' iti4D ~'. 3'h" CNIU Slidin~Sleeve wf2.813" ~ -~ -- ~~ DS Frofile (dc,sed po~tiurj ~~~., ~`>~._,_, ~ 9,608' NID f 5,01U' TVU 3 '.9' Csmc~'D Nipple v~ ~~~~~ ~. 2.75" No G o Pr~Rle lu C sling amt re[siner 9 za' t ro 9,b59' P,ID + %,031' TV D \ ~ s y '''~~ TOL Lw 9.3.`5 N4D ~- x" 13.3ii L-8U 9>_:~ ' ItHU f 5,210' TV D 3-1.2" r 5d 2" Liner Hanger & Packer (~ 9,595' N4D i 5,046' TVD ~'~ feff>tp ~ , 3-]f2"Hydril 5631S.~u '+ , .., e4 9,134' :'~, ' ' ~; ~ : N[D ! 3,122 TV D ~..!~., _ sett 9.921 1 "' 9.3d L-8U 1 U,328' AdD ! x,679' TV G 3-1 f"l" H ydril 3l l 9.3# liner set @ ]U,333' T"7D ! 3,487 TV D Page 1 of 1 filed/S:AANC\Longterm\Drilling & Wells Ops\G K A\2N Pad\2N-305A\Well Plan\... 4/21/2009 Cono~QPhillips Time Log & Summary Weltview Web ReAORtAg Report Well Name: 2N-305 Rig Name: DOYON 15 Job Type: DRILLING SIDETRACK Rig Accept: 2/14/2009 10:30:00 PM Rig Release: 3/20/2009 8:30:00 AM - ~ Time Loys --- - _ - -- -- ---- - _ _ _ _ _ --_ Date From To Dur S. Depth E_De~th Phase_ Code Subcode T Comment 2/11/2009 24 hrSummarv Move rockwasher, pits and sub off of 3H-33. Begin changing tires on pit module. 11:00 13:00 2.00 0 0 MIRU MOVE DMOB P Continue disconnecting lines between modules. 13:00 13:15 0.25 0 0 MIRU MOVE SFTY P PJSM -laying down beaver slide. 13:15 13:45 0.50 0 0 MIRU MOVE DMOB P Lay down beaver slide 13:45 14:00 0.25 0 0 MIRU MOVE SFTY P PJSM -skidding rig floor 14:00 14:45 0.75 0 0 MIRU MOVE DMOB P Skid rig floor 14:45 15:00 0.25 0 0 MIRU MOVE SFTY P PJSM -moving pits 15:00 20:15 5.25 0 0 MIRU MOVE DMOB P Move pits offf of mats and to side of ad where tires will be chan ed. 20:15 20:30 0.25 0 0 MIRU MOVE SFTY P PJSM - raiseing stompers. 20:30 21:00 0.50 0 0 MIRU MOVE DMOB P Rasiestomperfeet. 21:00 23:00 2.00 0 0 MIRU MOVE DMOB P Move sub off of well and off of rig mats. 23:00 00:00 1.00 0 0 MIRU MOVE RGRP P Prep new tires, tent overtire and place heaters on tires. Begin pulling tire off it module. 2/12/2009 Changed two tire on pit module. Moved from 3H pad to 1 Y -Spine road intersection. 00:00 05:00 5.00 0 0 MIRU MOVE DMOB P Replacing tires on pit module. Picking up rig mats and herculite. Cleanin ad. 05:00 17:00 12.00 0 0 MIRU MOVE MOB P Line up modules to exit pad, de-energize hiline, move modules from 3H to 1 O. 17:00 18:30 1.50 0 0 MIRU MOVE SFTY , P Safety standup at Drilling Tool House with both crews. 18:30 00:00 5.50 0 0 MIRU MOVE MOB P Move from 10 to 1Y detour. Move across 1Y pad to ice road detour. Move down ice road to 1 Y -Spine road intersection. 2/13/2009 Move from 1 Y -Spine road intersection to 2M pad. Make repairs to moving system as needed. Gave AOGCC, Jeff Jones, 24 hours notice of u comin o erations on 2N-305A. 00:00 05:00 5.00 0 0 MIRU MOVE MOB P Move from 1Y -Spine road intersection to 2B ad. 05:00 08:00 3.00 0 0 MIRU MOVE OTHR P Waiting on field crew change. 08:00 15:30 7.50 0 0 MIRU MOVE MOB T Repair moving system on pit module. 15:30 19:00 3.50 0 0 MIRU MOVE MOB P Move from 26 past 4 corners and halfwa to 2M ad. 19:00 22:00 3.00 0 0 MIRU MOVE MOB T Replace clutch on sub module drive motor. f'~a~~ 1 ~f ~~ ~ Time Logs ~_ _ _ Date From To Dur S De th E De th Pha e Code Subcode T _Comment__ __ 22:00 00:00 2.00 0 0 MIRU MOVE MOB P Move to 2M pad. Stop and allow traffic to ass. 2/14/2009 Move rig to 2N pad and spot sub over well 305. Begin moving camps, shop, parts house and rockwasher from 3H to 2N ad. 00:00 00:45 0.75 0 0 MIRU MOVE MOB P Let traffic pass at 2M pad. 00:45 12:15 11.50 0 0 MIRU MOVE MOB P Move from 2M pad across two bridges to hill before 2L pad. Hock up cats to sub and pull up hill. Move to 2N ad. 12:15 14:00 1.75 0 0 MIRU MOVE PRLO P Prep cellar area for sub. Haul and dump gravel, build up location for stom ers. 14:00 18:45 4.75 0 0 MIRU MOVE PRLO P Spread herculite and lay rig mats 18:45 19:00 0.25 0 0 MIRU MOVE SFTY P PJSM -moving sub onto mats and over well. 19:00 22:15 3.25 0 0 MIRU MOVE MOB P Move sub onto mats and turn 180 de rees. 22:15 23:45 1.50 0 0 MIRU MOVE PRLO P Work with Drill Site Operator to jack up oil and gas lines on adjacent wells to make room for stom er feet. 23:45 00:00 0.25 0 0 MIRU MOVE MOB P Spot sub over well 305. 2/15/2009 Set stomper feet, skid rig floor, Spot pits and rockwasher. Make rig ready for acceptance. Move and spot camps, shop and parts house. Displaced well to seawater, nipple down tree and begin nipple up of BOPE. Crews moving into 2L camps. Rig ready for acceptance at 13:30. Backed up time 15 hours due to CPAI caused delays during move. See toda s time to for details. 00:00 00:15 0.25 0 0 MIRU MOVE SFTY P PJSM -setting and preloading stom er feet. 00:15 00:45 0.50 0 0 MIRU MOVE MOB P Set stomper feet and preload. Turn pit module 90 degrees and prepare to crab onto mats. 00:45 01:00 0.25 0 0 MIRU MOVE SFTY P PJSM -skidding rig floor. 01:00 01:45 0.75 0 0 MIRU MOVE MOB P Skid rig floor into position over well and install hand rails. 01:45 03:30 1.75 0 0 MIRU MOVE MOB P Move pits onto mats and spot next to sub. Install beaver slide. Prep pad for sho and cam s. 03:30 04:00 0.50 0 0 MIRU MOVE MOB P Install roof caps between modules. Spot camps, shop, parts house and on 2N ad. 04:00 06:00 2.00 0 0 MIRU MOVE MOB P Spread herculite for rockwasher. Spot rockwasher next to pits. Berm up around rig. Begin hooking up water, steam air and mud lines between modules. f'~C ~ 2 €~f ~~ ~~ Time Logs Date_ From To _ _ Dur S. De th E. Depth Phase Code Subcode T Comment 06:00 13:30 7.50 0 0 MIRU MOVE MOB P Spot cuttings tanks for rockwasher, berm up around rockwasher and rig. Continue hooking up interconnects between modules. Work on rig acceptance checklist. Rig ready for acceptance @ 13:30. Rig acceptance backed up 15 hours due to CPAI caused delays during rig move (6.5 hours for field crew changes and safety stand up at DTH plus 8.5 hrs while rig waited on 2N pad for location to be made ready) Rig accept entered in wellview as 22:30 2/14/2009. 13:30 14:15 0.75 0 0 SURFA( RPCOM PULD P Pick up lubricator and crossovers. 14:15 16:00 1.75 0 0 SURFA( RPCOM MPSP P Rig up lubricator and pull BPV. 16:00 17:45 1.75 0 0 SURFA( RPCOM RURD P Rig up lines for displacing well. 17:45 18:00 0.25 0 0 SURFA( RPCOM PRTS P Pressure test lines to 1500 psi. Good test. 18:00 19:30 1.50 0 0 SURFA( RPCOM CIRC P Pump 42 bbls seawater down annulus displacing dielse from tubing. Pump 67 bbls seawater/safe-surf-o down tubing followed b 217 bbls of seawater. 19:30 20:00 0.50 0 0 SURFA( RPCOM CIRC P Shut in and blow down lines. Open annulus and tubing, check for flow, well is dead. 20:00 20:30 0.50 0 0 SURFA( RPCOM RURD P Rig down lines from displacement. 20:30 21:00 0.50 0 0 SURFA( RPCOM MPSP P Set BPV. 21:00 21:30 0.50 0 0 SURFA( RPCOM SFTY P PJSM -nipple down tree and nipple u BOPE. 21:30 23:00 1.50 0 0 SURFA( RPCOM NUND P Nipple down tree and adapter. Clean threads in tubing hanger. Install blanking plug per FMC rep. Cycle u er and lower lock down screws. 23:00 00:00 1.00 0 0 SURFA( RPCOM NUND P Nipple up spool adapter and riser. 2/16/2009 Nipple up ROPE equipment. Pick up 4"drill pipe, HWDP and jars. Test BOPE. Good test. Witnessed by AOGCC Chuck Scheve. Clean out debris from top of hanger and pull hanger to rig floor. Circulated seawater to clean hole. Set and iced in ri mats, run hi-line for sho and cam s across ad. 00:00 05:00 5.00 0 0 SURFA( RPCOM NUND P Nipple up BOP stack, bell nipple, riser, choke & kill lines and flow line. Chan a out saver sub. 05:00 07:15 2.25 0 0 SURFAf RPCOM RURD P Rig up to pick up 4"drill pipe. 07:15 07:45 0.50 0 0 SURFA( RPCOM NUND P Nipple down riser so it can be shortened to accomodate flush mounts iders. 07:45 11:00 3.25 0 0 SURFA( RPCOM PULD P Pick up 111 joints of 4"drill pipe and 14 'oints of HWDP lus 'ars. 11:00 11:45 0.75 0 0 SURFA( RPCOM NUND P Nipple up shortened riser. s s F'~~ 3 €~f ~~ ~~.~..~._ m Time Logs __ __ _ Date From To Dur S De th E. De th Phase Code Subcode T Comment 11:45 13:15 1.50 0 0 SURFA( RPCOM BOPE P Rig up to test BOPE. 13:15 17:00 3.75 0 0 SURFA( RPCOM BOPE P Test BOPE 250 psi low, 3500 psi high. Test annular, top and bottom rans with 3-1/2" test joint. Test 4" XT-39 dart valve and TIW valve. Test upper & lower IBOP, HCR kill, manual kill, blind rams and 18 choke manifold valves. Accumulator drawdown test starting pressure 3000 psi. Function HCR's, top & bottom rams and bag. 34 seconds for 200 psi increase, 3 minutes 17 seconds to full charge. 5 bottle average pressure 2400 psi. Test witnessed by AOGCC Chuck Scheve. 17:00 18:45 1.75 0 0 SURFA( RPCOM BOPE P Rig down test equipment and blow down lines. 18:45 19:30 0.75 0 0 SURFA( RPCOM MPSP T Attempt to pull BPV. Unable to catch BPV with T-bar due to debris on han er. 19:30 21:15 1.75 0 0 SURFA( RPCOM MPSP T Rig up suction hoses and suck out stack. Attempt to screw into hanger with landing joint. Wash top of hanger with water and compressed air. Screw into hanger with landing 'oint. Back out lock down screws 21:15 21:45 0.50 0 0 SURFA( RPCOM PULL P Pick up 20', 210k on weight indicator and tubing came free. Pull tubing hanger to rig floor. Pull landing joint, Check for pressure in tubing via BPV. Pull BPV. 21:45 22:00 0.25 0 0 SURFA( RPCOM SFTY P PJSM -circulating, laying down han er and com letion tubin . 22:00 22:30 0.50 0 0 SURFA( RPCOM PULL P Make up landing joint to hanger, break off & lay down hanger and landin 'oint. 22:30 23:30 1.00 0 0 SURFA( RPCOM CIRC P Make up head pin and circulate 130 bbls of seawater. Recovered 15 bbls of diesel when be an circulatin . 23:30 00:00 0.50 0 0 SURFA( RPCOM CIRC P Rig down circulating equipment and blow down lines. 2/17/2009 Pull 3-1/2" gas lift completion. Tubing not cut completely, pulled entire completion string from well. Tested BOPE with 4" and 5-1 /2" test joints. Sort used tubing and kick out corroded tubing. Pick up enough new tubin to make scra er run and set cement retainer. 00:00 06:00 6.00 0 0 SURFA( RPCOM PULL P POOH with 3-1/2"gas lift completion. Removed 80 centralizers from first 40 joints of tubing. Monitoring hole fill via trip tank. PU wt 110k, SO wt 98k. 06:00 12:45 6.75 0 0 SURFA( RPCOM PULL P Continue pulling 3-1 /2" tubing. PU wt 90k, SO wt 90k. Casing was not completely cut at 8500', joint # 270. Appear to be pulling complete tubing strin . 12:45 13:45 1.00 0 0 SURFA( RPCOM OWFF T Monitor well -static. ~~_ P~~ # of ~~ • Time Logs Date From To Dur S De th E. De th Phase Code Subcode T Comment 13:45 15:00 1.25 0 0 SURFAt RPCOM PULL T POOH with 3-1 /2" tubing string to seal assembly. Hole took 13 bbls over calculated fill on TOOH. 15:00 15:30 0.50 0 0 SURFA( RPCOM RURD P Rig down GBR handleing tools. 15:30 16:45 1.25 0 0 SURFA( RPCOM BOPE P Set test plug and fill stack with water for BOP test. Rig up test equipment. Pick u MWD tools via beaver slide. 16:45 19:45 3.00 0 0 SURFA( RPCOM BOPE P Test upper and lower rams with 4" test joint and annular preventor and upper rams with 5" test joint. Test manual and HCR chokes. 19:45 20:15 0.50 0 0 SURFA( RPCOM BOPS P Pull test joint and rig down test equipment. Begin removing corroded tubing from pipe shed. Remaining tubing will be used for scraper run and cement retainer. 20:15 20:45 0.50 0 0 SURFA( RPCOM OTHR T Install wear bushing and run in 2 lock down screws. 20:45 00:00 3.25 0 0 SURFA( RPCOM PULD T Continue unloading corroded tubing from pipe shed. Load shed with enough new tubing to run scraper and cement retainer to TD. Service drawworks. 2/18/2009 Run to bottom of 5-1/2" casing with scraper. No problems during trip in hole. Tagged up on depth. Circulate bottoms u at TD. Pull out of hole with scra er and icked u 5-1/2" cement retainer. 00:00 00:15 0.25 0 0 SURFA( RPCOM SFTY P PJSM -picking up and running in hole with scra er. 00:15 01:15 1.00 0 0 SURFA( RPCOM PULD P Make up scraper and crossovers to 3-1/2" EUE 8rd tubin . 01:15 05:15 4.00 0 0 SURFAt RPCOM TRIP T TIH with scraper with tubing from pipe shed. Monitor displacement via tri tank 05:15 06:45 1.50 0 0 SURFA( RPCOM TRIP T TIH with tubing from derrick. PU wt 100k, SO wt 95k. Monitor dis lacement via tri tank 06:45 07:45 1.00 0 0 SURFA( RPCOM SVRG P Steam and service Upper & Lower IBOP. Service drawworks. 07:45 10:30 2.75 0 0 SURFA( RPCOM TRIP T TIH with tubing from derrick. PU wt 120k, SO wt 100k. Monitor dis lacement via tri tank 10:30 10:45 0.25 0 0 SURFAt RPCOM SFTY T Post JSM -TIH from derrick. Pre JSM -Sin le in hole from i e shed. 10:45 14:00 3.25 0 0 SURFA( RPCOM TRIP T Single in hole with tubing from pipe shed. PU wt 140k, SO wt 103k. Ta ed u on de th. 14:00 15:30 1.50 0 0 SURFA( RPCOM CIRC T Rig up head pin and circulate bottoms up with seawater at 6 bpm, 2390 psi. 2727 units max gas EPOCH on bottoms u . 15:30 15:45 0.25 0 0 SURFA( RPCOM SFTY T PJSM -POOH with tubing. 15:45 22:00 6.25 0 0 SURFA( RPCOM TRIP T POOH with scraper, racking back tubin in derrick. 22:00 23:15 1.25 0 0 SURFA( RPCOM PULD T Lay down scraper and corssovers. 23:15 23:30 0.25 0 0 SURFA( RPCOM SFTY T PJSM -picking up and running cement retainer. ~ f'~c~~ ~ csf~ ~II ~® • Time Logs _ _ Comment __ Date From To Dur S. Depth E. De th Phase Code Subcode T 23:30 00:00 0.50 0 0 SURFA( RPCOM PULD _ T Pick up and make up cement retainer for 5-1/2" casin . 2/19/2009 Run 5-1/2" cement retainer on 3-1/2" tubing to 9378' MD. Set retainer and circulate bottoms up. Rig up Dowell and perform infectivity test and pump 10 bbl cement plug on top of retainer. Circulate and pull out of hole. Make u 2nd retainer and re to run in hole. 00:00 00:45 0.75 0 0 SURFA( PLUG TRIP T TIH with cement retainer on 3-1/2" tubin from i e shed. 00:45 08:45 8.00 0 0 SURFA( PLUG TRIP T TIH with retainer on 3-1/2" tubing from derrick. PU wt 120k, SO wt 100k. 08:45 09:00 0.25 0 0 SURFA( PLUG RURD T Make up crossover to top drive. 09:00 11:30 2.50 0 0 SURFA( PLUG PLUG T Pick up 2' and rotate 15 turns to the right. Slack off 2'. Plug not set. Reciprocate pipe to work turns down to setting tool. Rotate 10 turns and reciprocate pipe. Slack off, plug set. Pick up 25k overpull (175k) to confirm set. Slack off and set 25k down on tool (80k). Repeat 2 times. Pick up to 147k and make 10 turns to the right. Observed 5k loss in weight. Pick up, packer not released. Work pipe until packer released. Retainer set at 9,328'. 11:30 12:00 0.50 0 0 SURFAI PLUG TRIP T POOH and replace joint with bad collar. Rig up head pin and lines. 5' into to of lu . 12:00 12:45 0.75 0 0 SURFA( PLUG CIRC T Circulate bottoms up at 4 bpm, 1040 psi. PU wt 145k, SO wt 105k. Max as 1405 units. 12:45 13:00 0.25 0 0 SURFA( PLUG OWFF T Monitor well -static. 13:00 14:15 1.25 0 0 SURFA( PLUG PLUG P Turn over to Dowell to perform infectivity test and set cement plug. Sting into retainer and pressure up to 1000 psi. Hold for 10 minutes. No pressure loss, formation not taking fluid. Sting out of retainer and set 10 bbl cement lu on to of retainer 14:15 15:00 0.75 0 0 SURFA( PLUG TRIP T POOH at 20 fpm. PU wt 140k, SO wt 105k. 15:00 16:15 1.25 0 0 SURFA( PLUG CIRC T Circulate 2+ bottoms up at 6 bpm, 2050 si. Max as 847 units. 16:15 16:30 0.25 0 0 SURFA( PLUG OWFF T Monitor well -static. 16:30 16:45 0.25 0 0 SURFA( PLUG RURD T Rig down head pin and lines, blow down lines. Install stri in rubber. 16:45 17:00 0.25 0 0 SURFA( PLUG SFTY T PJSM -POOH with work string. 17:00 18:30 1.50 0 0 SURFA( PLUG TRIP T POOH with 3-1 /2" tubing and retainer running tool, racking back tubing in derrick. 18:30 22:45 4.25 0 0 SURFA( PLUG TRIP T POOH laying down tubing to pipe shed. 22:45 23:15 0.50 0 0 SURFAI PLUG PULD T Lay down retainer running tool. 23:15 23:30 0.25 0 0 SURFA( PLUG SFTY P PJSM -running 2nd retainer. ~ ~~ _ ~~r~e ~ ~~t ~a~ I Time Logs i _ _- ___ _ Subcode T Comment _ S. De th E. De th Phase Code Date From To D ur 23:30 00:00 _ _ 0.50 0 _ 0 SURFA( _ PLUG PULD P Make up retainer to tubing. 2/20/2009 Pressure test cement plug. Run and set second retainer at 3400' MD. Displace-well to mud, lay down work string and pressure test retainer. Cut casing with jet cutter on eline. Attempt to displace annulus to mud, no returns. S ear 5-1/2" casin and ull free. 00:00 00:30 0.50 0 0 SURFA( PLUG PRTS P Pressure test cement plug to 1000 psi. Hold for 15 minutes. Lost about 50 psi during test. No pressure increase observed on 7-5/8" x 5-1/2" annulus. 00:30 00:45 0.25 0 0 SURFA( PLUG PRTS P Rig down test equipment and blow down lines. 00:45 03:00 2.25 0 3,400 SURFA( PLUG PLUG P TIH with cement retainer on 3-1/2" tubing. Pick up single and make top drive connection. PU wt 95k, SO wt 90k. 03:00 03:30 0.50 3,400 3,400 SURFA( PLUG PLUG P Make 15 turns to the right, PU to 25k overpull, SO putting 10k on retainer. Repeat twice to confirm set. make 12 turns to the right and unsting. Sting back in confirm set and depth, 3400' MD. Unstin . 03:30 03:45 0.25 3,400 3,400 SURFA( PLUG SFTY P PJSM -displacing well to LSND mud. 03:45 04:15 0.50 3,400 3,400 SURFA( PLUG CIRC P Displace well to mud at 4 bpm, 460 si. 04:15 04:45 0.50 3,400 3,400 SURFA( PLUG OWFF P Monitor well -static. Rig down circulatin a ui ment. 04:45 09:15 4.50 3,400 3,400 SURFA( PLUG TRIP P POOH laying down tubing to pipe shed. La down retainer runnin tool. 09:15 10:15 1.00 3,400 3,400 SURFA( PLUG PULD P Lay down tubing from derrick 10:15 10:45 0.50 3,400 3,400 SURFA( PLUG RURD P Rig down 3-1/2 handling equipment and ri u test a ui ment. 10:45 11:15 0.50 3,400 3,400 SURFA( PLUG PRTS P Test casing / retainer to 1000 psi for 30 minutes. No ressure loss. 11:15 12:00 0.75 3,400 3,400 SURFA( PLUG PRTS P Rig down test equipment and blow down lines. 12:00 12:30 0.50 3,400 3,400 SURFA( RPCOM SFTY P PJSM -rigging up and cutting casing with eline. 12:30 15:00 2.50 3,400 3,400 SURFA( RPCOM RURD P Rig up eline and casing jet cutter. 15:00 16:00 1.00 3,400 3,400 SURFA( RPCOM ELOG P RIH with jet cutter on eline, 3370' ` c~*~ WLM. J«~sS ~` ~"J L 16:00 17:15 1.25 3,400 3,400 SURFA( RPCOM ELOG P POOH with jet cutter and rig down eline. 17:15 17:30 0.25 3,400 3,400 SURFA( RPCOM SFTY P PJSM -displacing 7-5/8" x 5-1/2" annulus 17:30 19:00 1.50 3,400 3,400 SURFA( RPCOM CIRC P Attempt to displace annulus. Unable to circulate, no returns. Pressured up to 900 psi, pumped away 8 bbps. Shut down, pressure stabilized at 410 psi. Bleed back 4 bbls to trip tank. 19:00 20:00 1.00 3,400 3,400 SURFA( RPCOM RURD P Pull wear bushing. ~~~~ 7 of 48 L~ i Time Logs __ _ __ ___ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 20:00 _ 21:00 1.00 3,400 3,400 SURFA( RPCOM PULL _ P Pull packoff. RIH with retrieval tool, close annular preventer, pressure up to 500 psi and back out lock down screws. Bleed off pressure. Casing did not grow. Open annular preventer and ull ackoff. 21:00 22:30 1.50 3,400 3,400 SURFA( RPCOM FISH P Make up spear to fish 5-1/2" casing. Grapples too large to fit thru hanger. Change out grapples and engage fish. 22:30 23:45 1.25 3,400 3,400 SURFA( RPCOM FISH P Attempt to pull casing free. Work pipe puling to 240k up wt. Increase pull to 270k up wt. Casing not free. Kick on pumps at 2 bpm, 500 psi and work casing. Casing came free at 220k up wt. No returns while um in . 23:45 00:00 0.25 3,400 3,400 SURFA( RPCOM PULD P Lay down double used to spear fish and blow down to drive. 2/21 /2009 Lay down 5-1/2" casing hanger and spear. Attempt to circulate well every 3 joints on trip to surface shoe. Establish circulation once in surface shoe. Circulate out diesel and gas trapped in 7-5/8" x 5-1/2" annulus. Pull out of hole, fillin i e eve 3 'oints due to hole swabbin . 00:00 00:45 0.75 3,400 3,400 SURFA( RPCOM PULL P Lay down 5-1 /2" casing hanger and s ear. 00:45 01:30 0.75 3,400 3,400 SURFA( RPCOM RURD P Rig up 5-1/2" handling equipment. 01:30 01:45 0.25 3,400 3,400 SURFA( RPCOM SFTY P PJSM -POOH with 5-1/2" casing. 01:45 03:30 1.75 3,400. 3,400 SURFA( RPCOM PULL P POOH with 5-1/2" casing on elevators. Stop every 3 joints and attempt to circulate. Pressure up to 600 psi spp with no returns. Continue POOH until cut joint abive surface shoe. 03:30 04:30 1.00 3,400 3,400 SURFA( RPCOM CIRC P Break circulation and divert returns thru poor boy degasser sending 50 bbls diesel to rockwasher. Pump 4 b m, 310 si, total of 257 bbls. 04:30 04:45 0.25 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -slight weeping. Mud weight in non-pressurized 9.0 ppg., mud weight out non-pressurized 8.4 ppg. Mud weight pressurized 9.0 04:45 05:45 1.00 3,400 3,400 SURFA( RPCOM CIRC P Circulate 232 bbls, until mud weight out non- ressurized = 8.8 05:45 06:15 0.50 3,400 3,400 SURFA( RPCOM CIRC P Circulate bottoms up taking returns down flow line. 06:15 07:15 1.00 3,400 3,400 SURFA( RPCOM RURD P Rig up for LOT using test pump. 07:15 08:00 0.75 3,400 3,400 SURFA( RPCOM LOT P Perform LOT. Formation broke over at 600 si s , 14.0 EMW. 08:00 08:30 0.50 3,400 3,400 SURFA( RPCOM RURD P Rig down LOT equipment 08:30 10:15 1.75 3,400 3,400 SURFA( RPCOM CIRC P Circulate 40 bbl nut plug sweep at 8 bpm, 520 psi. PU wt 105k, SO wt 105k. Max as 158 units. 10:15 10:30 0.25 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -breathing to static. ®~ Pa~~ 3 of ~~ ~~ Time Logs Date From To Dur S. Depth E. Depth Phase Code_ Subcode T Comment__ 10:30 11:30 1.00 3,400 3,400 SURFA( RPCOM CIRC P Circulate at 8 bpm, 520 psi. PU wt 105k, SO wt 105k. Max gas 157 units. 11:30 12:00 0.50 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -breathing to static. 12:00 12:30 0.50 3,400 3,400 SURFA( RPCOM CIRC P Circulate at 7.5 bpm, 460 psi. PU wt 105k, SO wt 105k. Max gas 122 units. 12:30 13:00 0.50 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -breathing to static. 13:00 13:15 0.25 3,400 3,400 SURFA( RPCOM PULL P POOH with 3 joints, hole swabbing. 13:15 14:00 0.75 3,400 3,400 SURFA( RPCOM CIRC P Circulate at 8 bpm, 520 psi. PU wt 105k, SO wt 100k. Max gas 194 units. 14:00 14:15 0.25 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -breathing to static. 14:15 15:00 0.75 3,400 3,400 SURFA( RPCOM CIRC P Circulate at 8 bpm, 500 psi. PU wt 105k, SO wt 100k. Max gas 156 units. 15:00 15:15 0.25 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -static 15:15 15:30 0.25 3,400 3,400 SURFA( RPCOM PULL P POOH with 3 joints, hole swabbing. 15:30 16:00 0.50 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -static 16:00 17:15 1.25 3,400 3,400 SURFA( RPCOM PULL P POOH with 6 joints, hole swabbing. Fill hole. Monitor well -static 17:15 17:30 0.25 3,400 3,400 SURFA( RPCOM CIRC P CBU at 8 bpm, 500 psi. PU wt 105k, SO wt 100k. Max as 183 units. 17:30 18:00 0.50 3,400 3,400 SURFA( RPCOM PULL P POOH with 3 joints, hole swabbing. Fill hole. 18:00 00:00 6.00 3,400 3,400 SURFA( RPCOM PULL P POOH. Fill hole, calculate fill volume eve 3 'oints Burin tri out of hole. 2/22/2009 Pulled out of hole with 5-1/2" casing. Test annular preventer, good test. Made cleanout run to top of 5-1/2" casing stub. Backreamed to surface casing shoe. Began singling in hole with 2-7/8" tubing /cement stinger for settin lu . 00:00 01:15 1.25 3,400 3,400 SURFA( RPCOM PULL P POOH with 5-1/2" casing. Fill hole, calculate fill volume every 3 joints during trip out of hole. Pulled total of 78 joints, plus hanger and 9.71' cut off joint. Hole took 7.8 bbls more than calculated hole fill over tri . 01:15 01:30 0.25 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -static 01:30 02:00 0.50 3,400 3,400 SURFA( RPCOM RURD P Rig down 5-1 /2" handling equipment. Blow down lines. 02:00 03:30 1.50 3,400 3,400 SURFA( RPCOM BOPE P Rig up and test annular preventer (250 psi low, 3500 psi high) with 3-1/2", & 5-1/2" test joints. Good test. Ri down test a ui ment. 03:30 04:00 0.50 3,400 3,400 SURFA( RPCOM OTHR P Install wear bushing and run in 2 lock down screws. 04:00 04:15 0.25 3,400 3,400 SURFA( RPCOM SFTY P PJSM -picking up and running in hole with cleanout assembl . 04:15 05:00 0.75 3,400 3,400 SURFA( RPCOM PULD P Pick up cleanout BHA per DD. Monitorin hole via tri tank. ~~--~ _ • Time Logs I Date From To Dur S De th E. De th Phase Code Subcode T Comment 05:00 06:15 1.25 3,400 3,400 SURFAt RPCOM TRIP P TIH with cleanout assembly on 4" drill pipe to surface casing shoe. Fill pipe at 2300'. PU wt 115k SO wt 108k 06:15 07:15 1.00 3,400 3,400 SURFAt RPCOM CIRC P Circulate bottoms up pumping 9 bpm, 460 psi. Max Epoch gas 460 units. 07:15 07:30 0.25 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -static 07:30 10:30 3.00 3,400 3,400 SURFA( RPCOM WASH P Wash in hole pumping 8 bpm, 520 psi. rotating 35 rpm to 3358' MD. Packed off and pressured up to 1300 psi. POOH to 3235' MD. Max EPOCH as 500 units. 10:30 11:00 0.50 3,400 3,400 SURFA( RPCOM CIRC P Circulate bottoms up pumping 8 bpm, 520 psi. PU wt 120k, SO wt 110k, rotating wt 110k. Max EPOCH as 2300 units. 11:00 13:00 2.00 3,400 3,400 SURFA( RPCOM WASH P Wash in hole pumping 8 bpm, 470 psi. rotating 35 rpm. PU wt 120k, SO wt 110k, rotatin wt 110k. 13:00 14:15 1.25 3,400 3,400 SURFA( RPCOM REAM P BROOH pumping 8 bpm, 460 psi. rotating 35 rpm. PU wt 125k, SO wt 108k, rotatin wt 105k. 14:15 14:45 0.50 3,400 3,400 SURFA( RPCOM CIRC P Circulate bottoms up pumping 8 bpm, 510 psi. PU wt 115k, SO wt 108k. Max EPOCH as 300 units. 14:45 15:15 0.50 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -static. Blow down top drive. 15:15 16:30 1.25 3,400 3,400 SURFA( RPCOM LOT P Rig up and perform LOT. Calcuted 13.7 EMW. 16:30 17:15 0.75 3,400 3,400 SURFA( RPCOM TRIP P TIH and tagged up on 5-1/2" casing stub at 3374'MD. Continue in hole until wash pipe 10' inside 5-1 /2" casin stub 17:15 19:15 2.00 3,400 3,400 SURFA( RPCOM CIRC P Circulate hole pumping 8 bpm, 450 psi, reciprocating string 60'. PU wt 120k, SO wt 110k. Max EPOCH gas 126 units. 19:15 19:30 0.25 3,400 3,400 SURFAt RPCOM OWFF P Monitor well -static 19:30 19:45 0.25 3,400 3,400 SURFAt RPCOM TRIP P POOH on elevators to surface casing shoe. 19:45 20:00 0.25 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -static. Pump 20 bbl d ~ob. 20:00 21:00 1.00 3,400 3,400 SURFA( RPCOM TRIP P POOH on elevators to BHA. Monitorin hole fill via tri tank. 21:00 22:00 1.00 3,400 3,400 SURFA( RPCOM TRIP P POOH with BHA, racking back HWDP and jars. Hole took 5 bbls over calculated Burin tri . 22:00 23:00 1.00 3,400 3,400 SURFA( RPCOM PULD P Clear rig floor and rig up GBR 2-7/8" handlin tools. 23:00 23:15 0.25 3,400 3,400 SURFA( CEMEN- SFTY P PJSM -picking up 2-7/8" cement stin er and runnin in hole. 23:15 00:00 0.75 3,400 3,400 SURFAt CEMEN TRIP P Single in hole with 2-7/8" cement stinger monitoring displacement via tri tank. ~~ l~:~r~e 1~7 of ~~ • Time Logs --- ------ - -- Date .From To Dur S. Depth E_D_epth Phase Code Subcode T Comment _ _ _ __ 2/23/2009 2a hr Summary Ran in hole with 2-7/8" cement stinger on 4" drill pipe. Circulated hole and pumped 28 bbl cement plug: Pulled out of plug and circulated out excess cement. Layed down cement stinger and rigged up slickline. made 'unk basket run and tali ed run in 7-5/8" surface casin . 00:00 00:45 0.75 3,400 3,400 SURFA( CEMEN' TRIP P Single in hole with 2-7/8" cement stin er. from i e shed. 00:45 01:00 0.25 3,400 3,400 SURFA( CEMEN' RURD P Rig down 2-7/8" handleing equipment and ri u 4"drill i e tools. 01:00 03:30 2.50 3,400 3,400 SURFA( CEMEN" TRIP P make up cross overs to 4" drill pipe and single in hole with drill pipe from shed. 03:30 04:00 0.50 3,400 3,400 SURFA( CEMEN" CIRC P Circulate bottoms up at surface casing shoe pumping 7 bpm, 390 si. Max E och as 112 units. 04:00 04:30 0.50 3,400 3,400 SURFAC CEMEN" TRIP T POOH and rack back 10 stands while waiting on cementers. 1st batch of cement mix went off early Dowell turned trucks around to unload, remix and reload. 04:30 05:00 0.50 3,400 3,400 SURFA( CEMEN" TRIP T Single in hole 10 stands while waitin on cementers. 05:00 05:30 0.50 3,400 3,400 SURFAC CEMEN" TRIP T POOH and rack back 10 stands while waitin on cementers. 05:30 06:15 0.75 3,400 3,400 SURFA( CEMEN" TRIP T Single in hole 10 stands while waitin on cementers. 06:15 06:45 0.50 3,400 3,400 SURFA( CEMEN- CIRC P Circulate bottoms up at surface casing shoe pumping 8 bpm, 450 si. 06:45 07:30 0.75 3,400 3,400 SURFA( CEMEN" OWFF P Monitor well -static. Blow down top drive. Pre for cement'ob. 07:30 08:15 0.75 3,400 3,400 SURFA( CEMEN" TRIP P TIH on elevators and tag casing stub. 08:15 09:45 1.50 3,400 3,400 SURFA( CEMEN" CIRC P Circulate bottoms up and continue circulating while rigging up for cement 'ob. 09:45 10:15 0.50 3,400 3,400 SURFA( CEMEN" SFTY P PJSM -setting cement plug. 10:15 10:45 0.50 3,400 3,400 SURFA( CEMEN" PLUG P Set cement plug in open hole and up into surface casing. Pressure test lines to 3000 psi. Dowell pumped 18 bbls mud push, 28 bbls cement. 5 bbls mud push and displaced with 20 bbls of mud. Held -200 psi of backpressure using annular preventer while pumping and displacing cement. 10:45 11:15 0.50 3,400 3,400 SURFA( CEMEN" TRIP P Pull stinger out of cement at 20 fpm. Washin u and blowin down lines. 11:15 12:45 1.50 3,400 3,400 SURFA( CEMEN" CIRC P Circulate out mud push and excess cement. Approximately 3 bbls of cement back to surface. Pumped 6 b m, 400 si. 12:45 13:15 0.50 3,400 3,400 SURFA( CEMEN" TRIP P POOH on elevators. 13:15 14:00 0.75 3,400 3,400 SURFA( CEMEN" CIRC P Flush stack and lines, function bag and rams. Blow down lines. 14:00 14:30 0.50 3,400 3,400 SURFA( CEMEN- TRIP P POOH with 4" drill pipe. e~ ~~€~~ ~ ~ ssf ~8 Time Logs ___ ~ _ _ _ _ Date Frorn To Dur S De th E De th Phase Code Subcode T Comment _ __ 14:30 15:00 0.50 3,400 3,400 SURFA( CEMEN" RURD P Rig down 4" handleing equipment and ri u 2-7/8". 15:00 15:15 0.25 3,400 3,400 SURFA( CEMEN' SFTY P PJSM -laying down 2-7/8" cement stin er. 15:15 17:00 1.75 3,400 3,400 SURFA( CEMEN" TRIP P POOH and lay down 2-7/8" tubing. 17:00 18:30 1.50 3,400 3,400 SURFA( EVALWE RURD X Rig up Halliburton slickline for caliper to in 18:30 20:15 1.75 3,400 3,400 SURFA( EVALWE SLKL X RIH with junk basket on slickline. Worked basket down to 2600' SLM. POOH. Dumped cement from basket. 20:15 21:30 1.25 3,400 3,400 SURFA( EVALWE SLKL X Lay down junk basket and pick up tali er tools. 21:30 00:00 2.50 3,400 3,400 SURFA( EVALWE SLKL X RIH with caliper on slickline. Log while POOH. First run bad, rerun. TD 2900' SLM. ... 2/24/2009 Finish caliper log, R/D, change lower rams to 3-1 /2" x 6" variables, test with 3-1/2", 4" and 5-1/2" test joints to 250 and 3500 psi, set wear bushing, PU/MU drilling assembly, upload MWD, continue with BHA to 648', shallow pulse test, PU 51 joints of 4" dp from pipe shed, trip in to 2917', service rig, PJSM, slip and cut drilling line, test the 7-5/8" surface casing to 1200 psi f/ 30 min (lost 80 psi in 30 minutes), R/D ewipment, trip in to top of cement @ 2925', drill cement to 3130', kick of point 3130', directional drill to 3185', CBU, POOH to 3010', perform LOT to 14.2 ppg EMW, R/D equipment, drop ball to activate Smith 7-1/2" Rhino Reamer, Ream to 3185', POOH to 3145', perform PWD baseline test, directional drill with 6-3/4" bit, GeoPilot and 7-1 /2" Rhino Reamer to 3457'. 00:00 00:30 0.50 3,400 3,400 SURFA( EVALWE SLKL X RIH with caliper on slickline. Log while POOH. First run bad, rerun. TD 2900' SLM. 00:30 00:45 0.25 3,400 3,400 SURFA( EVALWE SLKL X Rig down and release slickline. 00:45 01:15 0.50 3,400 3,400 SURFA( DRILL OTHR P Pull wear bushing. Install test plug. 01:15 02:00 0.75 3,400 3,400 SURFA( DRILL BOPE P Change lower pipe rams from 2-7/8" x 5" variables to 3-1/2" x 6" variables. 02:00 02:30 0.50 3,400 3,400 SURFA( DRILL BOPE P Rig up testing equipment. 02:30 03:30 1.00 3,400 3,400 SURFA( DRILL BOPE P Test lower pipe rams to 250 psi low and 3500 psi high. Hold each test 5 minutes. Chart test. Tested with 3-1/2", 4", and 5-1/2" test'oints. 03:30 03:45 0.25 3,400 3,400 SURFA( DRILL BOPE P Rig down testing equipment. Set wear bushing (10-11/16" OD x 7-13/16" ID 03:45 06:00 2.25 3,400 3,400 SURFA( DRILL PULD P Pickuo drillina assembly 06:00 07:00 1.00 3,400 3,400 SURFA( DRILL PULD P Upload Sperry Sun MWD. 07:00 07:45 0.75 3,400 3,400 SURFA( DRILL PULD P Continue to pick up BHA. 07:45 08:00 0.25 3,400 3,400 SURFA( DRILL DHEO P Shallow pulse test MWD tools. Pumping 280 gpm w/ 930 psi-29% flow out. Rotate 15 rpm w/ 1 k ft Ibs of for ue. Good test. 08:00 09:00 1.00 3,400 3,400 SURFA( DRILL TRIP P Trip in the hole w/ 51 jts of 4"drill pipe from the pipe shed. Monitor dis lacement on the tri tank. ~~~~~ 12 of 43 P~~ ~~ ~t~F s J Time Logs D~te_____ _ From To Dur S. De th E. De th Phase Code Subcode T Comment _ -- T 09:00 09:30 0.50 3,400 3,400 SURFA( DRILL TRIP P Trip in the hole w/ 4"drill pipe from the derrick. Monitor displacment on the trip tank. Fill pipe. Break in seals on the geoPilot, pumping 280 gpm w/ 1130 psi-29% flow out. Rotate 20 r m w/ 2k ft Ibs of for ue. 09:30 10:00 0.50 3,400 3,400 SURFA( DRILL SVRG P Service rig. 10:00 10:15 0.25 3,400 3,400 SURFA( DRILL SFTY P Pre job safety meeting on slip and cuttin drillin line. 10:15 11:30 1.25 3,400 3,400 SURFA( DRILL SVRG P Slip and cut 90' of 1-3/8" drilling line. Ins ect brakes on the drawworks. 11:30 12:00 0.50 3,400 2,917 SURFA( DRILL RURD P Rig up to test the 7-5/8" casing @ 291 T. 12:00 12:45 0.75 3,400 2,917 SURFA( DRILL PRTS P Test the 7-5/8" casing to 1200 psi. Bleed off 80 pis in 30 minutes. Rig down testin a ui ment. 12:45 13:00 0.25 3,400 3,130 SURFA( DRILL TRIP P Trip in to 2925'. 13:00 15:00 2.00 3,130 3,130 SURFA( DRILL WASH P Rotate and wash in the hole from 2925' to 3130' (drilling cement). Pumping 290 gpm w/ 1300 psi-30% flow out. Rotate 90 rpm w/ 3k ft Ibs of torque. PU wt 130k, SO wt 100k, Rotatin wt 118k. 15:00 16:15 1.25 3,130 3,185 SURFA( CEMEN' DRLG P Kick off point is 3130'. Directional drill from 3130' to 3185'. WOB 10k, 70 rpm w/ 4-5k ft Ibs of ~.~ °'3 Q S ~ ,~ ~ ~- ~ torque.Pumping 270 gpm w/ 1230 psi-29% flow out. PU wt 130k, SO wt 100k, Rot wt 118k. Total hrs on bit 1.2 hrs, jar hours 9.49. Max gas observed b EPOCH 442 units. 16:15 16:45 0.50 3,185 3,185 SURFA( DRILL CIRC P Circulate. Rotate and recip from 3185' to 3125'. Pumping 265 gpm w/ 1150 psi-29% flow out. Rotate 70 rpm w/ 4k ft Ibs of torque. Circulated 132 bbls. 16:45 17:00 0.25 3,185 3,185 SURFA( DRILL TRIP P Pull out of the hole to 3010' (Inside of 7-5/8" casin 17:00 17:30 0.50 3,185 3,185 SURFA( DRILL RURD P Rig up to perform LOT. 17:30 17:45 0.25 3,185 3,185 SURFA( DRILL LOT P Perform LOT to 14.2 ppg EMW. 17:45 18:30 0.75 3,185 3,185 SURFA( DRILL RURD P Rig down equipment and blow down lines. 18:30 18:45 0.25 3,185 3,185 INTRM1 DRILL CIRC P Drop ball to activate Rhino Reamer. Pressure up to 2500 psi, shear ball seat. 18:45 19:00 0.25 3,185 3,185 INTRMI DRILL REAM P Ream to bottom. Pumping 275 gpm w/ 1050 psi-30% flow out. Rotate 90 rpm w/ 4k ft Ibs of torque. PU wt 125k, SO wt 103k, Rot wt 110k. 19:00 19:30 0.50 3,185 3,145 INTRM1 DRILL TRIP P Pull out of the hole to 3145'. Perform PWD baseline test. Pumping 250 psi, 280 psi and 310 psi. Rotate 70 rpm, 80 rpm and 90 rpm at each flow rate. Clean hole ECD's with 9.3MW is a 9.98 ~~.~ ~ ~ ~~~~ 13 of 4 I Time Logs - ---- - -- Date From To Dur S. Depth E._Depth Pha e Code _ Subcode T Comment _ __ 19:30 00:00 4.50 3,145 3,457 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-112". Max gas observed by EPOCH 211 units. Pumped 20 bbls sweeps (9.3 ppg/210 vis w/medium nut plug 10ppb) @ 3192' and 3263'. Purpose to clean tools- seems effective. 2/25/2009 Continue to directional drill with 6-3/4" bit, GeoPilot and 7-1/2" Rhino Reamer from 3457' to 3663',_ circulate, monitor well, trip for lack of ROP, pump dry job, continue trip out, UD BHA #3, download MWD, service rig, service BHA, service rig, PU/MU BHA #4, RIH to 255', shallow pulse test, continue trip in to 3580', fill pipe, directional drill from 3663' to 3674' at midni ht. 00:00 06:00 6.00 3,457 3,621 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed by EPOCH 114 units. Pumped a 30 bbl sweep (9.3 ppg/250 vis w/ medium nut plug 10ppb) @ 3,530' & 3613'. Purpose to clean tools- with minimal im rovement. 06:00 12:00 6.00 3,621 3,663 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed by EPOCH 46 units. Pumped (3) 30 bbls sweeps (9.3 ppg/210 vis w/ medium nut plug 10ppb) Purpose to clean tools- with minimal results. Pumped a 20 bbl SAP pill followed w/ 30 bbl Hi-vis sweep (9.3 ppg/210 vis w/ medium nut plug 10ppb) to clean tools and bit- with minimal results. 12:00 12:15 0.25 3,663 3,663 INTRM1 DRILL CIRC T Circulate pill and sweep out of hole. Reciprocate from 3663' to 3573'. Pumping 304 gpm w/ 1490 psi- 32% flow. Rotate 120 rpm w/ 3k ft Ibs of torque. PU wt 128k, SO wt 110k, Rot wt 118k. 12:15 12:30 0.25 3,663 3,663 INTRM1 DRILL OWFF T Monitor well- static. Obtain slow um rates. 12:30 13:00 0.50 3,663 3,010 INTRM1 DRILL TRIP T Trip f/ lack of ROP. Obtain PU and SO wt's every 5 stands. PU wt 125k, SO wt 107k. 13:00 13:15 0.25 3,010 3,010 INTRMI DRILL OWFF T Monitor well- static. Pump a 20 bbl dry job (11.1 ppg). Pumping 45 spm w/ 750 si-26% flow out. 13:15 14:00 0.75 3,010 648 INTRMI DRILL TRIP T Trip out. Monitor well on the trip tank. Obtain PU and SO wt's every 5 stands. 14:00 14:45 0.75 648 74 INTRM1 DRILL PULD T UD BHA. Calculated fill 23.4 bbls, actual fill 32 bbls. 14:45 15:45 1.00 74 20 INTRM1 DRILL PULD T Download Sperry Sun MWD. -~ ~.®.®~e ~ ~ 1 ~'a:~e':~ z~f 4~ Time Logs _ ____ _ __ _ Date From To Dur S Ge th E. De th Phase Code Subcode T Comment ~- T - - - - 15:45 16:45 1.00 20 0 INTRM1 DRILL SVRG P Service rig: Top drive, blocks and drawworks. 16:45 17:15 0.50 0 0 INTRM1 DRILL PULD T Service Smith Rhino reamer and S er Sun Geo Pilot. 17:15 20:00 2.75 0 0 INTRM1 DRILL SVRG T Waiting on HTC bit. Service rig: Clean suction screens on #1  mud pumps, rebuild spare mix pump #2, inspect drawworks, service rig floor glycol syestem, inspect and service iron roughneck, inspect weekly SPCC target area, inspect stabbin board. 20:00 20:45 0.75 0 255 INTRMI DRILL PULD T PU/MU BHA #4. 20:45 21:15 0.50 255 255 INTRM1 DRILL DHEQ T Shallow pulse test Sperry Sun MWD and Geopilot. Pumping 250 gpm w/ 630 si-30% flow out. 21:15 21:30 0.25 255 653 INTRM1 DRILL PULD T Continue to PU/MU BHA #4. 21:30 23:00 1.50 653 3,580 INTRM1 DRILL TRIP T Trip in the hole. Displacement is correct. 23:00 23:15 0.25 3,580 3,663 INTRMI DRILL CIRC T Fill pipe, obtain drilling parameters, obtain slow pump rates @ 3580'. Wash to bottom 3663'. 23:15 00:00 0.75 3,663 3,674 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun Geopilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed by EPOCH 281 units on bottom's up. EPOCH gas 114 units max while drilling. Pumped a 30 bbl sweep (9.3 ppg/60 vis w/ medium nut plug 10ppb) @ 3,577' Purpose to clean tools- with minimal im rovement. 2/26/2009 Continue to directional drill with 6-3/4" bit, Geopilot and 7-1/2" Rhino Reamer from 3674' to 4768' at midnight. Note: Extreme) Slow ROP from 4710' to 4785' 43'/hr at 4710', 11'/hr 4752' 00:00 06:00 6.00 3,674 3,881 INTRMI DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun Geopilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Gas observed by EPOCH 52 units max while drilling. Note: Pumping 30 bbl nut plug sweep to control bit balling. Effectiveness- OK. 06:00 12:00 6.00 3,881 4,176 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun Geopilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Gas observed by EPOCH 159 units max while drilling. Note: Pumping 30 bbl nut plug sweeps to control bit balling. Effectiveness- OK. ®~e®~ ~ - ~ 1~~~~ 1 ~ ct s3 ~ ~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:00 18:00 6.00 4,176 4,538 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Gas observed by EPOCH 62 units max while drilling. Note: Pumping 30 bbl nut plug sweeps to control bit balling. Effectiveness- OK. 18:00 00:00 6.00 4,538 4,768 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Gas observed by EPOCH 62 units max while drilling. Note: Pumping 30 bbl nut plug sweeps to control bit balling. Effectiveness- OK. 2/27/2009 Continue to directional drill with 6-3/4" bit, GeoPilot and 7-1/2" Rhino Reamer from 4768' to 4898', backream to clean hole/bit from 4898' to 4710', wash in the hole to 4898', continue to directional drill with 6-3/4" bit, GeoPilot and 7-1/2" Rhino Reamer from 4898' to 5651'. 00:00 06:00 6.00 4,768 4,889 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed by EPOCH 25 units max while drilling. Note: Pumping 30 bbl nut plug sweeps to control bit balling. Effectiveness- OK. 06:00 07:00 1.00 4,889 4,898 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed by EPOCH 34 units max while drillin . 07:00 07:30 0.50 4,898 4,710 INTRM1 DRILL REAM P BROOH pumping @ 300 gpm, 1330 psi-30% flow out, 120 RPM with 4K ftllbs of for ue 07:30 07:45 0.25 4,710 4,898 INTRM1 DRILL WASH P Rotate and wash in hole @ 265 gpm, 1120 psi- 29% flow out, 120 rpm with 4K ft/Ibs of for ue 07:45 12:00 4.25 4,898 5,049 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed by EPOCH 34 units max while drillin . 12:00 18:00 6.00 5,049 5,357 INTRM1 DRILL DDRL P Directional drill 6-3l4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed by EPOCH 60 units max while drillin . ~~_..~ Pa;;e 1e"s of 4 C~ J Time Lomas __ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 18:00 00:00 6.00 5,357 5,651 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed by EPOCH 29 units max while drillin . 2/28/2009 Continue to directional drill with 6-3/4" bit, GeoPilot and 7-1/2" Rhino Reamer from 5651' to 5922', backream to reduce ECD's from 5900' to 5559' (pumped 30 bbl high vis sweep with nut plug), trip in the hole, continue to drill from 5922' to 6100', Pump out of the hole to 5181', trip into 6031', precautionary ream to 6100', directional drill to 6123', obtain slow pump rates, monitor well- static, pull out of the hole on elevators to 5087', monitor well- static, pump a dry job, pull out of the hole to BHA, work BHA, break bit, download Sperry Sun MWD, lay down MWD, clean floor, pull wear bushing, set FMC test plug w/ 3-1 /2" test joint, fill stack with water, be in testin BOPE Witness of test waived b AOGCC ins ector Bob Noble 00:00 06:00 6.00 5,651 5,922 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed by EPOCH 35 units max while drillin . 06:00 07:30 1.50 5,922 5,559 INTRM1 DRILL REAM P Backream out of the hole from 5900' to 5559' to help reduce ECD's. Pumping 350 gpm w/ 2220 psi- 35% flow out. Rotate 130 rpm w/ 5500 ft Ibs of torque. Pumped a 30 bbl high vis sweep w/ 10 ppb nut plug- some benefit. 07:30 07:45 0.25 5,559 5,845 INTRM1 DRILL TRIP P Trip in the hole. 07:45 08:00 0.25 5,845 5,922 INTRM1 DRILL CIRC P Make a top drive connection. Fire up the mud pumps, wash/ream to bottom @ 5922'. Pumping 300 gpm w/ 1350 psi-30% flow out. Rotate 130 r m w/ 5k ft Ibs of for ue.. 08:00 13:00 5.00 5,922 6,100 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed by EPOCH 26 units max while drillin . 13:00 14:45 1.75 6,100 5,181 INTRM1 DRILL TRIP P Pump 10 stands out of hole @ 330 GPM, 2200 PSI- 33% flow out. PU wt 150k, SO wt 108k. 14:45 15:00 0.25 5,181 6,100 INTRM1 DRILL TRIP P TIH to bottom, washing down last stand. While precautinary reaming 6031' to 6100': pumping 285 gpm w/ 1900 psi-33% flow out. Rotate 130 r m w/ 5k ft Ibs of for ue. 15:00 16:30 1.50 6,100 6,123 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed by EPOCH 50 units max while drillin . 16:30 17:00 0.50 6,123 6,123 INTRM1 DRILL OWFF P Monitor well -Static. Obtain SPRs 17:00 18:00 1.00 6,123 5,087 INTRM1 DRILL TRIP T TOOH on elevators monitoring on trip tank. Record PU and So wt's every 5 stands. PU wt 145k, So wt 112k. ~~ P~c~~: 17 €sf ~ Time Logs _ I Date From To Dur S Depth E. Depth Phase Code Subcode T__ Comment 18:00 18:15 0.25 5,087 5,087 INTRM1 DRILL OWFF T Monitor well- static. Pump a 20 bbl dry job (11.3 ppg). Pumping 48 spm w/ 770 si-26% flow out. 18:15 20:30 2.25 5,087 650 INTRMI DRILL TRIP T Trip out of the hole on elevators. Monitor well on the trip tank. Record PU and SO wt's eve 5 stands. 20:30 21:15 0.75 650 0 INTRM1 DRILL TRIP T Stand back HWDP, jars and drill collars. Lay down Smith 7-1/2" Rhino Reamer, stabilizer and float sub. Break Smith 6-3/4" bit. 21:15 22:00 0.75 0 0 INTRM1 DRILL OTHR T Download Sperry Sun MWD. 22:00 22:15 0.25 0 0 INTRM1 DRILL PULD T Continue to lay down Sperry Sun MWD and eo ilot. 22:15 22:45 0.50 0 0 INTRM1 DRILL OTHR T Clean and clear rig floor. 22:45 23:00 0.25 0 0 INTRM1 DRILL OTHR P Pull FMC wear bushing. 23:00 23:30 0.50 0 0 INTRM1 DRILL RURD P Rig up to test BOPE: Set test plug w/ 3-1/2" test joint, fill stack with water. 23:30 00:00 0.50 0 0 INTRM1 DRILL BOPE P Start testing BOPE with 3-1/2" test joint. Witness of test waived by AOGCC ins ector Bob Noble. 3/01 /2009 Continue testin BOPE Witness of test waived b AOGCC ins ector Bob Noble . Testin with 3-1/2" ' 5.5" test ~oints. Tested upper (3-1/2' x 6") and lower pipe (3-1/2" x 6") rams and annular to 250 psi low and 3500 psi high. Held all tests f/ 5 min each. Charted tests. Tested all valves in the choke manifold, all valves on kill line and choke lines. Tested 3-1/2" IF and 4" XT39 floor safety valves and dart valves. Tested top drive upper and lower IBOP. Performed accumulator test. Note: Lower pipe rams failed to test on 5-1/2", replaced packers on the 3-1 /2" x 6" variables, tested 250 psi low and 3500 psi high with 3-1/2", 4" and 5-1/2" test joint.- good. Finish testing @ 1015 hrs. Note: Entire Kuparauk field in phase 3 @ 0745 hrs. Rig down testing equipment, blow down lines, install FMC wear bushing, run in (2) lockdown screws. Chan a oil in the to drive. Clean and or anize around ri while in hase 3 weather. 00:00 05:00 5.00 0 0 INTRM1 DRILL BOPE P Continue testing BOPE (Witness of test waived by AOGCC inspector Bob Noble). Testing with 3-1/2", 4" and 5.5" test joints. Tested upper (3-1/2' x 6") and lower pipe (3-1/2" x 6") rams and annular to 250 psi low and 3500 psi high. Held all tests f/ 5 min each. Charted tests. Tested all valves in the choke manifold, all valves on kill Tine and choke lines. Tested 3-1/2" IF and 4" XT39 floor safety valves and dart valves. Tested to drive u er and lower IBOP. 05:00 06:00 1.00 0 0 INTRM1 DRILL BOPE P While testing lower pipe rams with the 5-1 /2" test joint, could not get a test- low or high-leaking. Pulled test joint, observed scar marks on jt. Ran back in with 3-1/2" test joint, cycle rams against 3-1/2" test joint, pull 3-1/2", install 5-1/2" test joint with another 4-1 /2" pup to change test area on the joint., attemept another test, still not holdin . ~~ ~~:~e 18 of ~~ ~~ ~ J Time Logs Date From To___ Dur_ _ S,De th E. D~th Phase __ Gode Subcode T _ Comment 06:00 07:30 _ . 1.50 0 0 INTRM1 DRILL BOPE P Open doors on lower pipe rams, remove the 3-1 /2" x 6" variable rams, replace packers. Note: Entire Kuparauk field in phase 3 @ 0745 hrs. Note: Service drawworks, top drive and blocks. 07:30 10:15 2.75 0 0 INTRM1 DRILL BOPE P Test lower pipe rams 250 psi low and 3500 psi high with 3-1/2", 4" and 5-1 /2" test joint.- good. Test accumulator :Full charge 3050 psi, after closing 1550 psi, 200 psi buildup in 52 seconds, full charge in 3 minutes 18 seconds.. 10:15 10:45 0.50 0 0 INTRM1 DRILL RURD P Rig down testing equipment, blow down lines, install FMC wear bushin ,run in 2 lockdown screws. 10:45 00:00 13.25 0 0 INTRM1 DRILL OTHR T While waiting on phase 3 weather: Change oil in the top drive. Clean and or anize around ri . 3/02/2009 Clean and organize around rig while in phase 3 weather, PU/MU BHA, upload MWD, shallow test, RIH to 935', Rotate through TAM port collar, continue RIH to 3139', test Rhino Reamer, circulate bottom's up, continue RIH to 4520' fill pipe, circulate bottom's up, RIH to 6034', circulate bottom's up, directional drill with 6-3/4" bit, GeoPilot and 7-1/2" Rhino Reamer from 6123' to 6380', trouble shoot slight loss of pump pressure, continue to directional drill from 6380' to 6734'. Note: Weather changed from Phase 3 to 2 @ approx 0100 hrs, then to normal on main roads (including all the way to 2N) @ 0600 hrs 3/2/2009. Note: Moved EPOCH shack so coiled tubin ri could work on a well, ri ed EPOCH back u and runnin . 00:00 01:00 1.00 0 0 INTRM1 DRILL OTHR T Phase 3 weather: Clean and or anize on the ri . 01:00 01:45 0.75 0 41 INTRM1 DRILL PULD T Pick up/ make up BHA. 01:45 02:30 0.75 41 41 INTRM1 DRILL OTHR T Upload MWD. 02:30 02:45 0.25 41 300 INTRM1 DRILL PULD T Continue to make up BHA. 02:45 03:15 0.50 300 300 INTRM1 DRILL DHEQ T Shallow pulse test, blow down top drive. 03:15 03:30 0.25 300 650 INTRM1 DRILL PULD T Continue to make up BHA. 03:30 03:45 0.25 650 935 INTRM1 DRILL TRIP T Trip in the hole w/ 4"drill pipe to 935' 03:45 04:15 0.50 1,027 1,123 INTRM1 DRILL CIRC T Pump to check Geo Pilot deflection before going through TAM port collar. Rotate through w/ bit and Rhino Reamer. 04:15 05:45 1.50 1,123 3,139 INTRM1 DRILL TRIP T Trip in the hole. 05:45 06:00 0.25 3,139 3,139 INTRM1 DRILL CIRC T Fill pipe, Pull test Rhino Reamer (Good), circulate bottom's up. Pumping 300 gpm w/ 1610 psi-30% flow out. Pum ed 224 bbls. 06:00 07:00 1.00 3,139 4,520 INTRM1 DRILL TRIP T Trip in the hole. ?~ag~ 1~ of ~~ ~~ ~ J Time Logs D~te _ _ ___ From To Dur S,_D~t_h_ E, D~th -__ Phase Code Subcode T --- Comment 07:00 08:00 1.00 4,520 4,520 INTRM1 DRILL _ CIRC _ T Fill pipe, circulate bottom's up. Pumping 275 gpm w/ 1580 psi-31% flow out. Rotate 50 rpm w/ 4k ft Ibs of torque. Pumped 205 bbls. bbls. PU wt 138k, SO wt 110k, Rot wt 120k.Max gas observed by EPOCH 234 units. 08:00 08:30 0.50 4,520 6,034 INTRM1 DRILL TRIP T Trip in the hole. 08:30 09:15 0.75 6,034 6,123 INTRM1 DRILL CIRC T Fill pipe, circulate bottom's up. Pumping 330 gpm w/ 2350 psi-34% flow out. Rotate 120 rpm w/ 6k ft Ibs of torque. Pumped 220 bbls. bbls. PU wt 158k, SO wt 115k, Rot wt 130k.Max gas observed by EPOCH 172 units. 09:15 12:00 2.75 6,123 6,263 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed b EPOCH 84 units. 12:00 15:00 3.00 6,263 6,380 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed b EPOCH 27 units. 15:00 16:00 1.00 6,380 6,380 INTRM1 DRILL CIRC P Noticed a slow 200 psi decrease in pump pressure over a one hour time period. Trouble shooting: switch to # 1 mud pump- same, pressure test surface equipment, including geo skid to 3500 psi-ok. Clean suction screens, compare slow pump rates- 20 si increase in ressure. 16:00 18:00 2.00 6,380 6,458 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed b EPOCH 27 units. 18:00 00:00 6.00 6,458 6,734 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed b EPOCH 71 units. 3/03/2009 Continue to directional drill with 6-3/4" bit, GeoPilot and 7-1/2" Rhino Reamer from 6734' to 7165', hole packing off- pump out to 6689', pump in the hole to 7165', resume drilling from 7165' to 7550', service swivel ackin , resume drillin f/ 7550' to 7702'. 00:00 06:00 6.00 6,734 6,973 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed b EPOCH 88 units. 06:00 10:00 4.00 6,973 7,165 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed b EPOCH 88 units. Time Logs -- Date From To_____ Our S. De th E. Depth__ _Phase Code - Subcode T -_ _~ - Comment - -- 10:00 11:45 _ , 1.75 7,165 . 7,165 INTRM1 DRILL TRIP _ P Packed off while drilling. Did a 5 stand wiper trip pumping out with 340 gpm and 2180 psi- 34% flow out. RIH, pumping 250 gpm with 1420 psi-31 % flow out. PU wt w! pumps on 162k, SO wt w/ um s 112k. 11:45 12:00 0.25 7,165 7,173 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed b EPOCH 117 units. 12:00 18:00 6.00 7,173 7,447 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed by EPOCH 118 units. Note:Layed down and replaced top sin le on stand #71 bad box . 18:00 21:00 3.00 7,447 7,550 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed b EPOCH 80 units. 21:00 21:30 0.50 7,550 7,550 INTRM1 DRILL SVRG P Stand back a stand. Service swivel ackin . PU/MU/ RIH stand. 21:30 00:00 2.50 7,550 7,702 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed b EPOCH 84 units. 3/04/2009 Continue to directional drill with 6-3/4" bit, GeoPilot and 7-1/2" Rhino Reamer from 7702' to 8486', POOH to 8391', blow down the top drive, change swivel packing, obtain slow pump rates, RIH from 8391' to 8486', continue to drill from 8486' to 8977'. 00:00 06:00 6.00 7,702 8,030 INTRMI DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed b EPOCH 88 units. 06:00 12:00 6.00 8,030 8,391 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed b EPOCH 313 units. 12:00 13:45 1.75 8,391 8,486 INTRM1 DRILL DDRL P Directional drill 6-3l4" hole with Sperry Sun GeoPi-ot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed b EPOCH 510 units. 13:45 14:00 0.25 8,486 8,391 INTRM1 DRILL TRIP P Pull out of the hole a stand to than a the to drive swivel ackin . 14:00 14:30 0.50 8,391 8,391 INTRM1 DRILL SVRG P Change swivel packing. 14:30 14:45 0.25 8,391 8,486 INTRM1 DRILL TRIP P Obtain Slow pump rates, trip in the hole with a stand of 4" drill pipe. Make a to drive connection. Pace2 ~1 ~t ~~ Time Logs I 'Date From To Dur S De th E De th Phase Code Subcode T __ __ _ _ _ ___________ Comment 14:45 18:00 3.25 8,486 8,695 INTRM1 _ DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed b EPOCH 398 units. 18:00 00:00 6.00 8,695 8,977 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed b EPOCH 83 units. 3/05/2009 Continue to directional drill with 6-3/4" bit GeoPilot and 7-1/2" Rhino Reamer from 8977' to 9323' lost partial returns ,flow check- static losses of 30-35 bph, lower mud weight from 11.2 ppg to 9.7 ppg, pump a 55 bbl / 20 ppb LCM pill, monitor well on trip tank, pump another 56 bbl / 25 ppb LCM pill, blow down the top drive, pull out of the hole from 9250' to 8205', pump a dry job, continue to pull out of the hole from 8205' to 6600', hole swabbing, Pump out of the hole from 6600' to 4901' (2.3 bpm w/ 430 psi while pulling pipe, appeared to have full returns @ 4901'. Circulate bottom's up pumping 4 bpm w/ 670 psi, stage up to 330 gpm w/ 1640 psi-31 % flow out. Blow down the top drive, change out the saver sub on the top drive, circulate bottom's up staging up from 170 to 330 gpm, trip in the hole 10 stands to 5937', circulate staging pumps up to final of 330 m, tri in to 6880', circulate same as revious-full returns. 00:00 06:00 6.00 8,977 9,297 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed b EPOCH 44 units. 06:00 07:00 1.00 9,297 9,323 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed b EPOCH 44 units. 07:00 07:30 0.50 9,323 9,323 INTRM1 DRILL OWFF T While drilling, lost 12% flow while pumping 325 gpm. Stop drilling, pick up, check for flow- falling. Monitor well on the trip tank- 30-33 bph losses static. 07:30 09:00 1.50 9,323 9,323 INTRM1 DRILL CIRC T Lower mud weight in the pits from 11..2 ppg to 9.7 ppg. Circulate @ 3 bpm w/ 660 psi-1 % flow out. Rotate and reciprocate from 9320' to 9250'. Pump a 55 bbl LCM pill (20 ppb LCM) @ 3 bpm w/ 650 psi-0% flow out. PU wt 190k, SO wt 120k. Once LCM was in the BHA, increase pump rate to 336 gpm w/ 2760 psi-0% flow out. Pum ed a total of 220 bbls. 09:00 10:00 1.00 9,323 9,323 INTRM1 DRILL OWFF T Monitor well on the trip tank while buildin another LCM ill. 10:00 10:45 0.75 9,323 9,323 INTRM1 DRILL CIRC T Pump a 56 bbl LCM pill (25 ppb LCM- 10.1 ppg/43 vis) @ 126 gpm w/ 650 psi-12% flow out. Rotate 50 rpm w/ 9k ft Ibs of for ue. 10:45 11:45 1.00 9,323 8,205 INTRM1 DRILL TRIP T Pull a stand, blow down the top drive, pull out of the hole on elevators from 9250' to 8205'. PU wt 195k, SO wt 118k. Keeping hole full with trip tank um . Time Logs Date Frorn To Dur ___ SDepth__ E_~th Phase Code Subcode_ T_ Comment __ ___ 11:45 12:15 0.50 8,205 8,205 INTRM1 DRILL CIRC T Pump a dry job (12 ppg). Pumping 126 gpm w/ 650 psi-0% flow out. Blow down the to drive. 12:15 14:00 1.75 8,205 6,600 INTRM1 DRILL TRIP T Continue to pull out of the hole from 8205' to 6600'. Fill the hole with the tri tank. 14:00 16:00 2.00 6,600 4,901 INTRM1 DRILL TRIP T Hole started swabbing while pulling pipe. Pumped out of the hole, pumping 97 gpm w/ 430 psi-22% flow out. 16:00 17:30 1.50 4,901 4,901 INTRM1 DRILL CIRC T Appear to have full returns @ 4901'. Pump168 gpm w/ 670 psi-22% flow out. stage pumps up from 168 gpm to 330 gpm w/ 1640 psi-31 % flow out. Pum ed a total of 347 bbls. 17:30 19:30 2.00 4,901 4,901 INTRM1 DRILL SVRG T Blow down the top drive. Proceed with changing the saver sub on the top drive. (XT39). Monitor well on the tri tank. 19:30 20:30 1.00 4,901 4,996 INTRM1 DRILL CIRC T Circulate, stage pumps up to 330 gpm w/ 1650 psi-32% flow out. Rotate 100 rpm w/ 5-6k ft Ibs of torque. Circulated a totatl of 320 bbls. No losses observed. 20:30 21:00 0.50 4,996 5,940 INTRM1 DRILL TRIP T Trip in the hole 10 stands to 5940'. 21:00 22:45 1.75 5,940 5,940 INTRM1 DRILL CIRC T Circulate, stage pumps up to 330 gpm w/ 1800 psi-31 to 32% flow out. Circulated a total of 584 bbls. Max gas observed on bottom's up by EPOCH was 425 units. 22:45 23:15 0.50 5,940 6,880 INTRM1 DRILL TRIP T Trip in the hole 10 stands to 6880'. 23:15 00:00 0.75 6,880 6,880 INTRM1 DRILL CIRC T Circulate, stage pumps up to 330 gpm w/ 1850 psi-31 to 32% flow out. Circulated a total of 584 bbls. Max gas observed on bottom's up by EPOCH was 425 units. Note: Mud losses from 0600 to 1800 hrs 3-5-2009 were 633 bbls, no aparent losses from 1800 to 0600 hrs 3-6-2009. 3/06/2009 Continue to circulate bottom's up staging up from 170 to 330 gpm @ 6880', trip in the hole 10 stands to 7825', circulate as previous- full returns, trip in the hole 10 stands to 8768', circulate as previous- full returns, trip in the hole 5 stands to 9240', circulate as previous- full returns, obtain slow pump rates, make a connections, ream to bottom @ 9323', directional drill with 6-3/4" bit. GeoPilot and 7-1/2" Rhino Reamer from 9323' to ;, circulate bottoms up, survey, pump a 50 bbl high vis sweep, circulate 3 bottom's up, blow down the top drive, monitor well, circulate to even MW @ 9.7 ppg, monitor well, blow down top drive, pull out of the hole 15 stands (correct fill-8 bbls , um a d 'ob, ull out of the hole 15 stands, correct fill-9 bbls . Faye 2~ s~f ~€~ ~.....~ Time Logs ___ __ __ _ __ Date Frorn To Dur S De th E. De th Phase Code Subcode T Comment 00:00 01:00 1.00 6,880. 6,880 INTRM1 DRILL CIRC T Continue to circulate, stage pumps up from 168 gpm w/ 740 psi-20% flow out, to 330 gpm w/ 1850 psi-31 to 32% flow out. Circulated a total of 584 bbls. Max gas observed on bottom's up by EPOCH was 684 units. Rot wt 130k, Rot 100 rpm w! 6500 ft Ibs of torque. Final ECD's were 10.78 ppg w/ 9.7 ppg all the wa around. 01:00 01:30 0.50 6,880 7,825 INTRM1 DRILL TRIP T Trip in the hole 10 stands to 7825'. 01:30 03:00 1.50 7,825 7,825 INTRM1 DRILL CIRC T Circulate, stage pumps up from 168 gpm w/ 850 psi-20% flow out, to 330 gpm w/ 2160 psi-31 to 32% flow out. Circulated a total of 584 bbls. Max gas observed on bottom's up by EPOCH was 670 units. Rot wt 140k, Rot 100 rpm w/ 7000-8000 ft Ibs of torque. Final ECD's were 10.95 ppg w/ 9.7 all the wa around. 03:00 03:30 0.50 7,825 8,768 INTRM1 DRILL TRIP T Trip in the hole 10 stands to 8768'. 03:30 05:00 1.50 8,768 8,768 INTRM1 DRILL CIRC T Circulate, stage pumps up from 168 gpm w/ 850 psi-22% flow out, to 330 gpm w/ 2200 psi-31 to 32% flow out. Circulated a total of 504 bbls. Max gas observed on bottom's up by EPOCH was 305 units. Rot wt 140k, Rot 100 rpm w/ 8000-8500 ft Ibs of torque. Final ECD's were 10.87 ppg w/ 9.7 all the wa around. 05:00 05:15 0.25 8,768 9,240 INTRM1 DRILL TRIP T Trip in the hole 5 stands to 9240'. 05:15 06:30 1.25 9,240 9,240 INTRM1 DRILL CIRC T Circulate, stage pumps up from 168 gpm w/ 850 psi-20% flow out, to 330 gpm w/ 2200 psi-31 to 32% flow out. Circulated a total of 433 bbls. Max gas observed on bottom's up by EPOCH was 182 units. Rot wt 140k, Rot 100 rpm w/ 8000-8500 ft Ibs of torque. Values with no Pump: PU wt 185k, SO wt 123k, Rot wt 147k, Rot torque 8500 ft Ibs. Final ECD's were 10.73 ppg w/ 9.7 ppg all the way around. 06:30 06:45 0.25 9,240 9,240 INTRM1 DRILL CIRC T Obtain slow pump rates w/ 9.7 ppg MW @ 9240'. Both pumps, 20 and 30 s m. 06:45 07:00 0.25 9,240 9,323 INTRM1 DRILL REAM T Make a top drive connection. Wash and ream from 9240' to 9323'. Pumping 330 gpm w/ 2250 psi-31-32% flow out, rotate 100 rpm w/ 9500 ft Ibs of torque. Max gas observed b EPOCH 58 units. ~_ ?<asl~ 2~ ~( ~f3 r~ ~~ Time Logs Date From To Dur_ _ S. Depth _ E_ Depth Phase Code Subcode T _ Comment 07:00 12:00 5.00 9,323 9,632 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed b EPOCH 236 units. 12:00 14:00 2.00 9,632 9,783 INTRM1 DRILL DDRL P Directional drill 6-3/4" hole with Sperry Sun GeoPilot and a Smith Rhino Reamer(95' behind bit) to enlarge hole to 7-1/2". Max gas observed by EPOCH 150 units. TD of hole section. Will run 5-1/2" casing, then drill with same. 9783' MD = 5115' TVD. 14:00 14:45 0.75 9,783 9,783 INTRM1 DRILL CIRC P Rotate and reciprocate while circulating bottom's up. Rotate 130 rpm w/ 7k ft Ibs of torque. Circulated 371 bbls. Max gas observed by EPOCH was 192 units. 14:45 15:30 0.75 9,783 9,783 INTRM1 DRILL SRVY P Stand back a stand, acquire MWD survey @ 9663', make connection, run in the hole to TD @ 9783' (5115' TVD 15:30 17:30 2.00 9,783 9,783 INTRM1 DRILL CIRC P Pump 50 bbl sweep high vis sweep (9.7 ppg/234 vis/ 20 ppb LCM 10 ppb dynaRed med & 10 ppb calcarb 500). Rotate 130 rpm w/ 7k ft Ibs of torque and reciprocate from 9783' to 9711', while circulating 335 gpm w/ 2570 psi-33% flow out. Pumped a total of 1420 bbls. Max gas observed by EPOCH was 147 units. PU wt 175k, SO wt 130k. 17:30 18:30 1.00 9,783 9,783 INTRM1 DRILL OWFF P Blow down the top drive. Monitor well- sli ht flow. 18:30 21:00 2.50 9,783 9,783 INTRM1 DRILL CIRC P Circulate to even out mud weight from 9.5 ppg to 9.7 ppg. Rotate 100 rpm w17500k ft Ibs of torque and reciprocate from 9783' to 9711', while circulating 335 gpm w/ 2570 psi-33% flow out. Final ECD was 10.88 ppg. Pumped a total of 1174 bbls. Max gas observed by EPOCH was 110 units. PU wt 180k, SO wt 132k, Rot wt 151 k. 21:00 21:30 0.50 9,783 9,783 INTRM1 DRILL OWFF P Obtain slow pump rates w/ 9.7 ppg mud @ 9783' (5115' TVD). Monitor well- static. Blow down the to drive. 21:30 22:45 1.25 9,783 8,394 INTRM1 DRILL TRIP P Pull out of the hole 15 stands, monitor well on the trip tank. Calculated 8 bbls, actual 8 bbls. No obstructions or over ull. 22:45 23:00 0.25 8,394 8,394 INTRM1 DRILL OWFF P Monitor well- static. 23:00 23:15 0.25 8,394 8,394 INTRM1 DRILL CIRC P Pump a dry job. Blow down the top drive. Faye 25 rsf ~ gate __ From To Dur _ S Depth E. Depth Phase Code Subcode T Comment 23:15 00:00 0.75 8,394 6,975 INTRM1 DRILL TRIP P Pull out of the hole 15 more stands, rack back a total of 30 stands of 4" in the derrick. Monitor well on the trip tank. Calculated 8 bbls, actual 9 !/07/2009 bbls. Pre job safety meeting on pulling out of the hole, laying down 4"drill pipe, lay down drill pipe f/ 6975' to 3010' , PJSM, service the top drive, PJSM, slip and cut drilling line, PJSM, pulling out of the hole laying down 4"drill pipe f/ 3010' to BHA @ 653', lay down BHA, clear floor, pull FMC wear bushing, change the saver sub on the top drive to 4-1/2" IF, PJSM, RU to run 5-1/2" 15.5 pf L-80 Hyd 563 casing, rig up TESCO casing running tool ' and Frank s flush mounted slips, PJSM, Run 5-1/2" 15.5 ppf L-80 Hyd 563 casing per plan to shoe circulate , BU, continue to run casin to 5063' ~t # 122 in the hole. 00:00 00:30 0.50 6,975 6,975 INTRM1 DRILL SFTY P Pre job safety meeting on pulling out 00:30 03:30 3.00 6,975 3,010 INTRM1 DRILL TRIP P of the hole/ la in down 4"drill i e. Pull out of the hole/ laying down 4" drill pipe to the pipe shed. Monitor well on the trip tank. Calculated fill to this point is 39 bbls, actual is 44.5 bbls 03:30 03:45 0.25 3,010 3,010 INTRM 1 DRILL SFTY P . Pre job safety meeting on service top drive 03:45 05:30 1.75 3,010 3,010 INTRM 1 DRILL SVRG P Service the VARCO TDS-8 top drive. 05:30 05:45 0.25 3,010 3,010 INTRM1 DRILL SFTY P Pre job safety meeting on slip and 05:45 06:30 0.75 3,010 3,010 INTRM1 DRILL SLPC P cut drillin line. Slip and cut 82' of 1-3/8"drilling line. Service the top drive. Monitor well on the trip tank- hole taking 1/2 bph 06:30 06:45 0.25 3,010 3,010 INTRM1 DRILL SFTY P static. Pre job safety meeting on pulling out of the hole, laying down 4" drill pipe 06:45 08:45 2.00 3,010 653 INTRM1 DRILL TRIP P to the i e shed. Pull out out of the hole f/ 3010' to 653', laying down 4"drill pipe to the 08:45 09:00 0.25 653 227 INTRM1 DRILL TRIP P i e shed. Lay down HWDP and jars. Monitor 09:00 09:15 0.25 227 227 INTRM1 DRILL OWFF P well on the tri tank. Monitor well- static. 09:15 09:30 0.25 227 93 INTRM1 DRILL PULD P Lay down BHA f/ 227' to 93', monitor 09:30 10:30 1.00 93 93 INTRM1 DRILL OTHR P well on the tri tank. Download Sperry Sun MWD. 10:30 11:15 0.75 93 0 INTRM1 DRILL PULD P Continue to lay down BHA f/ 93' to out of the hole. Calculated fill for whole trip is 65 bbls, actual is 77 11:15 11:45 0.50 0 0 INTRM1 DRILL OTHR P bbls. 12 bbls over calculated. Clear and clean rig floor. Closed blind rams. 11:45 12:00 0.25 0 0 I NTRM1 DRILL OTHR P Pull the FMC wear bushing. 12:00 13:00 1.00 0 0 I NTRM1 DRILL OTHR P Change out the saver sub on the top 13:00 13:15 0.25 0 0 I NTRM1 DRILL SFTY P drive from XT-39 to 4-1/2" IF. Pre job safety meeting on rigging up TESCO casing running tool f/ 5-1//2" 13:15 14:45 1.50 0 0 I NTRM1 CASING RURD P casin External bite runnin tool). Rig up to run 5-1/2" casin w/ TESCO casing running tool and Frank's flush mounted slios. ~`~t~& 26 c=~ ~#~ l~ Time Logs Date From 7o Dur _ S__De~th E nth Phase Code Subcode T_ Comment _ ,____ i 14:45 15:00 0.25 0 0 INTRM1 CASING SFTY P Pre job safety meeting on running 5-1 /2" 15.5 f L-80 H d 563 casin . 15:00 15:30 0.50 0 150 INTRMI CASING RNCS P Run 5-1/2" casing: First joint w/ Hughes 6-3l4" shoe/bit (EZC504ZX, ser # 7016685, w/ (4) 10/32" jets and a 3000 psi shear disc, P/N TE 17005) (Joint has 6-3/4" Wear Sox stabilizer 10' and 20' above the bit), joint # 2 with 6-3/4" Wear Sox stabilizer 5' above pin end, Weatherford double valve float collar (Mode1402 DS), then joint #3 with a wear 6-3/4" OD Wear Sox stabilizer 5' above pin. Make up jt # 4, check floats-ok. Baker locked to the pin end of jt #4, although the collars on the joints were not baker locked to the joints. Bit was torqued to 9600 ft Ibs and baker locked to the joint. Torqued connections to 15k ft Ibs of for ue. 15:30 15:45 0.25 150 490 INTRMI CASING RNCS P Continue to PU/MU/ RIH w/ 5-1/2" 15.5 ppf L-80 Hyd 563 casing (Jt# 5 thru #12. Torqued. connections to 15k ft Ibs of torque; used Jet Lube Seal Guard metal free standard grade service -20 de to 500 de doe . 15:45 16:00 0.25 490 490 INTRM1 CASING SFTY P Mid job safety meeting on running casin . 16:00 16:30 0.50 490 958 INTRM1 CASING RNCS P Continue to PU/MU/ RIH w/ 5-1/2" 15.5 ppf L-80 Hyd 563 casing (Jt# 13 thru #23. Torqued connections to 15k ft Ibs of torque; used Jet Lube Seal Guard metal free standard grade service (-20 deg F to 500 deg F do e . 16:30 17:00 0.50 958 1,154 INTRM1 CASING RNCS P Continue to PU/MU/ RIH w/ 5-1/2" 15.5 ppf L-80 Hyd 563 casing (Jt # 24 thru # 28. Torqued connections to 15k ft Ibs of torque; used Jet Lube Seal Guard metal free standard grade service (-20 deg to 500 deg dope). Rotated joints # 24 thru # 28 through the TAM port collar @ 1030' in the 7-5/8" surface casing. Rotate 30 r m w/ 1000k ft Ibs of for ue. 17:00 18:00 1.00 1,154 2,074 INTRM1 CASING RNCS P Continue to PU/MU/ RIH w/ 5-1/2" 15.5 ppf L-80 Hyd 563 casing (Jt # 29 thru # 50. Torqued connections to 15k ft Ibs of torque; used Jet Lube Seal Guard metal free standard grade service (-20 deg to 500 deg dope). Record PU, SO and Rot wt's eve 20 'ts. - ~ ~ -~~ ~ Pa~P 77 cif ~ ~~ l J Time Logs _ - - Date___ ____ -From To Dur S De th - E. Depth - Phase Code Subcode T -- _ Cor7iment______ _' 18:00 19:15 1.25 2,074 2,974 INTRM1 CASING RNCS P Continue to PU/MU/ RIH w/ 5-1/2" 15.5 ppf L-80 Hyd 563 casing (Jt # 51 thru # 71. Torqued connections to 15k ft Ibs of torque; used Jet Lube Seal Guard metal free standard grade service (-20 deg to 500 deg dope). Record PU, SO and Rot wt's eve 20 'ts. 19:15 19:30 0.25 2,974 2,974 INTRM1 CASING CIRC P Circulate bottom's up at the 7-5/8" shoe. Circulate 59 spm w/ 990 psi-29A% flow out. Circulated 90 bbls total. 19:30 19:45 0.25 2,974 3,281 INTRM1 CASING RNCS P Continue to PU/MU/ RIH w/ 5-1/2" 15.5 ppf L-80 Hyd 563 casing (Jt # 72 thru # 79. Torqued connections to 15k ft Ibs of torque; used Jet Lube Seal Guard metal free standard grade service (-20 deg to 500 deg dope). Record PU, SO and Rot wt's eve 20 ~ts. 19:45 20:45 1.00 3,281 3,272 INTRM1 CASING PULD T Lay down jt # 79 (Bad box- 40.53') and joint # 78 (cushed & bad box- 42.37'). replace with jt # 270-- 35.72' and 'oint # 271--37.83'. 20:45 23:15 2.50 3,272 4,606 INTRM1 CASING RNCS P Continue to PU/MU/ RIH w/ 5-1l2" 15.5 ppf L-80 Hyd 563 casing (Jt # 80 thru # 111. Torqued connections to 15k ft Ibs of torque; used Jet Lube Seal Guard metal free standard grade service (-20 deg to 500 deg dope). Record PU, SO and Rot wt's eve 20 'ts. 23:15 23:30 0.25 4,606 4,601 INTRM1 CASING PULD T Lay down jt # 111 (Bad box- 42.19') re lace with 't # 269-- 36.79' 23:30 00:00 0.50 4,601 5,063 INTRM1 CASING RNCS P Continue to PU/MU/ RIH w/ 5-1/2" 15.5 ppf L-80 Hyd 563 casing (Jt # 112 thru # 122. Torqued connections to 15k ft Ibs of torque; used Jet Lube Seal Guard metal free standard grade service (-20 deg to 500 deg dope). Record PU, SO and Rot wt's eve 20 ~ts. 3/08/2009 Continue to run 5-1/2" 15.5 ppf L-80 Hyd 563 casing f/ 5063' to 5400' Qt # 123 to jt #130), circulate- lost 80 bbls while circ, monitor well- breathed back 40 bbls, continue running casing f/ 5400' to to 5609' Qts # 131 to # 135), circulate staging pumps up from 85 gpm to 150gpm-losing 36 bph, continue running casing f/ 5609' to to 6438' (jts # 136 to # 155), circulate staging pumps up f/ 89 gpm to 175 gpm, run casing f/ 6438' to 7270' (jts # 156 to # 175), circulate pumping 100 gpm, run casing f/ 7270' to 8100' (jts # 176 to # 195), circulate pumping 100 gpm, run casing f! 8100' to 8940' (jts # 196 to # 215), circulate pumping 120 gpm, run casing f/ 8490' to 9770' (jts # 216 to # 235), circulate- stage up f/ 80 gpm to 150 gpm w/ approx 20 bph losses, drill with 5-1 /2" casing from 9783' to 9923' w/ 20 to 22 bph losses. Note: Fuid lost Midnight to 0600= 50 bbls, 0600 to 1800 hrs 141 bbsl, 1800 to midnight 110 bbls= total of 301 bbls. ..................~.~....~. ~ ~ ~ ..._. ~~ ~ -- P~~~ 2~ ~t 4~ l J _Time Logs _ _ __ ~~ Date From To Dur S. De th E De th Phase Code Subcode T Comment 00:00 00:30 0.50 5,063 5,400 INTRM1 CASING RNCS P Continue to PU/MU/ RIH w/ 5-1/2" 15.5 ppf L-80 Hyd 563 casing (Jt # 123 thru # 130. Torqued connections to 15k ft Ibs of torque; used Jet Lube Seal Guard metal free standard grade service (-20 deg to 500 deg dope). Record PU, SO and Rot wt's eve 20 ~ts: 00:30 01:30 1.00 5,400 5,400 INTRM1 CASING CIRC P Circulate, pumping 250 gpm w/ 1140 psi-25% flow out, reduced to 225 gpm w/ 950 psi-22% flow out, reduced rate to 200 gpm w/ 710 psi- 19%fiow out. Lost 80 bph while circulating. Pumped a total of 220 bbls. Gave back 40 bbls after pumps off. Flow out with pumps off 18% down to 1 % after 30 minutes. PU wt 132k, SO wt 108k, Rot wt 120k w/ 5500 ft Ibs of for ue. 01:30 02:00 0.50 5,400 5,400 INTRM1 CASING OWFF P Blow down the top drive, monitor well. Breathing back fluid lost. Flow out with pumps off 18% down to 1 after 30 minutes. 02:00 03:00 1.00 5,400 5,400 INTRM1 CASING OTHR P Daylight savings time- set clocks ahead one hour. 03:00 03:15 0.25 5,400 5,609 INTRM1 CASING RNCS P Continue to PU/MU/ RIH w/ 5-1/2" 15.5 ppf L-80 Hyd 563 casing (Jt # 131 thru # 135 . 03:15 04:00 0.75 5,609 5,609 INTRM1 CASING CIRC P Circulate, pumping 85 gpm w/ 440 psi- 19% flow out, pumping 125 gpm w/ 540 psi- 19 to 20% flow out, pumping 150 gpm w/ 550 psi- 20 to 21% flow out. Losin 36 b h. 04:00 05:45 1.75 5,609 6,438 INTRM1 CASING RNCS P Continue to PU/MU/ RIH w/ 5-1/2" 15.5 ppf L-80 Hyd 563 casing (Jt # 136 thru # 155). Running speed 40'/ min max. 05:45 07:00 1.25 6,438 6,438 INTRM1 CASING CIRC P Circulate, pumping 89 gpm w/ 380 psi-19% flow out, pumping 100 gpm w/ 400 psi-20% flow out, pumping 125 gpm w/ 460 psi-20% flow out, pumping 150 gpm w/ 600 psi-22% flow out, pumping 175 gpm w/ 750 psi- 22 to 24% flow out. Reciprocate from 6438' to 6396'. PU wt 132k, SO wt 102k, Rot wt 117k, torque with 80 r m is 6k ft Ibs. 07:00 08:00 1.00 6,438 7,270 INTRM1 CASING RNCS P Continue to PU/MU/ RIH w/ 5-1/2" 15.5 ppf L-80 Hyd 563 casing (Jt # 156 thru # 175 . 08:00 09:00 1.00 7,270 7,270 INTRM1 CASING CIRC P Circulate, pumping 100 gpm w/ 570 psi- 20% flow out. Reciprocate from 7270' to 7231'.PU wt 145k, SO wt 108k, Rot wt 121 k, torque with 80 r m is 7k ft Ibs. 09:00 10:00 1.00 7,270 8,100 INTRM1 CASING RNCS P Continue to PU/MU/ RIH w/ 5-1/2" 15.5 ppf L-80 Hyd 563 casing (Jt # 176 thru # 195 . P;~qe F9 ssf ~~3 l I • Time Logs Date From_ To Dur S. Depth E_Depth Phase Code Subcode T Comment 10:00 11:30 1.50 8,100 8,100 INTRM1 CASING CIRC P Circulate, pumping 100 gpm w/ 560 psi-20% flow out. Reciprocate from 8100' to 8060'. PU wt 156k, SO wt 110k, Rot wt 129k, torque with 80 r m is 7-9k ft lbs. 11:30 12:45 1.25 8,100 8,940 INTRM1 CASING RNCS P Continue to PU/MU/ RIH w/ 5-1/2" 15.5 ppf L-80 Hyd 563 casing (Jt # 196thru#215. 12:45 13:45 1.00 8,940 8,940 INTRM1 CASING CIRC P Circulate, pumping 100 gpm w/ 460 psi-21 % flow out, pumping 120 gpm w/ 530 psi-21 % flow out. Reciprocate from 8940' to 8899'. PU wt 165k, SO wt 111 k, Rot wt 130k, torque with 80 r m is 7-12k ft lbs. 13:45 14:45 1.00 8,940 9,770 INTRM1 CASING RNCS P Continue to PU/MU/ RIH w/ 5-1/2" 15.5 ppf L-80 Hyd 563 casing (Jt # 216 thru # 235 . 14:45 17:45 3.00 9,770 9,770 INTRM1 CASING CIRC P Circulate, pumping 80 gpm w/ 430 psi-21 % flow out. Reciprocate from 9770' to 9730'.PU wt 178k, SO wt 117k, Rot wt 138k, torque with 80 rpm is 7-12k ft lbs. Max gas observed b EPOCH was 234 units. 17:45 18:00 0.25 9,783 9,786 INTRM1 CSGDRI DCSG P Drill with 5-1/2" 15.5 ppf L-80 Hyd 563 casing from 9783' to 9786'. Weight on bit 5k, Rotate 80 rpm w/ 6-11 k ft Ibs of torque on, 6-11 k torque off. Pumping 175 gpm w/ 790 psi on, 750 psi off- 21 % flow out. Pumps off: PU wt 180k, SO wt 115k, Rot wt 145k. Actual drilling time .17 hrs. Total hours on the bit/shoe= .17 hrs. Max gas observed by EPOCH= 25 units 18:00 23:30 5.50 9,786 9,923 INTRM1 CSGDRI DCSG P Drill with 5-1/2" 15.5 ppf L-80 Hyd 563 casing from 9786' to 9923'. Weight on bit 5k, Rotate 80 rpm w/ 8-10k ft Ibs of torque on, 9-10k torque off. Pumping 175 gpm w/ 890 psi on, 780 psi off- 21 % flow out. Pumps off: PU wt 180k, SO wt 120k, Rot wt 145k. Actual drilling time 4.61 hrs. Total hours on the bit/shoe= .4.78 hrs. Max gas observed by EPOCH= 67 units 23:30 00:00 0.50 9,923 9,923 INTRM1 CSGDRI CIRC P Circulate bottom's up. Reciprocate from 9923' to 9900'. Pumping 100 gpm w/ 560 psi-20% flow out. Rotate 80 rpm w/ 9-10k ft Ibs of torque. Circulated a total of 71 bbls at midnight.The hole gave back 33 bbls while circulating at the reduced rate of 100 gpm, then stabilized while continuin to circulate. ~ ~_ ~ F'~~~ 3t3 s~f ~~ L~ Time Los - 9 i ~~ Date - _ - - - -------- --- From To Dur S De th E. Depth Phase Code Subcode T Comment - - P - -- - ----- - 3/09/2009 - - 2a hr Summary Continue to circulate bottom's up, lay down jt # 239, continue to circulate, lay down Jt # 238 & # 237, pick up (2) pup joints and (2) joints of 5-5/" 15.5 ppf L-80 Hyd 563 casing to 9921', Install casing cementing head and hoses, circulate, perform LOT to 11.9 ppg EMW, pre job safety meeting on cementing. Dowell/Schlumberger m 5 bbl wat r tes lines o 3 i mix and pump 128.5 bbls (617 sx .yield 1-17 cuft/sx. 5221 gal/sx mix waterl of 15.8 ooa class "G cement with additives, drop top plug, rig displaced with pumps @ 4 bpm until last 11.5 bbls, then slowed to 2 bpm, bumped plug w/ 500 psi over (1800 psi bump pressure), checked floats- good. monitor annulus-static. WOC f/ 6 hrs: rigging down ZTESCO and Frank's tools, RU bales and elevatorschange saver sub on the top drive,bring handling tools to the floor, clean floor, PJSM, nippling down to set slips, set slips w/ 210k on wt indicator (Blocks 72k), cut casing, dress same, install packoff, torque lower lockdown screws to 550 ft Ibs of torque. Note: Fuid lost Midni ht to Midni ht= None. 00:00 01:30 1.50 9,923 9,923 INTRM1 CSGDRI CIRC P Continue to circulate bottom's up. Reciprocate from 9923' to 9900'. Pumping 100 gpm w/ 560 psi-20% flow out. Rotate 80 rpm w/ 9-10k ft Ibs of torque. Circulated a total of 324 bbls. PU wt 180k, SO wt 121 k, Rot wt 145k w/ 9-10k ft Ibs of for ue. 01:30 02:15 0.75 9,923 9,895 INTRM1 CSGDRI TRIP P Lay down a joint of 5-1/2" 15.5 ppf L-80 casing Qt # 239). Monitor well- sli ht flow- trendin down. 02:15 03:15 1.00 9,895 9,895 INTRM1 CSGDRI CIRC P Circulate. Reciprocate from 9895' to 9855'. Pumping 100 gpm w/ 520 psi-21 % flow out. Circulated a total of 112 bbls. PU wt 180k, SO wt 120k, MW9.7 w/ 10 b LCM. 03:15 04:00 0.75 9,895 9,921 INTRM1 CSGDRI TRIP P Pulll out of the hole jts # 238 and # 237, lay down both. PU a 4.82' pup jt, a 19.82' pup jt, then a joint 42.63' and final joint 39.22'. Note: the last joint 39.22' will be the landing joint and the 42.63' joint will be the cut off joint, when set on sli s. 04:00 06:00 2.00 9,921 9,921 INTRM1 CSGDRI CIRC P Circulate and reciprocate from 9921' to 9880'. Pumping 100 gpm w/ 520 psi-21 % flow out. PU wt 180k, SO wt 120k. 06:00 07:00 1.00 9,921 9,921 INTRM1 CEMEN- RURD P Rig up casing equipment. Cement head and hoses. 07:00 07:45 0.75 9,921 9,921 INTRM1 CEMEN" CIRC P Circulate and reciprocate. Pumping 100 gpm w/ 510 psi-22% flow out. PU wt 181 k, SO wt 120k. 07:45 08:15 0.50 9,921 9,921 INTRM1 CEMEN" LOT P Perform LOT w/ 9.7 ppg MW. Shoe of 7-5/8" Cc~ 3032' MD (2302' TVD). 11.9 w/ 260 si. 08:15 09:00 0.75 9,921 9,921 INTRM1 CEMEN" SFTY P Pre job safety meeting on cementing the 5-1/2" 15.5 ppf L-80 Hyd 563 casing. Still circulating and reciprocating, pumping 100 gpm w/ 510 gpm-22% flow out. PU wt 181 k, SO wt 120k. Mud properties prior to cementing: MW in 9.7 ppg, MW out 9.8 ppg, Vis in 58, vis out 66, PV/YP: 17/15, 10 min els 7. ~~ ~~ ~~ge 39 rsf ~t8 r~ Time Lops __ _ ~ Date _ From 09 0 _ To Dur _ S D~th E D~th Phase Code Subcode T Comment : 0 09:30 0.50 9,921 9,921 INTRM1 CEMEN" CMNT P __ Turn over to Schlumber er/Dowelf 9 cementers. Dowell pump 5 bbls water, test lines to 3500 psi-good, Mix and pump 42.9 bbls of 12 ppg mud push @ 4 bpm w! 398 to 705 09:30 10:00 0.50 9,921 9,921 INTRM1 CEMEN" OTHR T si. Dro bottom lu . Tesco casing running tool would not bite on the pipe (Dies not cleaned), clean dies, grease unit, adjust 10:00 10:45 0.75 9,921 9,921 INTRM1 CEMEN" PUCM P ressure- trouble shoot. Mix and Dump 128.5 bbls (617 sx) 15.8 ppq class G cement w/ Gasblok 17 of c .2 1 gal/sx mix water). Pump @ 4 bpm /yr 490 nsi to final of 9nf1 ~~i. Drop to lu . 10:45 11:45 1.00 9,921 9,921 INTRM 1 CEMEN ' DISP P Rig displace cement w/ 9.7 ppg mud. Pumping 4 bpm. Caught plug after pumping 20 bbls, w/mud push at the shoe the presure was 300 psi, with cement at the shoe the pressure was 750 psi, with 11.5 bbls left to pump- slow to 2 bpm. Prior to slowing down the pumps pressure was 2020 psi-20% flow out. Slow to 2 bpm w/ initial pressure of 1190 psi and final of 1250 psi. Bump the plug w/ 1800 psi @ 1145 hrs 3/9/2009. Bumped at 2346 strokes. Hold f/ 5 minutes- bleed off- floats held. Note: Reciprocated pipe 40' from 9921' to 9881' (PU wt 185-198k, SO wt 122-120k). Once water reached the shoe, start rotating w/ 30 rpm (initial. torque of 11 k ft Ibs torque), once 10 bbls of cement rounded the shoe, start reciprocating and rotating (Initial PU while rotating 165k, SO w/ rotating 142k, Rotating w/ no movement 148k). Continue to reciprocate and rotate until bumping plug. Final slack off rotating weight 125k w/ 7k ft Ibs of torque. Final pick up roating weight 125kw/ 7k ft Ibs of for ue 11:45 12:00 0.25 9,921 9,921 I NTRM1 CEMEN' OWFF P . Monitor annulus- static. PU to 172k on casin strin 12:00 12:45 0.75 9,921 9,921 I NTRM1 CEMEN" WOC P . While waiting on cement for 6 hrs: Rig down the TESCO casing running tool. 12:45 13:00 0.25 9,921 9,921 I NTRM1 CEMEN' WOC P While waiting on cement for 6 hrs: Pre job safety meeting on changing t he saver sub on the top drive to XT 39. 13:00 14:30 1.50 9,921 9,921 I NTRM1 CEMEN" WOC P While waiting on cement for 6 hrs: Change out the saver sub on the top drive from 4-1/2" IF to XT 39. ~e"i L]9 3~ cst' ~3 n ;~ Time Logs Dat From To Dur S_ pe th E. De th Phase Code -_ Subcode _ - T ---- Comment - -- 14:30 15:45 1.25 9,921 9,921 INTRM1 CEMEN" WOC P -- - - While waiting on cement for 6 hrs: Bring handling tools to the floor. Rig up bales, elevators. Pickup the 5-1/2" casing to 210k on the weight indicator Blocks 72k . 15:45 16:00 0.25 9,921 9,921 INTRM1 CEMEN" WOC P While waiting on cement for 6 hrs: Pre job safety meeting on laying down the TESCO casing running tool. 16:00 16:15 0.25 9,921 9,921 INTRM1 CEMEN" WOC P While waiting on cement for 6 hrs: Lay down the TESCO casing running tool. 16:15 16:30 0.25 9,921 9,921 INTRMI CEMEN' WOC P While waiting on cement for 6 hrs: Pre job safety meeting on laying down the Frank's flush mounted sli s. 16:30 17:15 0.75 9,921 9,921 INTRM1 CEMEN" WOC P While waiting on cement for 6 hrs: Disconnect lines, lay down the Frank's flush mounted slips, and control anel. Install master bushin . 17:15 17:45 0.50 9,921 9,921 INTRM1 CEMEN" WOC P While waiting on cement for 6 hrs: Clean and clear ri floor. 17:45 18:00 0.25 9,921 9,921 INTRM1 CEMEN" SFTY P Pre job safety meeting on nippling down to set sli sand ackoff. 18:00 19:15 1.25 9,921 9,921 INTRM1 CEMEN' NUND P Break bolts on tubing spool to casing spool, nipple down flow line, work turnbuckes. Pickup 13-5/8" BOP stack and FMC tubin s ool. 19:15 20:15 1.00 9,921 9,921 INTRM1 CEMEN" OTHR P Install FMC emergency slips (planned). Weight of string on weight indicator was 210k (Blocks 72k . 20:15 22:45 2.50 9,921 0 INTRM1 CEMEN" OTHR P Rig up Wach's cutter to cut 5-1/2" casing. Cut off 5-1/2" and dress same. 22:45 00:00 1.25 0 INTRM1 CEMEN" OTHR P Dress cut, install packoff. Torque lower lockdown screws to 550 ft Ibs of for ue. 3/10/2009 Set Stack Down /Replace API Ring, Tighten Flange. R/U & Test Pack -Off 4,000 PSI (10 Min Test) With FMC Rep. Flood Lines W/9.7 ppg Mud Pressure test Lines to 3,000 PSI (High) Perform Infectivity Test On Outer Annulus. Rig Up To Flush 7-5/8" X 5-1/2" Annulus. Flush Annulus with 55 bbls H2O. pump @ 1bpm w/ 890. psi ICP and 600 FCP. 500 SICP on Outer Annulus. Freeze Protect w/ 25 bbls diesel with "Little red" SYM OPS PJSM /Change Lower and upper rams T/2-7/8" X 5" Variables. Nipple Up flowline, Bell Nipple, Turnbuckles & Center Stack. Rig Up To test BOPE. Test BOPE Witness waived by lou Grimaldi. Test 250 low / 3,500 High. Test # 1-Upper rams (2-7/8" X 5") w/3.5 test joint, 3" Demco, 4" Dart, Choke Manifold vaves # 16,17,18. Test # 2 - Hydril Bag w/3.5 test joint, HCR kill, 4" TIW, Choke Manifold valves 12,13,14,15 &9. Test # 3 lower pipe rams (2-7/8" X 5") w/ 3.5 test joint. Upper IBOP. Test # 4 - Bag w/4" test joint Manual Kill, Choke Manifold Valve # 5,6,10,11, Lower IBOP. Test # 5 Upper rams (2-7/8" X 5") w/4" test joint, 3.5" dart. Test # 6- 3.5 TIW, Choke Manifold Valves # 1,4,7. Test # 7- 2-7/8 Dart (#1) Choke Manifold valves # 2,3,8. Test # 8 -Lower rams w/ 4" test joint. 2-7/8 TIW (#1). Test # 9 -bag w/ 2-718" test joint HCR Choke, 2-7/8" Dart (#2) Perform Drawdown 3,075 psi start, 1,500 psi drawdown 58 seconds = 200 psi increase, 3 minutes 37 seconds =full charge, 2,250 psi 5 bottle average. Test # 10 Upper pipe rams w/ 2-7/8" test joint, Manual choke, 2-7/8" TIW (#2). Test # 11 Lower pipe rams w/ 2-7/8" test joint. test # 12 Blind rams. Breakdown 2-7/8" Test joint. Pull test plug. Set Wear bushing 10.8" OD 7-3/8" ID length 1.0' Rig down test equipment. Blow down. Pick up tools for. BHA, Rig up double stack hyd. tongs. prep rig floor for BHA. Pre job safety meeting on picking up Superslim BHA with Co. rep, Tool usher,S er directional drill ~~ ~~ I e ~~ ~a~ ~3 cf ~3 n ~~ Time Logs _ _ __ __ Date From To Dur S De th E. De th Phase Code Subcode T Comment '~ 00:00 01:00 1.00 9,921 9,921 INTRM1 DRILL NUND P Set Stack Down /Replace API Ring, Ti hten Flan e 01:00 02:30 1.50 9,921 9,921 INTRM1 DRILL DHEO P R/U & Test Pack -Off 4,000 PSI (10 Min Test With FMC Re 02:30 03:00 .0.50 9,921 9,921 INTRM1 DRILL PRTS P Flood Lines W/9.7 ppg Mud Pressure test Lines to 3,000 PSI Hi h 03:00 06:00 3.00 9,921 9,921 INTRM1 DRILL LOT P Perform Infectivity Test On Outer Annulus 06:00 07:00 1.00 9,921 9,921 INTRM1 DRILL OTHR P Rig Up To Flush 7-5/8" X 5-1/2" Annulus 07:00 10:00 3.00 9,921 9,921 INTRM1 DRILL CIRC P Flush Annulus with 55 bbls H2O. pump @ 1 bpm w/ 890 psi ICP and 600 FCP. 500 SICP on Outer Annulus. Freeze Protect w/ 25 bbls diesel with "Little red" SYM OPS PJSM /Change Lower and upper rams T/2-7/8" X 5" Variables 10:00 10:45 0.75 9,921 9,921 INTRM1 DRILL NUND P Nipple Up flowline, Bell Nipple, Turnbuckles & Center Stack 10:45 12:00 1.25 9,921 9,921 INTRM1 DRILL BOPE P Rig Up To test BOPE 12:00 18:30 6.50 9,921 9,921 INTRM1 DRILL BOPE P Test BOPE Witness waived by lou Grimaldi. Test 2501ow / 3,500 High. Test # 1-Upper rams (2-7/8" X 5") w/3.5 test joint, 3" Demco, 4" Dart, Choke Manifold vaves # 16,17,18. Test # 2 - Hydril Bag w/3.5 test joint, HCR kill, 4" TIW, Choke Manifold valves 12,13,14,15 &9. Test # 3 lower pipe rams (2-7/8" X 5") w/ 3.5 test joint. Upper IBOP. TPCt # a -Bag w/4" test joint Manual Kill, Choke Manifold Valve # 5,6,10,11, Lower IBOP. Test # 5 Upper rams (2-7/8" X 5") w/4" test joint, 3.5" dart. Test # 6- 3.5 TIW, Choke Manifold Valves # 1,4,7. Test # 7- 2-7/8 Dart (#1) Choke Manifold valves # 2,3,8. Test # 8 -Lower rams w/ 4" test joint. 2-7l8 TIW (#1). Test # 9 -bag w/ 2-7/8" test joint HCR Choke, 2-7/8" Dart (#2) Perform Drawdown 3,075 psi start, 1,500 psi drawdown 58 seconds = 200 psi increase, 3 minutes 37 seconds = full charge, 2,250 psi 5 bottle average. Test # 10 Upper pipe rams w/ 2-7/8" test joint, Manual choke, 2-7/8" TIW (#2). Test # 11 Lower pipe rams w/ 2-7/8" test joint. test # 12 Blind rams. 18:30 20:00 1.50 9,921 9,921 INTRM1 DRILL BOPE P Breakdown 2-7/8" Test joint. Pull test plug. Set Wear bushing 10.8" OD 7-3/8" ID length 1.0' Rig down test e ui ment. Blow down. ~~~ _ Pa~~; 3~ a~f 4~ i C~ Tirne Logs _ __ _ _ !Date From To Dur S De th E. De th Phase Code Subcode T Comment 20:00 21:15 1.25 9,921 _ 9,921 INTRM1 DRILL PULD P Pick up tools for BHA, Rig up double stack hyd. tongs. prep rig floor for BHA. 21:15 21:45 0.50 9,921 9,921 INTRM1 DRILL SFTY P Pre job safety meeting on picking up Superslim BHA with Co. rep, Toolpusher,Sperry directional driller and GBR ton hand 21:45 00:00 2.25 9,921 9,921 INTRM1 DRILL PULD P Pick Up BHA /Bit, Motor, Float Sub, Stabilizer, 2 Joints flex drill collars,and 6 s iral drill collars. 3/11 /2009 Completed picking up BHA, Tripped in picking up 2-7/8" HT PAC drillpipe to 9.840' MD. (Torque and drag data obtained every 20 joints) Circulated bottoms up, Tested casing to 3,000 psi F/30 min. Drilled out cement, Float Collar, Shoe/ bit, rathole and 20' of new hole. 00:00 02:30 2.50 9,921 9,921 INTRM1 DRILL PULD P Continue picking up BHA # 7 - 23 Spiral HWDP, 3-1/8" Jars w/ bumper sub, 15-S iral HWDP 02:30 03:00 0.50 9,921 9,921 INTRM1 DRILL PULD P PJSM Discuss procedure for using 4"joint as kelly. Change over to 4" elevators, make up joint 4"drillpipe for use as Kelly. Add crossover from XT-39 to 2-7/8" HT-PAC 03:00 03:30 0.50 9,921 9,921 INTRMI DRILL CIRC P Fill Pipe @ 1,500' MD. 120 gpm, 600 psi, 18% flow out. Obtain torque and drag data - Up wt = 92K/ Down wt = 96K /Rot wt = 98 K (Pumps off) 50 r m = 1 K Tor ue. 03:30 03:45 0.25 9,921 9,921 INTRM1 DRILL OTHR P Lay down Kelly joint w/crossover. Chan a elevators. 03:45 04:45 1.00 9,921 9,921 INTRM1 DRILL TRIP P PJSM on picking up drillpipe. Trip in hole picking up 2-7/8" HT-PAC Drillpipe From 1,500' To 2,101' MD 20 Joints 04:45 05:15 0.50 9,921 9,921 INTRM1 DRILL CIRC P Pick up kelly joint/ Fill pipe @ 2,101' MD. 120 gpm, 720 psi, 18% flow out. Obtain torque and drag data - Up wt = 95K/ Down wt = 100K /Rot wt = 100 K (Pumps off) 50 rpm = 1-2K Torque. Lay down 4" Kelly w/ crossover. Chan a Elevators. 05:15 06:00 0.75 9,921 9,921 INTRM1 DRILL TRIP P Pick up 2-7/8"drillpipe tripping in from 2,101' to 2,735' MD 20 ~oints 06:00 06:45 0.75 9,921 9,921 INTRM1 DRILL CIRC P Pick up kelly joint/ Fill pipe @ 2,735' MD. 120 gpm, 890 psi, 18% flow out. Obtain torque and drag data - Up wt = 100K/ Down wt = 105K /Rot wt = 105 K (Pumps off) 50 rpm = 2K Torque. Lay down 4" Kelly w/ crossover. Change Elevators. Blow Down to drive Path ~~ #~f ~~ Date From To Dur S Depth E Depth Phase C:n~ie Suhcnde T Comment 06:45 12:00 5.25 9,921 9,921 INTRM1 DRILL TRIP P Continue tripping in hole picking up 2-7/8" HT-PAC drillpipe F/2,735' - T/ 6,530' Filling pipe and obtaining torque and drag data every 20 joints. Pumps Off data = 3,367' MD Up wt 101 K /Down wt 99K /Rot wt @ 60 rpm = 101 K Torque 2K 4,000' MD Up wt 106 K /Down Wt 99 K /Rot wt @ 60 rpm Torque 2K // 4,633' Up wt 109K Down wt 101 K Rot wt @ 60 rpm 106 K Torque 2.5K// 5,266' MD Up wt 113 K Down wt 101 K Rot wt @ 60 rpm 108K Torque 2-3K // 5,898' MD Up wt 115K Down wt 101 K Rot wt @ 60 rpm 110K Torque 2-3K // 6,530' MD Up wt 120 K Down wt 108K Rot wt @ 60 rpm 3K Hole took ro er dis lacement. 12:00 14:45 2.75 9,921 9,921 INTRM1 DRILL TRIP P Continue tripping in hole picking up 2-7/8" HT-PAC drillpipe F/6,530' - T/ 9,840' MD Torque and drag data with pumps off (All rotating weights @ 60 rpm) - 7,162' MD Up wt 128K Down Wt 108 K Rot wt.115K Torque 2-3K // 7,795'MD Up wt 131 K Down wt 109K Rot wt 120K Torque 2-3K // 8,428' MD Up wt 135K down wt 109K Rot wt 121 K Torque 3K // 9,061' MD Up wt 140 K Down wt 109K Rot wt 122 K Torque 3-4K !/ 9,694' MD Up wt 147K Down wt 112K Rot wt 127K Torque 3-4K. Hole took ro er dis lacement. 14:45 15:00 0.25 9,921 9,921 INTRM1 CEMEN- 000F P Tagged float collar on depth at 9,840' MD. set down with 5K to verify tag up. Pull up to 9,821' MD lay down 'pint. 15:00 16:00 1.00 9,921 9,921 INTRM1 DRILL CIRC P Circulate and condition for casing test. reciprocating pipe from 9,821' - to 9,790' MD Pump rate 150 gpm, 3,100 psi, 19% flow out, 60 rpm Tor ue = 3-4K 16:00 17:45 1.75 9,921 9,921 INTRMI DRILL PRTS P Rig up and test 5-1/2" L-80 15.5 ppf Hvdril casino to 3.000 psi for 30 Minutes. Good test. Rig down testing equipment. (Moved 4" drillpipe in derrick to support 2-7/8"drillpipe in derrick when racked back 17:45 18:30 0.75 9,921 9,921 INTRM1 DRILL OTHR P Change elevators to 4" Prep rig floor for drilling out cement.Pick up 4" kell 'pint with crossover 18:30 21:30 3.00 9,921 9,921 INTRM1 CEMEN" DRLG P Drill Float Collar and cement from 9,840' to 9,920' MD. Parameters = 100 gpm / 1,620 psi / 60 rpm/ Torque 3K/Up wt140KDownwt115KRot wt 128K 17% flow out ~~g~ 35 ssf ~1~ I • ~~ Time Logs - - - -- ~~~ Date From To D ur S. De th E. Depth Phase Code Subcode T Comment 21:30 22:15 _ _ 0.75 9,921 9,923 INTRM1 CEMEN" DRLG P Drill Shoe/bit and rathole from 9,920' to 9,923' Parameters 100 gpm 1,700 psi /flow out 18% / 60 rpm / torque 3-4 K. 4K - 7 K bit weight. Up wt 140K down wt 115 K Rot wt 128K 22:15 00:00 1.75 9,923 9,943 INTRM1 DRILL DDRL P Drill 20' new hole from 9,923' to 9,943' MD 5,223 ND (Projected) Bit weight 6K-10K Rpm =60 Torque on = 4K Torque off = 3K-4K GPM = 120 with 2,490 psi on 2,250 psi off. Flow out 18% Up wt 148K Down wt 115K Rot wt 128K. Bit hrs =1.5 ART = 1.5 ADT = 1.5 jar hrs = 1.5. Max gas observed = 10 units E och 3/12/2009 Circulate for LOT. Rig up and perform LOT. Results of LOT = 17.5 ppg EMW. Trip out for PDC bit and MWD tools. Pick u same and tri back in hole. Service ri .Ream from 9,818' MD to 9,913 MD 00:00 01:00 1.00 9,943 9,943 INTRM1 DRILL CIRC P Circulate Bottoms Up @ 9,943' Parameters - 150 gpm , 2,990 psi, 17% flow out, 60 rpm 3K-4K torque, Up wt 140 K, Down wt 115 K, Rot wt 128K, Total Strokes = 2,460. Trip out from 9,943' - to 9,916' SPR's taken @ 9,943' MD 5,223' TVD. # 1 mudpump 20 spm = 1,000 psi. 30 spm = 1,720 psi # 2 mudpump 20 spm = 1,000 psi. 30 s m = 1,730 si. 01:00 01:15 0.25 9,943 9,943 INTRM1 DRILL OTHR P Lay down 4" Kelly joint with crossover. Blow down topdrive and mud lines. 01:15 01:30 0.25 9,943 9,943 INTRM1 DRILL LOT P Rig Up For FIT/ LOT 01:30 02:15 0.75 9,943 9,943 INTRM1 DRILL LOT P Perform LOT ~ 9,916' MD 5,213' TVD with 8.7 mud. PSI = 2,210 ; EMW = 17.5 02:15 02:30 0.25 9,943 9,943 PROD1 DRILL OWFF P Blow down Kill line, Monitor well (Static) 02:30 02:45 0.25 9,943 9,943 PROD1 DRILL CIRC P Pump 10 bbl dry job. Use 12.0 ppg mud pumped at 30 spm, 102 gpm, 1630 si 17% flowout. 02:45 03:00 0.25 9,943 9,943 PROD1 DRILL TRIP P Change elevators, Install stripping rubber and airsli s for tri out of hole. 03:00 03:15 0.25 9,943 9,943 PROD1 DRILL TRIP P PJSM for tripping out of hole with 2-7/8" drill i e usin bell ro e. 03:15 06:00 2.75 9,943 9,943 PROD1 DRILL TRIP P Trip out of hole from 9,916' MD to 3,503' MD recorded up and down weights every 10 stands.Torque and Drag readings = 9,916' MD - 148 K Up wt 112 K down wt. / 9,061' MD 154K up wt 108 K down wt / 8,112' MD 138 K up wt. 105 K down wt. ! 7,163' MD 130 K up wt 102 K down wt./6,214'MD125Kup wt. 100K down wt. / 5,266' MD 120 K up wt. 100 K down wt. 4,317' MD 110 K u wt. 98 K down wt. __. ~ ~ Y<~~ ~ ~? rst ~8 C, :~ .Time Logs _ Date __ From To Dur S. Depth _E De th Phase Code Subcode T_ Comment 06:00 07:15 1.25 9,943 9,943 PROD1 DRILL TRIP P Continue trip out of hole from 3,503' MD to 1,468 MD Hole took proper displacement. Torque and drag = 3,368' MD 100 K up wt. 98 K down wt. / 2,418' up wt. 98 K down wt. 98 K 07:15 10:15 3.00 9,943 9,943 PROD1 DRILL PULD P Lay Down BHA # 7. Per Sperry DD. Drain Motor and break bit. Bit inspected and graded = 8-7-WT-A-E-2-CR-TD 10:15 10:45 0.50 9,943 9,943 PROD1 DRILL OTHR P Clean And Clear Rig Floor. Rig Up To Pick U BHA 10:45 15:00 4.25 9,943 9,943 PROD1 DRILL PULD P Pick Up BHA # 8. Make up PDC bit to Motor. Pick up MWD Directional, Res, Slimhole Hang off collar, Flow tube and bottle neck crossover. Pick up flex drillcollars, crossovers and circulating sub, Spiral drill collars. Shallow pulse test @ 696' MD 120 gpm, 1,200 psi. 15% flow out. Staged flow up to 135 gpm with 1,440 psi, 16% Flow out. (Good pulse test) Blow down top drive and mud lines. Pick up remaining BHA spiral HWDP Crossovers and jars. Total BHA len th = 1528.90' 15:00 18:00 3.00. 9,943 9,943 PROD1 DRILL TRIP P Trip In Hole with 2-7/8"drillpipe from 1,528' MD - to 5,611' MD Hole took proper displacement. Pipe filled every 25 stands. 18:00 18:45 0.75 9,943 9,943 PROD1 DRILL TRIP P Continue trip in hole from 5,611' MD to 6,275' MD fill every 25 stands. filled at 6,275' MD, 120 gpm 2,320 psi, 17% Flow out, Up wt 120 K Down wt 105 K 18:45 19:15 0.50 9,943 9,943 PROD1 DRILL SVRG P Rig Service, Lubricate upper and lower IBOP's on to drive. 19:15 22:00 2.75 9,943 9,943 PROD1 DRILL TRIP P Continue trip in hole from 6,275' MD to 9,818' MD fill every 25 stands. filled at 8,647' MD, 120 gpm 2,670 psi, 18 % Flow out, Up wt 135 K Down wt 110 K Rot wt 125 K Torque 4,000 ft/Ibs. 22:00 22:30 0.50 9,943 9,943 PROD1 DRILL TRIP P Latch stand 2-7/8"drillpipe from derrick. Run single in hole lay down remaining 2 joints from stand. Latch stand of 2-7/8" drillpipe from derrick and lay down. (Joints to be used to ream to bottom due to previous bit bein under au e 22:30 00:00 1.50 9,943 9,943 PROD1 DRILL REAM P Precautionary reaming to bottom from 9,818' MD to 9,913' MD. with 120 gpm, 3020 psi, 60 rpm, torque = 4,000 ft/Ibs. Flow out 17%, Up wt 145 K Down wt 110 K Rot wt 125 K (Pum s On) Faye ~H cif 4~ • ~ J Time Logs _ ~ _ _ _ _ Date From To Dur _ S G~i E Depth Phase_ _Co_d_e Subcode T _ Comment __ 3/13/2009 2a hr Summary PJSM -Drilling reservoir, Well Control and displacing mud. Displaced from 9.7 ppg to 12.0 ppg mud. Drilled from 9,943' to 10,259' Base of Bermuda at 10,138' MD 5,368' TVD 00:00 00:30 0.50 9,943 9,943 PROD1 DRILL REAM P Precautionary Reaming from 9,913' MD to 9,940' MD @ 120 gpm, 3,020 psi, 60 rpm, 4,000 ft/Ibs. torque, Flow out 17%. Up wt 145 K, Down wt 115 K, rot wt 128 K, (Pumps On) (Note :Surveys taken at 9,841' MD Inclination 45.36? Survey at 9,904' Inclination 44.66? Show 1.11? per 100' drop rate occurred while casing drillin . 00:30 01:00 0.50 9,943 9,943 PROD1 DRILL TRIP P Trip Out and lay down 1 joint. From 9,940' MD to 9,913' MD. Blow down top drive. Pick up Kelly joint and monitor well. Well Static (Note: Toolpusher moved flow paddle on flowline indicating a flow increase. Driller immediately called for BOP drill. All hands responded efficiently and went to correct blowout stations. Drill done when pulling up to break off kell ~oint 01:00 02:00 1.00 9,943 9,943 PROD1 DRILL SFTY P Monitor well (Static) Hold Pre reservoir drilling safety meeting, Discussion on well control swab and surge, Mud properties etc. Reviewed BOP drill. Held PJSM on fluid displacement. (Good Discussion Good Partici ation 02:00 04:30 2.50 9,943 9,943 PROD1 DRILL CIRC P Trip in hole from 9,913' MD to 9,940' MD. Pump 20 bbl tube sweep chase with 60 bbl 9.7 ppg mud. Begin displacing 9.7 ppg mud with 12.0 ppg mud at 120 gpm ICP 3,020 psi, flow out 16% Up wt 145 K, Down wt 115 K, Rot wt 130 K, 60 rpm torque = 4,000 ft/Ibs. Lube pill at surface 2,250 strokes. 9.7 ppg mud at surface 2,540 strokes. 12.0 ppg mud at surface 3,750 strokes. 120 gpm FCP = 3,750 psi, 15% flow out 60 rpm. Torque 2K-3K ft/Ibs. Up wt 140 K Down wt 118 K, Rot wt 128K Circulated total of 4,020 strokes. 04:30 05:00 0.50 9,943 9,943 PROD1 DRILL OWFF P Monitor well (Static) Mud pits brought on 12.0 ppg mud from vac truck. Cleaned all shaker screens. Rig floor prepped to drill ahead. SPR's taken 9,943' MD 5,215' TVD # 1 Mudpump 20 spm = 1,820 psi 30 spm = 3,230 psi # 2 mudpump 20 spm = 1,730 psi 30 s m = 3,310 si I __ ?~na 39 €~~ ~~ l I ' Time Logs __ Date From To Dur S. fle th E. De th Phase Code Subcod e T Comment 05:00 06:00 __ 1.00 9,943 9,967 PROD1 DRILL _ DDRL P Drill from 9,943' MD to 9,967' MD (5,245' ND) Bit wt 4K, rpm = 60, torque on 3K, ft/Ibs.Torque off 2K-3K ft/Ibs. 120 gpm 4,020 psi on, 3,890 psi off, flow out 15%, Up wt 140 K, Down wt 118K, Rot wt 128K, Total bit hrs.=.68 Jar hrs. = 2.18, hrs. ART _ .68 hrs. ADT.68 hrs. Max Gas Observed = 2 units (Epoch) 24' Drilled Avera a ROP = 35 FPH 06:00 12:00 6.00 9,967 10,102 PROD1 DRILL DDRL P Drill from 9,967' MD 5,245' ND to 10,102' MD 5,342' ND. 120 gpm, 3,980 psi on, 3,810 psi off. Flow out = 17% Bit wt 4K, rpm = 60, torque on = 3K-4K ft/Ibs. Torque off = 3K ft/Ibs. Up wt 141 K, Down wt 118 K, Rot wt 128K, Total bit hrs = 4.13 ART = 3.45 ADT = 3.45 AST = 0.0 Jar hrs. = 6.31 Max Gas Units = 182 (Epoch) 135' Drilled Average ROP = 36 FPH 12:00 18:60 6.00 10,102 10,215 PROD1 DRILL DDRL P Drill from 10,102' MD 5,342' ND to 10,215' MD 5,423' ND. 120 gpm, 4,010 psi on, 3,890 psi off. Flow out = 17% Bit wt 4K, RPM = 60, Torque on = 4K ft/Ibs. Torque off = 4K ft/Ibs. Up wt 140 K, Down wt 112 K, Rot wt 123 K, Total bit hrs = 7.85 ART = 3.04 ADT = 3.04 AST = 0.0 Jar hrs. = 9.35 Max Gas Units = 1,446 (Epoch) Gas Circulated Out @ 10,132' Before drilling continued. (Base of Bermuda 10,138' MD 5,368' ND.) 113' Drilled Average ROP = 37 FPH SPR's @ 10,135' MD 5,365' ND Mud wt. 12.0 ppg Taken with # 2 Mudpump 10 spm = 900 psi 20 spm = 1,850 psi 30 spm = 3,450 si 18:00 00:00 6.00 10,215 10,259 PROD1 DRILL DDRL P Drill from 10,215' MD 5,423' ND to 10,259' MD 5,455' ND. 120 GPM 4,480 psi on 4,380 psi off, Flow out = 17% Bit wt 10 K RPM = 60, Torque on 4K fUlbs. Torque off 3K-4K ft/Ibs. Up wt 145 K, Down wt 118 K, Rot wt 125 K, (Pumps On) Total bit hrs = 12.03 ART = 4.18 AST = 0.0 ADT = 4.18 Jar hrs = 13.53 Max Gas Observed 1,444 (Epoch) 44' Drilled Avera a ROP = 10.5 FPH 3/14/2009 Drilled from 10.259 MD to TD Ccil 10.335' MD. Circulated and conditioned mud. Monitored well. Backreamed from 10,335' to 5-1/2" casin shoe. Circulate at shoe. Pulled 10 stands on elevators. Serviced rig. Tripped back to bottom. Circulated increase in as units. Be an wei htin u from 12.2 12. -__________. ~ e ~ mi~~ar~e 4~1 of ~t3 i • Time Logs __ -- _. Date From_ To Dur S Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 10,259 10,265 PROD1 DRILL DDRL P _ __ _ Drill from 10,259' MD 5,455' ND to 10,265' MD 5,459' ND, 120 gpm 4,480 psi on, 4,380 psi off Flow out 17% 60 RPM, Torque on = 4,000 ft/Ibs Torque off = 3K-4K ft/Ibs. Bit wt _ 10K, Total bit hrs. 12.36 ART .33, AST 0.0 ADT .33 Jar hrs. 13.86. Up wt 145 K, Down wt 118 K, Rot wt 125K. Max Gas Observed 25 Units (Epoch) 6' Drilled Average ROP 18 FPH. 01:00 02:30 1.50 10,265 10,265 PROD1 DRILL RGRP T Lay down kelly joint, Blow down topdrive, Pick Up kelly joint and reciprocate drill string. Change out . liner gasket on mudpump: Monitor well for flow. Well Static. 02:30 06:00 3.50 10,265 10,304 PROD1 DRILL DDRL P Drill from 10,265' MD 5,459' ND to 10,304' MD 5,487' ND, 110 gpm 3,940 psi on, 3,800 psi off Flow out 16% 60 RPM Torque on = 4,000 ft/Ibs. Torque off = 3K -4K ft/Ibs. Bit wt = 10K, Total bit hrs. 14.23, ART 1.87 AST 0.0 ADT 1.87 Jar hrs. 15.73. Up wt 148 K, Down wt 115 K, Rot wt 128 K. Max Gas Observed 1,957 Units (Epoch) 39' Drilled Average ROP = 21 FPH. Mud weight increased from 12.0 ppg to 12.2 ppg. While drilling ahead. SPR's at 10,304' MD 5,487' ND 12.2 ppg mud weight. Mudpump # 1 10 spm = 990 psi, 20 spm = 2,110 psi 30 spm = 3,510 psi Mudpump # 2 10 spm = 1,020 psi, 20 spm = 2,040 psi, 30 s m = 3,690 si. 06:00 11:00 5.00 10,304 10,335 PROD1 DRILL DDRL P Drill from 10 3[14' MIS 5 4RT Nr1 to 10,335 MD 5,509' ND. 105 gpm, ~ 3,810 psi on 3,750 psi off Flow out 17% 60 RPM, Torque on 4,000 ft/Ibs. Torque off 3K-4K fUlbs. Bit wt = 10 K, Total bit hrs. 17.86, ART = 3.63 AST = 0.0 ADT = 3.63 Jar hrs. 17.86 Max Gas Observed 145 Units (Epoch) 10,335' TD for well. 31' Drilled Avera a ROP = 8.5 FPH. 11:00 12:45 1.75 10,335 10,335 PROD1 DRILL CIRC P Circulate And Condition Mud at 10,335' MD (TD) Pump at 105 gpm, 3,750 psi, Flow out 17% RPM = 60 Torque 3K - 4K ft/lbs. Max Gas Observed 56 Units E och 12:45 13:00 0.25 10,335 10,335 PROD1 DRILL OWFF P Blow Down Top Drive, Monitor Well Well Static 13:00 16:00 3.00 10,335 9,913 PROD1 DRILL REAM P Backream Out Of Hole from 10,335' MD to 9,913' MD. (5-1/2" Casing Shoe 9,920') Pump at 25 spm, 60 rpm, Torque 3K-4K. Pulling speed 30 ft/min. No hole problems encountered. _-__.___ ~ _ ~~~~ 4't of ~II ''r~ l J Time Logs Date From To _ Dur_ S. Depth E. De t h Phase Code Subcode T C_omm_e_nt___ __ 16:00 _ 17:00 1.00 9,913 _ _ 9,913 PROD1 DRILL CIRC P Circulate Bottoms Up at 110 gpm 4-,000 psi, 19% Flow out, 60 RPM, Torque 3K - 4K, Total Strokes Circulated 1,904. Max Gas Observed 71 Units E och 17:00 18:00 1.00 9,913 8,964 PROD1 DRILL TRIP P Trip Out from 9,913' MD to 8,964' MD. Hole took ro er dis lacement. 18:00 19:00 1.00 8,964 8,964 PROD1 DRILL SVRG P Service Rig, Lubricate top drive, traveling blocks, crown and draworks. 19:00 20:15 1.25 8,964 9,913 PROD1 DRILL TRIP P Trip In Hole, w/ 2-7/8"drillpipe out of derrick at 30 FUMin from 8,964' MD to 9,913' MD. Up wt 140 K, Down wt 112K 20:15 21:00 0.75 9,913 10,325 PROD1 DRILL TRIP P Trip Into Open Hole with singles from 9,913' MD to 10,335' MD. Up wt 145 K, Down wt 115 K, No indications of hole roblems on tri . 21:00 21:15 0.25 10,325 10,335 PROD1 DRILL TRIP P Change Out Elevators and Pick Up Kelly Joint. Make Up To Drillstring. Tri In To Bottom 21:15 00:00 2.75 10,335 10,335 PROD1 DRILL CIRC P Circulate at 110 gpm, 3,940 psi, 18% Flow out, 60 RPM, Toque 4K-5K ft/Ibs. Up wt 140 K, Down wt 115 K, Rot wt 125 K. Gas increase while circulating at 1,000 strokes pumped gas units climbed with max gas units 1,422 (Epoch) Decision to weight up mud system to 12.5 ppg. Reduced pump rate to 90 gpm 3,010 psi Flow out 17% 60 RPM, Torque 3K-4K ft/Ibs. Up wt 148 K, Down wt 115 K, Rot wt 130 K, 4,550 strokes pumped 24:00 hrs. 3/15/2009 Complete Weighting up mud. Short trip. Circulate (Check for gas) Trip out laying down 2-7/8"drillpipe. Monitorin well via tri tank. Start la in down BHA 00:00 03:15 3.25 10,335 10,335 PROD1 DRILL CIRC P 10,335' MD - 5,509' TVD Circulate while weighting up mud from 12.2 ppg to 12.5 ppg. 90 gpm, 3,010 psi, Flow out 17%, 60 rpm Torque 4,000 fUlbs. Up wt 148 K, Down wt 115 K, Rot wt128K. Max Gas Units 72 (Epoch) Total Strokes Pumped 9,030. SPR's # 1 Mudpump 10 spm - 1,070 psi 20 spm 2,080 psi # 2 mudpump 10 spm 1,080 psi 20 spm 2,050 si 03:15 05:15 2.00 10,335 10,335 PROD1 DRILL TRIP P Short trip. Lay down keely joint w/crossover. Change Elevators. Trip out on elevators from 10,335' MD to 9,920' MD at 20-30 fpm. (No overpull) Monitor well (Static) Trip back in hole from 9,920' MD to 10,335' MD at 20-30 fpm. (No hole problems encountered) Change Elevastors. Pick u keel ~oint w/ crossover. t~~~~e ~~ ~t ~F l I I Time Logs. --_- _- - Date From To ____Dur S De th E. Depth Phase Code Subcode T Comment 05:15 09:30 4.25 10,335 10,335 PROD1 DRILL CIRC P Circulate and Condition mud. 90 gpm, 3,010 psi, Flow out 17%, 60 rpm, Up wt 148 K, Down wt 115 K, Rot wt 128 K, Max Gas Units 202 (Epoch) gas units at end of circulation 29 E och 09:30 10:00 0.50 10,335 10,335 PROD1 DRILL OWFF P Blow Down Top Drive, Monitor well. Well Static 10:00 11:00 1.00 10,335 9,375 PROD1 DRILL TRIP P Trip out of hole from 10,335' to 9,375' Pulled on elevators with overpull @ 9,440'. Worked through area then worked area twice no overpull observed. Up wt 140K down wt 110 K @ 9,440'. Pulling speed 30 ft/min. Hole took correct displacement. (10 Stands racked in derrick 11:00 12:00 1.00 9,375 9,375 PROD1 DRILL OWFF P Monitored well. (Well Static) Pumped Dry Job. Blow down topdrive and mud lines. 12:00 15:00 3.00 9,375 5,801 PROD1 DRILL TRIP P Trip out of hole from 9,375' MD to 5,801' MD laying down 2-7/8" drillpipe. Hole took correct dis lacement. 15:00 15:30 0.50 5,801 5,801 PROD1 DRILL OWFF P Monitor well (Well Static) 15:30 20:00 4.50 5,801 1,558 PROD1 DRILL TRIP P Trip out of hole from 5,801' MD to 1,558' MD. Laying down 2-7/8" drill i e. Hole took correct fill. 20:00 22:00 2.00 1,558 1,558 PROD1 DRILL. TRIP P Lay down 10 stands 2-7/8" Drillpipe from derrick. Monitored well via trip tank well static 22:00 22:15 0.25 1,558 1,528 PROD1 DRILL TRIP P Trip out of hole from 1,558' MD to 1,528' MD. Lay down last joint of 2-7/8" Drill i e. Chan a elevators. 22:15 00:00 1.75 1,528 837 PROD1 DRILL PULD P 1,528' MD at BHA. Lay down Spiral HWDP, Crossover, Jars w/Bumper sub, Crossover and 11 Joints Spiral HWDP (837' BHA still in hole @ 24:00 hrs. 3!16/2009 Lay Down BHA, Pick Up Liner, Hanger/Packer, Circulate Liner Volume, Trip In with Liner Circulate Bottoms U 3,000' MD.Tri In With Liner to 6,000' MD Circulate, 00:00 01:00 1.00 837 330 PROD1 DRILL PULD P Lay Down BHA 12 Joints Spiral HWDP 01:00 01:30 0.50 330 330 PROD1 DRILL OWFF P Monitor Well, Mid job safety meeting on laying down Drill collars and S er BHA Com onents. 01:30 02:30 1.00 330 113 PROD1 DRILL PULD P Continue Laying Down BHA. (Crossover, 6 X drill collars, Crossover, Circulating Sub, 2 X crossovers and 1 Non Mag Flex Drill Collar) 02:30 03:45 1.25 113 113 PROD1 DRILL PULD P Download MWD ~~ P~r~~ 43 ~t ~~ • • Time Logs - -- Date From_ _ To Dur S Depth - E. De th Phase - Code Subcade T Comment 03:45 05:15 1.50 113 0 PROD1 DRILL PULD P Lay Down Remaining BHA (1 Non Mag Flex Drill Collar, Bottle neck crossover, Flow Tube, Hang Off Collar, EWR, Directional, Stabilizer, Float Sub, Motor and Bit. Bit graded 1-1-NO-A-X-I-NO-TD 05:15 05:30 0.25 0 0 COMPZ CASING OTHR P Clear Rig Floor, Change Elevators, Toolbox Safety Meeting on making u float shoe 05:30 06:00 0.50 0 95 COMPZ CASING PUTB P Pick Up 3-1/2" Casing Shoe. Make up to 3-1/2" Linerjoint. Pick up 1 joint 3-1/2" liner, Float collar with 3-1 /2"joint, Joint with landing collar. All connections bakerlocked. 06:00 07:00 1.00 95 95 COMPZ CASING PUTB P Clean And Clear Rig Floor, Rig Up Fill U Line 07:00 08:30 1.50 95 601 COMPZ CASING PUTB P PJSM, Fill Liner, Check Floats (OK) ;Pick Up 3-1/2" Hydril 511 9.2ppf L-80 Liner Per Runnin detail. 08:30 09:30 1.00 601 645 COMPZ CASING PUTB P Change Elevators, Pick Up Baker flex Lock Liner Hanger, ZXP Liner Top Packer, ZXP Extension and Liner Running Tool w/Crossover Per Baker Rep. Mix and Pour Pal Mix, 1/2 hr set time. Make Up Floor Valve For PH6 Work Strin . 09:30 10:30 1.00 645 740 COMPZ CASING CIRC P Change Out Elevatros, Trip Into 740' MD Circulate 2 liner volumes, Pump at 2 b m, 270 si, 20% Flow Out 10:30 11:15 0.75 740 740 COMPZ CASING OTHR P Rig Down Circulating Lines Bring subs to floor. 11:15 15:30 4.25 740 2,987 COMPZ CASING RUNL P Trip In Hole with Liner. From 740' MD to 2,987' MD Filling on every joint, Topping off every 30 joints. 1,583' MD Up wt 80K, Down wt 90K, 2,520' MD Up wt 90K Down wt 95K, Hole took proper displacement. 40-50 ft/min runnin seed. 15:30 17:15 1.75 2,987 2,987 COMPZ CASING CIRC P 2,987' MD Circulate Bottoms Up w/ 29 gpm, 310 psi,3% Flow out, Max Gas Units 272 E och 17:15 17:30 0.25 2,987 2,987 COMPZ CASING OTHR P Make Up Crossovers, Blow Down To Drive 17:30 21:30 4.00 2,987 6,023 COMPZ CASING RUNL P Trip In Hole with Liner from 2,987' MD to 6,023' MD. Up wt 115K, Down wt 102K. Hole took proper displacement. 20-30 ft/min running s eed. 21:30 23:00 1.50 6,023 6,023 COMPZ CASING CIRC P 6,023' MD Circulate string volume,30 gpm, 610 psi, Flow out 5%, Pumped 578 strokes total. 3,456' MD Up wt 100K, Down wt 98K. 4,391' MD Up wt 100K, Down wt 98K, 5,329' MD U wt 108K Down wt 98K. 23:00 23:30 0.50 6,023 6,023 COMPZ CASING OTHR P Lay down crossovers, Blow down To drive. 23:30 00:00 0.50 6,023 6,023 COMPZ CASING OTHR P Change out fill up line and prime hoses. - - Pau~~ es3 ~»8 i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 3/17/2009 ___ _____________ _ 24 hr Summary Trip in w/Liner to 5-1/2" Csg. shoe, Circulate, Run Liner to Bottom, Circulate and condition mud. (Lost returns) Cement liner, Bump plug, Set hanger and packer. Circulate, Pump dry job. Trip out laying down PH-6 Tubin 00:00 06:30 6.50 6,023 9,918 COMPZ CASING RUNL P Trip In Hole With 3-1/2" Production Liner on 3-1/2" PH-6 tubing from 6,023' MD to 9,918' MD. Hole took proper displacement. Monitored via trip tank. Up and down wts. every 30 joints. 6,266' MD Up wt 118K, Down wt 103K, 7,204' MD Up wt 125K Down wt 103K, 8,140' MD Up wt 132K Down wt 105K, 9,076' MD Up wt 140K Down wt 104K. 06:30 09:30 3.00 9,918 9,918 COMPZ CASING CIRC P 9,918' Circulate Bottoms Up at 28 gpm with 920 standpipe psi, Flow out 2% Up wt 145K Down wt 108K. Total strokes pumped 1,400. Rig down Crossover from PH-6 tubing to to drive. Blow down to drive. 09:30 11:30 2.00 9,918 10,346 COMPZ CASING RUNL P Trip in hole from 9,918' MD to 10,346' MD at 20 ft/min running speed. Tagged up 11' deep. Up wt 150K Down wt 118K. 11:30 12:30 1.00 10,346 10,324 COMPZ CASING RUNL P Trip out of hole from 10,346' MD to 10,230' MD. Lay down 17.80' pup ~oint Tri in hole to 10,324' 12:30 13:00 0.50 10,324 10,346 COMPZ CASING RUNL P Pick up one joint PH-6 tubing 31.20' to replace pup laid down. Make up cement head. Check depth 5' stick in to 10, 346' M D. 13:00 17:30 4.50 10,346 10,346 COMPZ CEMEN- CIRC P 10,346' MD, Circulate and condition mud at 28 gpm with 990 standpipe psi, Flow out 2%. Up wt 150K Down wt 118K, 400 strokes pumped loss of pump pressure and returns. Continued circulating at reduced rate 14 gpm 340 standpipe psi Flow out 0%. Held PJSM for cement job. Total Strokes Pum ed 1,219. 17:30 19:15 1.75 10,346 10,346 COMPZ CEMEN" PUCM P Turn over to cementers. Pump 5 bbl's water pressure test lines to 4,000 psi. Pump 10 bbl 13.5 ppg mudpush - 20.7 bbl's 15.8 ova cement. Shut down break cement line and flush free of cement reattach cement line. U wt 150K Down wt 120K. 19:15 20:30 1.25 10,346 10,346 COMPZ CEMEN" DISP P Drop bottom plug. Displace cement with 76.5 bbl's 12.5 ppg mud. Note: picked up Liner wiper plug w/ 71.7 bbls displaced (calculated liner volume 4.71 bbls). Up wt 150K Down wt 120K. Started displacement 19:11 Mud push at shoe 19:50 (46 bbl's) Cement at shoe 19:58 (56.3bb1's) Plug bumped 20:36 (76.6 bbl's Cement In Place 20:36 ~~m®~ ~ s ~~~~ ~~ of ~~ • Time Logs Date____ ___ From To ___ Dur S Depth E. Depth Phase Code Subcode T CommEnt 20:30 21:00 ,_ _ 0.50 10,346 . 10,346 COMPZ CEMEN" DISP _ P ______ Pressure up to 3,000 psi. Slack off 20K on hanger. Pressure up to 4,000 psi. Bleed psi off to 900 psi pull up to release packer dogs. Rotate slowly a 130K down wei ht set acker. 21:00 23:00 2.00 10,346 10,346 COMPZ CEMEN' DISP P Pull up 8' to 9,696' MD. Circulate (long way) at 170 gpm with 2,690 psi 26% flow out, Pumped 5,500 strokes total. PH increased to 10.5 @ bottoms u and cemnet shakers 23:00 00:00 1.00 10,346 10,346 COMPZ CEMEN' RURD P Rig down cement head as per baker re 3/18/2009 Trip Out laying down 3-1/2" PH-6 tubing, Pull wear bushing, Service rig, PJSM Run completion tubing per detail to 6,317 00:00 00:45 0.75 10,346 9,696 COMPZ RPCOM PULD P Rig down Cement head per Baker Re .Blow down lines. 00:45 01:15 0.50 9,696 9,696 COMPZ RPCOM OWFF P Monitor Well, Pump 18 bbl dry job. 14.5 ppg 135 spm with 1,550 stand i e si. 23% flow out 01:15 01:30 0.25 9,696 9,696 COMPZ RPCOM PULL P Blow down top drive. Hold PJSM for la in down PH-6 Tubin . 01:30 06:00 4.50 9,696 4,623 COMPZ RPCOM PULL P Trip out of hole laying down 3-1 /2" PH-6 Tubing w/ Liner running tool. From 9,696' MD to 4,263' MD. 195 joints layed down. Monitoring hole fill via tri tank. 06:00 09:30 3.50 4,623 7 COMPZ RPCOM PULL P Trip out of hole laying down 3-1/2" PH-6 tubing w/liner running tool from 4,263' MD to running tool.(Liner runnin tool 7' 09:30 10:15 0.75 7 0 COMPZ RPCOM PULL P Change elevators, Lay down liner runnin tool Per Baker re 10:15 11:00 0.75 0 0 COMPZ RPCOM OTHR P Back out lock down screws. Pull wear bushin . 11:00 11:30 0.50 0 0 COMPZ RPCOM SVRG P Change elevators, Clean and clear rig floor. Prep for picking up tubing. Grease travelin blocks. 11:30 12:00 0.50 0 0 COMPZ RPCOM SFTY P Post job review on laying down 3-1/2" PH-6 tubing, PJSM on picking up 3-1/2" tubing and gaslift mandrels, Seal assembl . 12:00 15:15 3.25 0 1,186 COMPZ RPCOM RCST P Trip in hole w/ seal assembly and 3-1/2" L-80 9.3 ppf tubing to 1,186' MD (36 jts.) as per running detail. Up wt 79K Down wt 82K. 15:15 15:45 0.50 1,186 1,186 COMPZ RPCOM RCST T Change out hydraulic tubing tongs. 15:45 18:00 2.25 1,186 3,200 COMPZ RPCOM RCST P Trip in hole w! 3-1/2" L-80 9.3 ppf tubing from 1,186' to 3,200' MD as per running detail. (100 jts) Up wt 95K Down wt 92 K 18:00 18:30 0.50 3,200 3,200 COMPZ RPCOM CIRC P Make up head pin & pump 5 bbl 14 83 vis. d 'ob 10 s m. 18:30 00:00 5.50 3,200 6,317 COMPZ RPCOM RCST P Trip in hole w/ 3-1/2" L-80 9.3 ppf tubing from 3,200' to 6,317' MD as per running detail. Up wt 108K Down wt 95K 1~~C~f? R~ 4Y~ ~ l Time Logs _ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 3/19/2009 _ 24 hr Summary Complete running 3-1/2" tubing, Space out, Pick up pup and hanger, Displace well to seawater, Land hanger, Test tubin /Annulus. Shear SOV in lower aslift. 00:00 03:15 3.25 6,317 9,717 COMPZ RPCOM RCST P Trip in hole w/ 3-1 /2" L-80 9.3 ppf tubing from 6,317' MD to 9,717' MD. Ta no o ni le set down 10K, 03:15 03:45 0.50 9,717 9,717 COMPZ RPCOM OTHR P Make Up Head pin, Chicksan, Lo torque valve and circulating hose to tubin strip . 03:45 04:15 0.50 9,717 9,700 COMPZ RPCOM HOSO P Pressure up tubing string to 500 psi. Pick up slowly watch for psi to bleed off. Pressure bled off and verified acker to 9,701.5' 04:15 05:30 1.25 9,700 9,700 COMPZ RPCOM HOSO P Rig down circulating equipment, Pull out of hole laying down 3 joints tubing, Pick up 9.79' tubing pup joint, Pick up last joint of tubing laid down, Make up hanger to top of joint. Make u landin 'oint to hap er, 05:30 06:15 0.75 9,700 9,700 COMPZ RPCOM OTHR P Make Up Head pin, Chicksan, Lo torque valve and circulating hose to dis lace well to seawater. 06:15 06:30 0.25 9,700 9,700 COMPZ RPCOM PRTS P Close Hydril element, test finer packer with 1,500 psi for 10 minutes. Prior to dis lacin mud. Good test 06:30 07:00 0.50 9,700 9,700 COMPZ RPCOM SFTY P PJSM on for seawater displacement and spotting corrosion inhibitor. A oint s ill cham ion. 07:00 09:30 2.50 9,700 9,700 COMPZ RPCOM CIRC P 9,700' MD. Pump 16 bbl 8.4 ppg 191 vis spacer, Chase with seawater at 175 gpm with 2,070 psi, Flowout 31% Clean seawater returned at surface 4,034 strokes. Continued circulating with 178 gpm, 930 psi, 31 % flow out. (Clean drip pan, Prep rockwasher for move) 09:30 10:00 0.50 9,700 9,700 COMPZ RPCOM CRIH P Load 5 bbls seawater on vac truck, Mix corrosion inhibitor. (Continue cleaning drip pan, Prepping misc rig areas for move 10:00 11:15 1.25 9,700 9,700 COMPZ RPCOM CRIH P 9,700' MD. Spot corrosion inhibitor in the annulus top of packer to bottom gas lift mandrel. Spotted with seawater at 105 gpm,340 psi, 24% flow out. 1,064 total strokes 11:15 12:00 0.75 0 0 COMPZ RPCOM HOSO P Land hanger, Run in lock down screws per FMC rep. Rig up to ressure test tubin . ~ ~Par~e 47 of ~8 I r~ i Time Logs _. _ Date From To Dur S. De th E. De th ~ Phase _ -- Code Subcode T Comment 12:00 13:45 1.75 0 0 COMPZ RPCOM DHEQ P Pressure test lines in cellar to 3,000 psi. Open annulus, Pressure up on tubing to 2,500 psi. Hold psi for 15 min (Chart test) Annulus monitored for returns. No returns.Bleed off tubing pressure to 1,500 psi. Pressure up to 2,500 psi on annulus. Hold pressure for 30 minutes. (Chart test) Tubing pressure increased to 2,200 psi. Bleed tubing pressure off to 0. Shear off valved did shear and annulus si bled to 0. 13:45 14:15 0.50 0 0 COMPZ RPCOM OTHR P Rig down head pin and circulating lines. Blow down 14:15 15:00 0.75 0 0 COMPZ RPCOM OTHR P Pull landing joint install 2-way check per FMC rep. (Cleaning pits and re in ri for move 15:00 19:15 4.25 0 0 COMPZ RPCOM NUND P PJSM Nipple Down BOP's. Flow line, Riser, turnbuckles and stack. Continue prepping rig for move and cleanin its. 19:15 22:45 3.50 0 0 COMPZ RPCOM NUND P Prep tubing hanger, Nipple up tree, (Orientation per 2N pad operator) Test tree 250 psi low 5,000 psi high. (Good Test) Continued prepping rig for move, Cleaning pits, Rockwasher. Blow down water to sub. Prep wheel wells for move. 22:45 23:15 0.50 0 0 COMPZ RPCOM OTHR P Pull 2 Way check valve. Continue re in ri for move. 23:15 00:00 0.75 0 0 COMPZ RPCOM FRZP P Rig up lines to freeze protect well and allow to U tube. 3/20/2009 . Set BPV N/D BOP's. N/U tree. Test tree. R/U & freeze protect. Prep rig for move. 00:00 05:15 5.25 0 0 COMPZ RPCOM FRZP P Freeze protect well with diesel pumping with "little red" down annulus & taking returns thru tubing. Pump rate .75 bbl/min with 600 psi.72 bbl's pumped.Shut in tubing pressure = 0.0 psi. Shut in annulus pressure = 0.0 psi. Rig up circulating hoses to allow annulus and tubing to communicate U-tubing fluid. Final shut in pressure = 0.0 psi. (Continued prepping rig for move. Truck hooked to rockwasher spun U 'oint on driveline 05:15 08:30 3.25 0 0 COMPZ RPCOM OTHR P Instal back pressure valve, Install gauges on tree and record shut in pressures. Pressure = 0.0 psi. Complete cleaning pits and cellar box. Ri released 08:30 ~~ __ ®® €'~tge ~~ ~f ~~ 2N-305A Post Rig Well Work DATE SUMMARY 3/25/09 TAGGED MUD @ 10070' SLM. SET CATCHER @ 9659'. PULLED SOV ET DV @ 9565' RKB. TESTED IA 2500 PSI, GOOD. PULLED CATCHER. READY FOR CTU. 3/31/09 PERFORMED MUD CLEAN OUT TO PBTD @ 10210 CTMD, DISPLACED TUBING WITH DIESEL, READY FOR S/L. 4/1/09 DRIFTED TBG TO 10200' SLM WITH 2.72" x 10' DUMMY GUN. BOTTOM PROPOSED PERF: 10105'. READY FOR E-LINE. 4/3/09 PERFORATE INTERVAL FROM 10095' TO 10105' USING 2.5" HSD HYPERJET / 2506 RDX API PENETRATION: 13.1", ENTRANCE HOLE DIAMETER: 0.43", 6 SPF, 60 DEGREE PHASING 4/4/09 TAGGED @ 10241' RKB. MEASURED BHP @ 10100' RKB: 3394 PSI. COMPLETE. 4/5/09 Pumped T2 Bermuda sand, frac, to completion placed a total of 180194# with # 10 PPA, 16/20 Carbolite to formation, 106% of job placed with an additional 112 bbl of 10 ppa pumped. Flushed 87 bbls with 50 bbls freeze protect included. Used 2104 bbls of SW and 90 bbls of diesel. Estimated BHP=3449 psi 10 min SIP = 1657 psi. RDMO inspect pad turn over to DSO. 4/13/09 PERFORM FILL CLEAN OUT TO PBTD @ 10243 CTMD, WELL IS FREEZE PROTECTED, READY FOR S/L. 4/14/09 GAUGE TBG TO 2.69" & TAG @ 10188' SLM. SET 2.75" STANDING VLV @ 9659' RKB. PULLED DMY VLV @ 9565' RKB (***BTM PACKING STACK DAMAGED***). DISPLACED TBG/ IA WITH 200 BBLS DIESEL. SET 5/16" ORIFICE @ 9565' RKB. ATTEMPT TO PULL STANDING VLV. ***EST ~10' FILL ON TOP OF SV*** IN PROGRESS. 4/15/09 BAILED FRAC SAND FROM 9631' SLM TO 9640' SLM. PULLED STANDING VLV @ 9659' RKB. JOB COMPLETE. ~ ~ ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2N Pad 2N-305A Permit to Drill: 208-202 API: 50-103-20349-01 Definitive Survey Report 25 March, 2009 ~~Z~ r.~ $pcrry C~riiiing Servi+c~~ ConocoPhillips Definitive Surrey Report • Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: We112N-305 Project: Kuparuk River Unit TVD Reference: 2N-305A @ 160.4ft (D15 (41.15+119.3)) Site: Kuparuk 2N Pad MD Reference: 2N-305A @ 160.4ft (D15 (41.15+119.3)) Well: 2N-305 North Reference: True Weilbore: 2N-305A Survey Calculation Method: Minimum Curvature Design: 2N-305A Database: CPAI EDM Production oject Kuparuk River Unit ~p System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level ro Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point ip Zone: Alaska Zone 04 Using geodetic scale factor Well 2N-305 -- - -- Well Position +N/-S 0.0 ft Northing: 5,912,000.60ft ~ Latitude: 70° 10' 13.902 N +E/-W 0.0 ft Easting: 461,063.88 ft Longitude: 150° 18' 48.111 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 119.3ft - Weilbore 2N-~05A Magnetics Model Name Sample Date BGGM2007 2/16/2009 Design - - 2N-305A Audit Notes: Version: 1.0 Phase: Vertical Section: Depth From (TVD) (ft) 41.1 Survey Program Date From To Declination Dip Angle Field Strength 21.98 80.66 57,614 ACTUAL Tie On Depth: 2,989.8 +N/-S +E/-W Direction (ft) (ft)'°' (°) 0.0 0.0 0.00 (ft) (ft) Survey (Weilbore) Tool Name Description Survey Date Y12.3 3,085.9 2,989.8 2N-305 IIFR (2N-305) 10,300.6 2N-305A MWD (2N-305A) MWD+IFR-AK-I',AZ-SL MWD+IFR-AK-CAZ-SC M1rUD+iFR AK CAZ SCC MWD+IFR AK CAZ SCC 6/13/2001 1: 2/24/2009 1: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northiny Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 41.1 O.Ou 0.00 41.1 -119. 0.0 0.0 5,912,u00.o 461,063.9 0.0 0.00 UNDEFINED 212.3 0.56 101.99 212.3 51.9 -0.2 0.8 5,912,000.4 461,064.7 0.3 -0.17 MWD+IFR-AK-CAZ-SC (1) 242.7 0.54 86.86 242.7 82.3 -0.2 1.1 5,912,000.4 461,065.0 0.5 -0.20 MWD+IFR-AK-CAZ-SC (1) 280.2 0.61 73.11 280.2 119.8 -0.1 1.5 5,912,000.5 461,065.4 0.4 -0.13 MWD+IFR-AK-CAZ-SC (1) 311.6 1.02 48.30 31 t.6 151.2 0.1 1.8 5,912,000.7 461,065.7 1.7 0.11 MWD+IFR-AK-CAZ-SC (1) 342.5 1.92 26.26 342.5 182.0 0.8 2.3 5,912,001.3 461,066.2 3.4 0.75 MWD+IFR-AK-CAZ-SC (1) 372.8 3.15 19.24 372.7 212.3 2.0 2.8 5,912,002.6 461,066.7 4.2 1.99 MWD+IFR-AK-CAZ-SC (1) 403.5 4.54 13.87 403.4 242.9 4.0 3.3 5,912,004.6 461,067.2 4.7 3.97 MWD+IFR-AK-CAZ-SC (1) 433.8 5.35 10.68 433.6 273.2 6.5 3.9 5,912,007.1 461,067.8 2.8 6.53 MWD+IFR-AK-CAZ-SC (1) 463.6 6.39 6.62 463.2 302.8 9.5 4.3 5,912,010.1 461,068.3 3.8 9.54 MWD+IFR-AK-CAZ-SC (1) 494.0 7.68 4.07 493.4 332.9 13.2 4.7 5,912,013.8 461,068.6 4.4 13.24 MWD+IFR-AK-CAZ-SC (1) 524.8 8.95 4.32 523.8 363.4 17.7 5.0 5,912,018.3 461,069.0 4.1 17.68 MWD+IFR-AK-CAZ-SC (1) ~ 555.0 9.67 6.63 553.6 393.2 22.5 5.5 5,912,023.1 461,069.5 2.7 22.54 MWD+IFR-AK-CAZ-SC (1) 3/25/2009 10:38:36AM Page 2 COMPASS 2003.16 Build 42F ConocoPhillips Definitive Survey Report Company: Project: Site: Well: Wellbore: Design; Survey ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: We112N-305 Kuparuk River Unit TVD Reference: 2N-305A @ 160.4ft (D15 (41.15+119.3)) Kuparuk 2N Pad MD Reference: 2N-305A @ 160.4ft (D15 (41.15+119.3)) 2N-305 North Reference: True 2N-305A Survey Calculation Method: Minimum Curvature 2N-305A Database: CPAI EDM Production Map MD Inc Azi TVD TVDSS +N/-S +Ei-W Northing (ft) (°) (°) Ift) (ft) lft) (ft) (ft) 585.9 9.61 7.66 564.1 423.7 27.7 6.1 5,912,028.2 617.1 10.10 8.24 614.8 454.4 33.0 6.9 5,912,033.5 646.2 10.89 9.06 643.5 483.0 38.2 7.7 5,912,038.8 678.1 11.68 10.29 674.8 514.3 44.4 8.7 5,912,044.9 707.0 12.90 11.16 703.0 542.6 50.4 9.9 5,912,051.0 739.6 14.29 11.30 734.6 574.2 57.9 11.3 5,912,058.4 830.9 15.87 13.56 822.9 662.4 81.1 16.5 5,912,081.6 891.3 16.35 13.75 880.9 720.4 97.4 20.4 5,912,097.9 940.3 18.21 14.82 927.7 767.2 111.5 24.0 5,912,112.0 1,000.3 19.51 14.81 984.4 823.9 130.2 29.0 5,912,130.7 1,065.2 20.84 14.14 1,045.3 884.9 151.9 34.6 5,912,152.3 1,128.4 22.08 13.13 1,104.1 943.7 174.4 40.0 5,912,174.8 1,197.3 24.83 12.23 1,167.4 1,007.0 201.2 46.0 5,912,201.5 1,286.3 28.04 11.71 1,247.1 1,086.6 239.9 54.3 5,912,240.2 1,349.7 29.21 11.73 1,302.7 1,142.3 269.7 60.4 5,912,269.9 1,381.3 30.65 11.54 1,330.1 1,169.6 285.1 63.6 5,912,285.3 1,444.3 32.54 10.38 1,383.7 1,223.3 317.5 69.9 5,912,317.7 1,507.7 34.94 10.03 1,436.5 1,276.0 352.1 76.1 5,912,352.3 1,571.1 38.10 9.73 1,487.4 1,326.9 389.3 82.6 5,912,389.4 1,634.1 40.48 8.91 1,536.2 1,375.7 428.7 89.0 5,912,428.8 1,697.5 42.54 8.33 1,583.6 1,423.2 470.2 95.3 5,912,470.3 1,760.3 44.46 8.25 1,629.2 1,468.7 513.0 101.5 5,912,513.0 1,823.4 45.64 8.44 1,673.8 1,513.3 557.2 108.0 5,912,5572 1,886.2 47.44 8.35 1,717.0 1,556.5 602.3 114.7 5,912,602.2 1,952.2 49.22 7.67 1,760.8 1,600.4 651.1 121.5 5,912,651.0 2,013.1 51.33 7.16 1,799.8 1,639.3 697.5 127.6 5,912,697.4 2,076.5 53.68 6.94 1,838.4 1,677.9 747.5 133.8 5,912,747.3 2,139.9 55.90 7.13 1,874.9 1,714.5 798.9 140.1 5,912,798.7 2,203.5 57.67 6.30 1,909.7 1,749.3 851.7 146.3 5,912,851.5 2,266.5 59.09 7.27 1,942.7 1,782.3 904.9 152.7 5,912,904.6 2,328.8 60.64 6.70 1,974.1 1,813.6 958.5 159.2 5,912,958.1 2,392.2 61.13 6.73 2,004.9 1,844.5 1,013.5 165.7 5,913,013.1 2,455.3 61.81 5.68 2,035.0 1,874.6 1,068.6 171.7 5,913,068.2 2,518.5 61.88 5.68 2,064.8 1,904.4 1,124.0 177.2 5,913,123.6 2,582.6 62.58 5.70 2,094.7 1,934.3 1,180.5 182.8 5,913,180.0 2,646.2 62.75 6.20 2,123.9 1,963.5 1,236.6 188.7 5,913,236.1 2,709.4 62.66 5.55 2,152.9 1,992.5 1,292.5 194.4 5,913,292.0 2,772.7 62.78 6.23 2,181.9 2,021.5 1,348.5 200.2 5,913,347.9 2,835.9 62.62 6.23 2,210.9 2,050.5 1,404.3 206.3 5,913,403.7 2,899.1 62.36 6.04 2,240.1 2,079.6 1,460.0 212.3 5,913,459.3 Map Vertical Fasting DLS Section (ft) (°1100') (ft) Survey Tool Name 461,070.1 0.6 27.68 MWD+IFR-AK-CAZ-SL (tl 461,070.9 1.6 32.96 MWD+IFR-AK-CAZ-SC (1) 461,071.7 2.8 38.21 MWD+IFR-AK-CAZ-SC (1) 461,072.8 2.6 44.36 MWD+IFR-AK-CAZ-SC (1) 461,074.0 4.3 50.41 MWD+IFR-AK-CAZ-SC (1) 461,075.5 4.3 57.91 MWD+IFR-AK-CAZ-SC (1) 461,080.8 1.8 81.12 MWD+IFR-AK-CAZ-SC (1) 461,084.8 0.8 97.39 MWD+IFR-AK-CAZ-SC (1) ~ 461,088.5 3.8 111.50 MWD+IFR-AK-CAZ-SC (1) 'I 461,093.5 2.2 130.23 MWD+IFR-AK-CAZ-SC (1) 461,099.2 2.1 151.91 MWD+IFR-AK-CAZ-SC (1) 461,104.8 2.0 174.38 MWD+IFR-AK-CAZ-SC (1) 461,111.0 4.0 201.16 MWD+IFR-AK-CAZ-SC (1) 461,119.4 3.6 239.90 MWD+IFR-AK-CAZ-SC (1) 461,125.7 1.8 269.65 MWD+IFR-AK-CAZ-SC (1) 461,128.9 4.6 285.07 MWD+IFR-AK-CAZ-SC (1) 461,135.4 3.2 317.47 MWD+IFR-AK-CAZ-SC (1) 461,141.8 3.8 352.13 MWD+IFR-AK-CAZ-SC (1) i 461,148.4 5.0 389.29 MWD+IFR-AK-CAZ-SC (1) 461,155.1 3.9 428.66 MWD+IFR-AK-CAZ-SC (1) 461,161.6 3.3 470.21 MWD+IFR-AK-CAZ-SC (1) 461,168.1 3.1 512.99 MWD+IFR-AK-CAZ-SC (1) 461,174.8 1.9 557.18 MWD+IFR-AK-CAZ-SC (1) 461,181.7 2.9 602.30 MWD+IFR-AK-CAZ-SC (1) 461,188.8 2.8 651.09 MWD+IFR-AK-CAZ-SC (1) 461,195.0 3.5 697.55 MWD+IFR-AK-CAZ-SC (1) 461,201.5 3.7 747.46 MWD+IFR-AK-CAZ-SC (1) 461,208.1 3.5 798.89 MWD+IFR-AK-CAZ-SC (1) 461,214.6 3.0 851.70 MWD+IFR-AK-CAZ-SC (1) 461,221.2 2.6 904.93 MWD+IFR-AK-CAZ-SC (1) 461,228.0 2.6 958.46 MWD+IFR-AK-CAZ-SC (1) 461,234.8 0.8 1,013.49 MWD+IFR-AK-CAZ-SC (1) 461,241.0 1.8 1,068.59 MWD+IFR-AK-CAZ-SC (1) 461,246.8 0.1 1,123.99 MWD+IFR-AK-CAZ-SC (1) 461,252.8 1.1 1,180.47 MWD+IFR-AK-CAZ-SC (1) ~i 461,258.9 0.7 1,236.64 MWD+IFR-AK-CAZ-SC (1) i 461,264.9 0.9 1,292.51 MWD+IFR-AK-CAZ-SC (1) 461,271.0 1.0 1,348.48 MWO+IFR-AK-CAZ-SC (1) 461,277.4 0.3 1,404.32 MWD+IFR-AK-CAZ-SC (1) 461,283.6 0.5 1,459.99 MWD+IFR-AK-CAZ-SC (1) 3/25/2009 10:38:36AM Page 3 COMPASS 2003.16 Build 42F ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) In c. Locat,Co-ordinate Reference: We112N-305 Project: Kuparuk River Unit ND Reference: 2N-305A @ 160.4ft (D15 (41.15+119.3)) Site: Kuparuk 2N Pad MD Refere nce: 2N-305A @ 160.4ft (D15 (41.15+119.3)) Well: 2N-305 North Reference: True Wellbore: 2N-305A Survey Ca lculation Met hod: Minimu m Curvature Design: 2N-305A Datahass: CPAI EDM Production Survey I{ Map_, Map Vertical MD (ft) Inc (°1 Azi (°) TVD (ft) TVDSS lftl +N/-S (ft) +El-W Ift1 Northing (ft) Fasting DLS (ft) (°/100') Section (ft) Survey Tool Name 2,989.8 62.25 0.83 2,282.2 2,121.8 1,539.8 221.3 5,913,539.1 461,283.1 0.8 1,539.81 MWD+IFR-AK-CAZ-SC (1) 3,085.9 60.50 5.87 2,328.3 2,167.8 1,623.7 230.6 5,913,622.9 461,302.8 2.0 1,623.68 MWD+IFR-AK-CAZ-SC (2) ,i 3,130.5 58.31 5.27 2,357.0. 2,190.5 1,661.8 234.3 5,913,661.0 461,306.7 5.1 1,661.83 MWD+IFR-AK-CAZ-SC (2) 3,166.0 59.33 6.51 2,369.4 2,208.9 1,692.1 237.5 5,913,691.3 461,310.0 4.1 1,692.10 MWD+IFR-AK-CAZ-SC (2) 3,259.8 63.10 9.91 2,414.6 2,254.1 1,773.5 249.3 5,913,772.6 461,322.2 5.1 1,773.45 MWD+IFR-AK-CAZ-SC (2) 3,354.0 65.35 12.55 2,455.5 2,295.1 1,856.6 265.8 5,913,855.6 461,339.2 3.5 1,856.59 MWD+IFR-AK-CAZ-SC (2) 3,449.4 67.10 6.90 2,494.0 2,333.5 1,942.6 280.5 5,913,941.5 461,354.3 5.7 1,942.58 MWD+IFR-AK-CAZ-SC (2) i 3,499.1 66.62 8.87 2,513.5 2,353.1 1,987.8 286.8 5,913,986.7 461,360.8 3.8 1,987.83 MWD+IFR-AK-CAZ-SC (2) 3,543.0 66.45 9.04 2,531.0 2,370.6 2,027.7 293.0 5,914,026.5 461,367.3 0.5 2,027.66 MWD+IFR-AK-CAZ-SC (2) 3,637.0 66.30 7.15 2,568.7 2,408.2 2,112.9 305.2 5,914,111.7 461,379.9 1.8 2,112.90 MWD+IFR-AK-CAZ-SC (2) 3,732.6 65.94 8.28 2,607.4 2,446.9 2,199.6 316.9 5,914,198.3 461,392.1 1.1 2,199.55 MWD+IFR-AK-CAZ-SC (2) ~ 3,826.6 66.01 8.50 2,645:6 2,485.2 2,284.4 329.4 5,914,283.1 461,405.0 0.2 2,284.42 MWD+IFR-AK-CAZ-SC (2) i 3,921.1 66.90 10.70 2,683.4 2,522.9 2,369.8 343.9 5,914,368.4 461,419.9 2.3 2,369.84 MWD+IFR-AK-CAZ-SC (2) 4,015.5 67.07 12.49 2,720.3 2,559.9 2,455.0 361.3 5,914,453.5 461,437.8 1.8 2,454.99 MWD+IFR-AK-CAZ-SC (2) 4,110.2 67.01 11.97 2,757.2 2,596.8 2,540.2 379.8 5,914,538.5 461,456.7 0.5 2,540.77 MWD+IFR-AK-CAZ-SC (2) 4,203.7 67.65 10.07 2,793.3 2,632.9 2,624.9 396.3 5,914,623.2 461,473.6 2.0 2,624.91 MWD+IFR-AK-CAZ-SC (2) ~ 4,298.5 66.06 9.39 2,830.5 2,670.1 2,710.8 411.0 5,914,708.9 461,488.8 1.8 2,710.75 MWD+IFR-AK-CAZ-SC (2) 4,391.7 66.20 8.96 2,868.3 2,707.8 2,795.0 424.6 5,914,793.1 461,502.8 0.4 2,794.97 MWD+IFR-AK-CAZ-SC (2) ~ 4,486.7 66.90 9.05 2,906.1 2,745.6 2,881.0 438.2 5,914,879.0 461,516.9 0.7 2,880.97 MWD+IFR-AK-CAZ-SC (2) 4,581.7 66.76 8.22 2,943.5 2,783.0 2,967.4 451.4 5,914,965.3 461,530.5 0.8 2,967.35 MWD+IFR-AK-CAZ-SC (2) 4,676.2 65.72 7.18 2,981.5 2,821.1 3,053.0 463.0 5,915,050.9 461,542.5 1.5 3,053.03 MWD+IFR-AK-CAZ-SC (2) 4,770.7 66.00 7.50 3,020.2 2,859.7 3,138.6 474.0 5,915,136.4 461,554.0 0.4 3,138.61 MWD+IFR-AK-CAZ-SC (2) 4,864.4 65.86 7.54 3,058.4 2,898.0 3,223.4 485.2 5,915,221.2 461,565.6 0.2 3,223.42 MWD+IFR-AK-CAZ-SC (2) 4,958.6 67.02 7.52 3,096.0 2,935.6 3,309.0 496.5 5,915,306.7 461,577.3 1.2 3,309.00 MWD+IFR-AK-CAZ-SC (2) 5,053.0 66.14 7.67 3,133.6 2,973.1 3,394.9 507.9 5,915,392.5 461,589.2 0.9 3,394.91 MWD+IFR-AK-CAZ-SC (2) 5,148.3 66.56 7.25 3,171.8 3,011.3 3,481.4 519.3 5,915,479.0 461,601.0 0.6 3,481.42 MWD+IFR-AK-CAZ-SC (2) 5,241.8 66.96 6.28 3,208.7 3,048.2 3,566.7 529.4 5,915,564.2 461,611.6 1.0 3,566.73 MWD+IFR-AK-CAZ-SC (2) 5,335.5 66.34 7.01 3,245.8 3,085.4 3,652.2 539.3 5,915,649.6 461,622.0 1.0 3,652.20 MWD+IFR-AK-CAZ-SC (2) ~ 5,430.9 66.21 7.86 3,284.2 3,123.8 3,738.8 550.6 5,915,736.2 461,633.7 0.8 3,738.84 MWD+IFR-AK-CAZ-SC (2) 5,526.2 66.19 7.07 3,322.6 3,162.2 3,825.2 562.0 5,915,822.5 461,645.5 0.8 3,825.20 MWD+IFR-AK-CAZ-SC (2) 5,619.4 65.74 6.87 3,360.6 3,200.2 3,909.7 572.3 5,915,906.9 461,656.2 0.5 3,909.73 MWD+IFR-AK-CAZ-SC (2) 5,714.4 65.48 7.92 3,399.9 3,239.4 3,995.6 583.4 5,915,992.7 461,667.8 1.0 3,995.56 MWD+IFR-AK-CAZ-SC (2) 5,808.9 65.61 8.68 3,439.0 3,278.5 4,080.7 595.9 5,916,077.7 461,680.7 0.7 4,080.66 MWD+IFR-AK-CAZ-SC (2) ~ 5,902.9 65.46 8.85 3,477.9 3,317.5 4,165.2 608.9 5,916,162.2 461,694.1 0.2 4,165.23 MWD+IFR-AK-CAZ-SC (2) 5,995.8 66.75 11.32 3,515.6 3,355.1 4,248.9 623.8 5,916,245.8 461,709.4 2.8 4,248.86 MWD+IFR-AK-CAZ-SC (2) 6,091.1 66.33 10.61 3,553.5 3,393.0 4,334.7 640.4 5,916,331.5 461,726.5 0.8 4,334.66 MWD+IFR-AK-CAZ-SC (2) 6,185.4 66.91 9.32 3,590.9 3,430.5 4,419.9 655.4 5,916,416.6 461,741.9 1.4 4,419.90 MWD+IFR-AK-CAZ-SC (2) 6,280.1 66.05 7.57 3,628.7 3,468.2 4,505.8 668.1 5,916,502.4 461,755.1 1.9 4,505.76 MWD+IFR-AK-CAZ-SC (2) 6,374.9 66.17 7.53 3,667.1 3,506.7 4,591.8 679.5 5,916,588.4 461,767.0 0.1 4,591.76 MWD+IFR-AK-CAZ-SC (2) 6,469.9 66.63 6.85 3,705.1 3,544.7 4,678.0 690.4 5,916,674.6 461,778.3 0.8 4,678.05 MWD+IFR-AK-CAZ-SC (2) 3/25/2009 90:38:36AM Page 4 COMPASS 2003.16 Build 42F ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: We112N-305 Project: Kuparuk River Unit TVD Reference: 2N-305A @ 160.4ft (D15 (41.15+119.3)) Site: Kuparuk 2N Pad MD Refere nce: 2N-305A @ 160.4ft (D15 (41.15+119.3)) Welk 2N-305 North Reference: True Wellbore: 2N-305A Survey Calculation Meth od: Minimu m Curvature Design: 2N-305A Database: _ _ CPAI E DM Production Survey Map Map Vertical MD lnc Azi ND NDSS +N/-5 +Ei-W Northing 'Fasting DL 5 Section (ft) (°) (°) (ft) (ft) (ft) (ft} (ft} (ft) (°/1 00') (ft) Survey Tool Name 6,564.4 66.06 7.16 3,743.1 3,582.6 4,164.0 701.0 5,916,160.5 461,789.3 0.7 4,764.04 MWD+IFR-Ak-CAZ-5C t2) 6,658.0 66.29 6.84 3,780.9 3,620.4 4,849.0 711.4 5,916,845.4 461,800.2 0.4 4,848.98 MWD+IFR-AK-CAZ-SC (2) i~ 6,752.6 66.83 6.69 3,818.5 3,658.0 4,935.2 721.6 5,916,931.5 461,810.8 0.6 4,935.19 MWD+IFR-AK-CAZ-SC (2) 6,846.7 66.81 7.09 3,855.5 3,695.1 5,021.0 732.0 5,917,017.3 461,821.6 0.4 5,021.04 MWD+IFR-AK-CAZ-SC (2) 6,941.3 66.40 8.23 3,893.1 3,732.7 5,107.1 743.6 5,917,103.3 461,833.7 1.2 5,707.14 MWD+IFR-AK-CAZ-SC (2) 7,036.4 66.26 9.15 3,931.3 3,770.8 5,193.2 756.7 5,917,189.3 461,847.2 0.9 5,193.20 MWD+IFR-AK-CAZ-SC (2) 7,130.6 66.29 10.13 3,969.2 3,808.7 5,278.2 771.2 5,917,274.3 461,862.1 1.0 5,278.23 MWD+IFR-AK-CAZ-SC (2) j 7,224.2 67.22 8.89 4,006.1 3,845.7 5,363.0 785.4 5,917,359.0 461,876.8 1.6 5,363.02 MWD+IFR-AK-CAZ-SC (2) 7,319.2 66.63 7.85 4,043.3 3,882.9 5,449.5 798.1 5,917,445.3 461,889.9 1.2 5,449.45 MWD+IFR-AK-CAZ-SC (2) 7,413.0 66.07 8.94 4,081.0 3,920.5 5,534.5 810.6 5,917,530.3 461,902.9 1.2 5,534.50 MWD+IFR-AK-CAZ-SC (2) 7,507.8 66.75 8.72 4,118.9 3,958.4 5,620.3 824.0 5,917,616.1 461,916.7 0.7 5,620.32 MWD+IFR-AK-CAZ-SC (2) i 7,602.8 65.96 9.59 4,157.0 3,996.6 5,706.3 837.8 5,917,701.9 461,931.0 1.2 5,706.28 MWD+IFR-AK-CAZ-SC (2) ~ 7,697.9 66.08 9.70 4,195.7 4,035.2 5,791.9 852.4 5,917,787.5 461,946.0 0.2 5,791.92 MWD+IFR-AK-CAZ-SC (2) 7;792.4 65.88 8.98 4,234.1 4,073.7 5,877.1 866.4 5,917,872.5 461,960.4 0.7 5,877.06 MWD+IFR-AK-CAZ-SC (2) 7,886.5 65.45 8.35 4,272.9 4,112.5 5,961.9 879.3 5,917,957.3 461,973.8 0.8 5,961.90 MWD+IFR-AK-CAZ-SC (2) 7,980.4 65.38 8.44 4,312.0 4,151.5 6,046.3 891.8 5,918,041.7 461,986.7 0.1 6,046.33 MWD+IFR-AK-CAZ-SC (2) 8,075.4 65.94 8.59 4,351.1 4,190.7 6,131.9 904.6 5,918,127.2 461,999.9 0.6 6,131.93 MWD+IFR-AK-CAZ-SC (2) ~~~ 8,168.7 66.75 11.13 4,388.6 4,228.1 6,216.1 919.2 5,918,211.3 462,015.0 2.6 6,216.11 MWD+IFR-AK-CAZ-SC (2) 8,263.1 66.14 10.78 4,426.3 4,265.9 6,301.1 935.7 5,918,296.2 462,031.9 0.7 6,301.12 MWD+IFR-AK-CAZ-SC (2) 8,357.5 66.56 10.86 4,464.2 4,303.7 6,386.0 951.9 5,918,381.0 462,048.5 0.5 6,386.00 MWD+IFR-AK-CAZ-SC (2) 8,451.8 66.95 9.50 4,501.4 4,340.9 6,471.3 967.2 5,918,466.2 462,064.3 1.4 6,471.31 MWD+IFR-AK-CAZ-SC (2) 8,546.0 65.99 5.55 4,539.0 4,378.6 6,556.9 978.5 5,918,551.7 462,076.0 4.0 6,556.89 MWD+IFR-AK-CAZ-SC (2) 8,640.1 65.74 5.98 4,577.5 4,417.0 6,642.3 987.2 5,918,637.1 462,085.1 0.5 6,642.33 MWD+IFR-AK-CAZ-SC (2) ~ 8,735.1 65.86 7.40 4,616.4 4,456.0 6,728.4 997.3 5,918,723.1 462,095.6 1.4 6,728.37 MWD+IFR-AK-CAZ-SC (2) 8,827.9 65.34 8.35 4,654.7 4,494.3 6,812.1 1,008.8 5,918,806.7 462,107.7 1.1 6,812.06 MWD+IFR-AK-CAZ-SC (2) 8,923.4 64.94 9.56 4,694.9 4,534.5 6,897.7 1,022.3 5,918,892.3 462,121.6 1.2 6,897.68 MWD+IFR-AK-CAZ-SC (2) 9,018.5 65.47 10.11 4,734.8 4,574.3 6,982.7 1,037.1 5,918,977.2 462,136.8 0.8 i 6,982.72 MWD+IFR-AK-CAZ-SC (2) 9,112.1 66.37 9.71 4,773.0 4,612.5 7,066.9 1,051.8 5,919,061.3 462,151.9 1.0 7,066.93 MWD+IFR-AK-CAZ-SC (2) 9,207.2 66.48 8.93 4,811.0 4,650.6 7,153.0 1,065.9 5,919,147.3 462,166.5 0.8 7,152.99 MWD+IFR-AK-CAZ-SC (2) it 9,300.9 64.44 8.06 4,849.9 4,689.5 7,237.2 1,078.5 5,919,231.5 462,179.5 2.3 7,237.24 MWD+IFR-AK-CAZ-SC (2) 9,395.5 62.99 7.91 4,891.8 4,731.4 7,321.3 1,090.3 5,919,315.5 462,191.7 1.5 7,321.28 MWD+IFR-AK-CAZ-SC (2) 9,490.1 58.57 7.67 4,938.0 4,777.5 7,403.0 1,101.5 5,919,397.1 462,203.3 4.7 7,403.04 MWD+IFR-AK-CAZ-SC (2) 9,584.9 54.64 11.04 4,990.2 4,829.7 7,481.1 1,114.3 5,919,475.1 462,216.5 5.1 7,481.07 MWD+IFR-AK-CAZ-SC (2) 9,629.9 53.01 10.92 5,016.7 4,856.3 7,516.7 1,121.2 5,919,510.7 462,223.6 3.6 7,516.73 MWD+IFR-AK-CAZ-SC (2) i 9,678.6 51.06 10.18 5,046.7 4,886.2 7,554.5 1,128.2 5,919,548.4 462,230.8 4.2 7,554.49 MWD+IFR-AK-CAZ-SC (2) i 9,747.7 47.70 9.20 5,091.7 4,931.2 7,606.2 1,137.1 5,919,600.1 462,240.0 5.0 7,606.18 MWD+IFR-AK-CAZ-SC (2) !i 9,842.0 45.36 8.84 5,156.5 4,996.0 7,673.7 1,147.8 5,919,667.6 462,251.0 2.5 7,673.72 MWD+IFR-AK-CAZ-SC (2) 9,937.9 44.52 8.46 5,224.4 5,063.9 7,740.7 1,158.0 5,919,734.5 462,261.6 0.9 7,740.70 MWD+IFR-AK-CAZ-SC (2) 10,031.1 44.23 8.56 5,291.0 5,130.6 7,805.2 1,167.6 5,919,798.9 462,271.5 0.3 7,805.17 MWD+IFR-AK-CAZ-SC (2) I 10,064.8 44.01 8.87 5,315.3 5,154.8 7,828.4 1,171.2 5,919,822.1 462,275.2 0.9 7,828.41 MWD+IFR-AK-CAZ-SC (2) 3/25/2009 10:38:36AM Page 5 COMPASS 2003. t6 Build 42F ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Ina Local Co-ordinate Reference: ;, We112N-305 Project: Kuparuk River Unit TYD Ref®rence: 2N-305A @ 160.4ft (D15 (41.15+119.3)) Site: Kuparuk 2N Pad MD Reference: 2N-305A @ 160.4ft (D15 (41.15+119.3)) Well: 2N-305 North Reference: True Wellbore: 2N-305A Survey Calculation Method: Minimum Curvature Design: 2N-305A Database: CPAI EDM Production Survey ` Map Map Vertical MD Inc Azi TVD TVDSS +Nl-5 +E/-W Northing Easting DLS Section (ff) (~) l~l (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,159.6 4A.02 5.10 5,383.4 5,223.0 7,853.4 1,181.5 5,919,887.1 462,285.8 0.2 7,893.45 MWD+iFR-i,h-G;;:.-SC (2) 10,192.0 43.83 8.76 5,406.8 5,246.3 7,915.7 1,185.0 5,919,909.3 462,289.4 0.9 7,915.67 MWD+IFR-AK-CAZ-SC (2) 10,286.2 44.81 7.71 5,474.1 5,313.7 7,980.8 1,194.4 5,919,974.3 462,299.2 1.3 7,980.75 MWD+IFR-AK-CAZ-SC (2) 10,300.6 44.85 7.19 5,484.4 5,323.9 7,990.9 1,195.7 5,919,984.4 462,300.6 2.6 7,990.85 MWD+IFR-AK-CAZ-SC (2) i 10,335.0 44.85 7.19 5,508.7 5,348.3 8,014.9 1,198.7 5,920,008.5 462,303.7 0.0 8,014.92 PROJECTED to TD ~ 3/25/2009 10:38:36AM Page 6 COMPASS 2003.16 Build 42F ~~~,L L®G 'I' NSIi~II'T'TAY.. 'I'®e State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 2N-305A April 16, 2009 AK-MW-6247153 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Bryan Burinda, Sperry Drilling, 6900 Arctic Blvd., Anchorage, AK 99518 2N-305A 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Lo 50-103-20349-01 g 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Lo 50-103-20349-O1 g Digital Log Images 1 CD Rom 50-103-20349-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 90?-273-3535 Bryan. Bur-inda~halliburtoncom BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~ ~~~ Date: Signed: ~ ~ ~O~'2 ~~ ~ "}~ !~' WELL. I,®G T12A1~1S1VII'I"i'AI~ To: State of Alaska April 16, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`l' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 2N-305A AK-MW-6247153 1 LDWG formatted CD Rom with verification listing. API#: ~ 0-103-20349-01 0 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRAi~TSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan:Bun ruia~alliburton. com Date: Signed: ~c~~- :~~~ 1 ~~~ 3 a ~ ~ ~or~ocoPMilips FROM: Sandra D. Lemke, ATO1808 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Kuparuk River Unit 2N-305A DATE: 4/6/2009 TO: Christine Mahnken State of Alaska AOGCC 333 W. 7~' Ave. Suite 100 Anchorage, Alaska 99501-3539 Kuparuk River Unit, North Slope, Alaska 2N-305A X501032034901 Report and CDROM _ Final Well Report, Mud Logging Data, 2N-305A; Epoch, report date: 3/1412009; table of contents, uipment and crew, well data, geological data, drilling data, daily reports, formation logs; r log prints: Formation Log MD and TVD 2925-10335' md' LWD Combo Log MD and TVD 2925-10335 md' Gas Ratio Log MD and TVD 2925-10334' and Drilling Dynamics MD and TVD 2925-10335' and FIT GAS Log MD 2296-10335' and CDROM contains: well report, morning reports, LAS data, PDF and tiff format color log image files; DML; FIT data files and lithology remarks. CC: eSearch well files Contact: Pat Pe ett CPAI Geologist Receipt. Date: i / ~ t Wk ' Y ~ ~ ~ ~ yR d t~ ~ ~ ~ d f a v\ j ~~ x A r ~ r I, ! i ~ {tt ~ I ~. ~ f ~ .„_. .. a.. ~!_... . _ _ ... : ... ,..a A.~ Y.,a ALASSA ou Arm c~As C01~5ER~ATIOrT COIrII-IISSIOrT G. C. Alvord GKA Drilling Team Lead ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510-0360 SARAH PALlN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Tarn Oil Pool, 2N-305A ConocoPhillips Alaska Inc. Permit .No: 208-202 Surface Location: 6' FNL, 529' FEL, SEC. 3, T9N, R7E, UM Bottomhole Location: 2094' FNL, 777' FWL, SEC. 26, T10N R7E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincer ly, Daniel T. Seamount, Jr. p~ ~ Chair DATED this (day of January, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS N PERMIT TO DRILL ~ 20 AAC 25.005 1a. Type of Work: Drill ^ Re-drill ^/ Re-entry ^ 1b. Current Well Class: Exploratory Development Oil /^ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 - 11. Well Name and Number: 2N~9'SA~Z~- ~b 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 10973' ND: 5800' 12. Field/Pool(s): ~D y Ku aruk River Field ~ Z P 4a. Location of Well (Governmental Section): Surface: 6' FNL, 529' FEL, Sec. 3, T9N, R7E, UM 7. Properly Designation: ADL 375074, 380053 Tarn Oil Pool Top of Productive Horizon: 2482' FSL, 651' FWL, Sec. 26, T10N, R7E, UM 8. Land Use Permit: ALK 4293, 4601 13. Approximate Spud Date: 2/18/2009 Total Depth: 2094' FNL, 777' FWL, Sec. 26, T10N, R7E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 10554' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 461064 ~ 5912001 ~ Zone- 4 Y- 10. Elevation • ,h,~ ~~~~~ .eU~ZC~~,, ~ ~ (Height above GL): 40' feet 15. Distance to Nearest Well within Pool: 2N-305 , 388' @ 10 82' 18. Deviated wells: Kickoff depth: 3180' ft. Maximum Hole Angle: 66° .deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) a ~ ~ ~ w Downhole:,psig'~~ ~ Surface: psig ~~ 18. Casing Program if i Setting Depth Quantity of Cemen Size icat ons Spec Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) /.! ?~ 7.5" 5.5" 15.5# L-80 Hydril 9962' " ~37d'S' 9962' 5244' 540 sx GasBLOK Class G 4.75" 3.5" 12.6# L-80 IBTM 1211' 9763' 5114' 10973' ~ 5959' 100 sx GasBLOK Class G 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): 10334' Total Depth ND (ft): 56$2' Plugs (measured) 9374' Effective Depth MD (ft): 10200' Effective Depth ND (ft): 5614' Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural 80' 16" 8 cu yds High Early 118' 118' Surface 2990' 7-5/8" 330 sx ASIII Lite, 240 sx G 3025' 2296' Production 9348' S.5" 170 sx CI G & 520 sx CI G 9383' 5210' Production 945' 3.5" included above 10328' 5679' Perforation Depth MD (ft): 9724'-9734' Perforation Depth TVD (ft): 5372'-5377' 20. Attachments: Filing Fee ^ BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis / Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name G. C. Alvord Title GKA Drilling Team Lead Signature ~ ~'j 1 Phon 265-6120 Date !•~ ~~~~ t/~~- h r n All k Commission Use Only Permit to Drill ' ^ Number: ~~ ~~~ API Number: ' /~ ' / 50- ~d3 ~ G•~/3 `>! "Q ~ Permit Approv/a~ l Date: (~/ ~~ See cover letter for other requirements Conditions Of approval : If box is checked, well may not be used to explore for, test, or produce coalbedrm~ethane, gas hydrates, or gas contained in shales: ` Samples req'd: Yes ^ No IYJ Mud log req'd: Yes ^ No [/]~ Other: ~~~v ~S~ C-"C3-i~e.~rE.`-i 1 H2iS measures: Yes [~No ^ Directional svy req'd: Yes [~ No ^ APPROVED BY THE COMMISSION DATE: ,COMMISSIONER '8 t~`~`l ~` rVI111 IU-4U1 RCVIJCU IG/GVVV ~ """""•"""''"""^'~ ~~~~ ~z-~~-wt~ i • i use. i vi .~ Maunder, Thomas E .(DOA) From: Greener, Mike R. [Mike.R.Greener@conocophillips.com] Sent: Wednesday, January 07, 2009 7:10 AM To: Maunder, Thomas E (DOA) Cc: Alvord, Chip Subject: RE: 2N-305A Attachments: Greener Mike.vcf .Response to your questions. l . In step 9 and 10 we are not changing BOP stacks, the ND BC)P and. NU ~30P is not necessary for what we are doing for those steps and should not have been there. ':C`11ese steps allow us to test the blind rams in the BOl'. 2. Test pressure will. be 3500 psi. 3. We need the barrier tl~.at the storm packer gives us to meet one of our barrier rules ~~-l~ile we open. the :BOP to change out the rams. =l•. F-1ere is a picture of the casing drive s~Tstem we pick up to run the 5- l IL" casing. It is currently being used on both Doyon 1 S anal DotiTon 1 ~ 1 to run casing and shortly to drill with casing on Doyon 15. It is the same tool that both Pioneer anal BP are using. 1 /7/2009 Page 2 of 5 And here it is hanging below the top drive. v~i2oo9 N O O _ *, mM _ d~~ yt M»wt "1 G+ dQ W Mike (_rreegier From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, January 06, 2009 3:47 PM To: Greener, Mike R. Cc: Alvord, Chip Subject: RE: 2N-305A Mike, I started to finalize the permit application for this well and noted that I do not have a reply to this message. Could you respond to my questions? Thanks in advance. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, December 23, 2008 12:54 PM To: Greener, Mike R. Cc: Alvord, Chip Subject: RE: 2N-305A Mike, Thanks for the reply. Prior to receiving your message, I had found a message to Guy Schwartz regarding the P&A. There are a number of the steps in your procedure that will be covered by the sundry approval. The PTD approval applies when you dril{ off the OH whipstock. Some further information requests: 1. It appears that you are changing BOP stacks in steps 9 and 10. Could you provide some additional comments as to the stack sizes and # of rams? Although there are stack diagrams on file for the various rigs CPAI employs, it is probably appropriate to list the stack size and ram number that is being employed on a given well 2. I don't find any suggested pressure test value for the BOP. 3. In steps 26 and 27, I believe the wear bushing is pulled prior to running any storm packer. Is it not possible to set a test plug? 4. Please provide some additional information regarding the casing drive system. Regarding comments for 4" DP, will that string just have been racked back? Thanks in advance. I am supposed to be gone right now, but flights got cancelled. Now scheduled to leave on Friday. I will likely finalize the PTD in the first week of January. Best regards for the holidays. Tom Maunder, PE AOGCC From: Greener, Mike R. [mailto:Mike.R.Greener@conocophillips.com] Sent: Tuesday, December 23, 2008 12:45 PM To: Maunder, Thomas E (DOA) Cc: Alvord, Chip Subject: RE: 2N-305A 1. t.~sing .~0 for tl~e gradient for 1VIASP gives MPSP = (5,271. ft TVD}~{.6-.11 psi!`ft} 1 /7/2009 MPS1' --= ?,583 psi 2. Fell reference is 2N-3fl5 3. "I-he m ud plan for this well has been changed and that mud ~v eight is From a mud program dome before a static BHI' ~~~as taken in August. I~he 3,253 psi. is based on a static F3HI' taken an 8/16,~2~08 which showed 3,253 psi at the perforations in the 2N-305 r~~ell. We will drill. the ~~-ell allo~~=i_ng a 1.2 lb trip margin ~~~h_ich would give us a mud weight of l 2.1 ppg to dri (1 the wel l.. ~. Our wells group has submitted the sundry for this well.. if you have other questicros please send. them to me. I am out this week but tip. ill be heel: the next. Mike Greener From: Maunder, Thomas E (DOA) [maitto:tom.maunder@ataska.gov] Sent: Tuesday, December 23, 2008 12:29 PM To: Greener, Mike R. Cc: Alvord, Chip Subject: 2N-305A Mike, am beginning to review the permit for this well and have some questions. 1. On page 3, you indicate that the formation pressure is estimated to be 11.6 ppg however you do not use 0.60 gradient to calculate the MASP. Would you please check the calculation? 2. The well reference in that section is 2A-26. What is the correct well reference? 3. On page 4, the maximum mud weight listed is 11.3 ppg. In view of the estimated BHP EMW, this seems a bit light. 4. Also, have you submitted a sundry for the P&A of 2N-305? !don`t find any entry in my "spreadsheet". Thanks in advance. I may have other questions, however I wanted to get these off to you. Tom Maunder, PE AOGCC 1 /7/2009 Post Office Box 100360 Anchorage, Alaska 99510-0360 Chip Alvord Phone (907) 265-6120 Email: Chip.Alvord@conocophillips.com December 18, 2008 Alaska Oil and Gas Conservation Commission 333 West 7~` Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Dril12N-305A Dear Commissioners, ~~1 ~ '' ConocoPhillips Alaska, Inc hereby applies for a Permit to Drill a sidetrack from the 2N-305 production well. This well would be called the 2N-305A and it also would be a production well. The well will be drilled and completed using Doyon Rig #15. The planned spud date for 2N-305A is February 18, 2009. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information, please contact Mike Greener at 907-263-4820. Sincerely, ~~. Chip Alvord Kuparuk Drilling Team Leader Appl~n for Permit to Drill, Well 2N-305A Saved: 18-Dec-08 Permit It -Tarn Well 2N-305A r.~ !Lt Application for Permit to Drill Document ~'~'~ ~I -~, wsii'ya~u~ Table of Contents 1. Well Name .................................................................................................................................2 Requirements of 20 AAC 25.005 (~ ........................................................................................................................2 2. Location Summary ...................................................................................................................2 Requirements of 20 AAC 25.005(c) (2) ............................................... .....................................................................2 Requirements of 20 AAC 25.050(b) ................................................... .....................................................................2 3. Blowout Prevention Equipment Information ........................................................................3 Requirements of 20 AAC 25.005(c)(3) ............................................... .....................................................................3 4. Drilling Hazards Information .................................................................................................3 Requirements of 20 AAC 25.005 (c)(4) .............................................. .....................................................................3 5. Procedure for Conducting Formation Integrity Tests .........................................................3 Requirements of 20 AAC 25.005 (c)(S) .............................................. .....................................................................3 6. Casing and Cementing Program ............................................................................................4 Requirements of 20 AAC 25.005(c)(6) ............................................... .....................................................................4 7. Diverter System Information ..................................................................................................4 Requirements of 20 AAC 25.OOS(c)(7) ................................................ ....................................................................4 8. Drilling Fluid Program ............................................................................................................4 Requirements of 20 AAC 25.005(c)(8) ................................................ ....................................................................4 9. Abnormally Pressured Formation Information ....................................................................5 Requirements of 20 AAC 25.005 (c)(9) ............................................... .................................................................... S 10. Seismic Analysis .......................................................................................................................5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................................. S 11. Seabed Condition Analysis ......................................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ............................................. .................................................................... S 12. Evidence of Bonding ................................................................................................................5 Requirements of 20 AAC 25.005 (c)(12) ............................................. ....................................................................5 13. Proposed Drilling Program .....................................................................................................5 Requirements of 20 AAC 25.005 (c)(13) ............................................. ....................................................................5 ORIGINAL 2N-305A APD Page 1 of 7 Printed: 18-Dec-08 CJ App~n for Permit to Drill, Well 2N-305A Saved: 18-Dec-08 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .......................................7 Requirements of 20 AAC 25.005 (c)(14) .................................................................................................................7 15. Attachments ..............................................................................................................................7 Attachment 1 Directional Plan ..............................................................................................................................7 Attachment 2 Drilling Hazards Summary .............................................................................................................. 7 Attachment 3 Well Schematic ................................................................................................................................ 7 Attachment 4 Cement Summary ............................................................................................................................. 7 1. Well Name Requirements of 20 AAC 25.005 (~ Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identifred by a unique Warne and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 2N-305A. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for ara item already on file i~~ith the commission and identified in the application: (2) a plat ident~ing the property and the property's owners and showing (A)Ihe coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration: (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 6' FNL, 529' FEL, Sec 3, T09N, R7E, UM NAD 1927 RKB Elevation 159' AMSL Northings: 5,912, 000 ~ Eastings: 461, 063 , Pad Elevation 119' AMSL Location at Top of Productive Interval (Bermuda 2,482' FSL, 651' FWL, Sec 26, T10N, R7E, UM Nad 1927 Measured Depth, RKB: 10,000' Northings: 5,919,788 Eastings: 462,278 Total Vertical Depth, RKB: 5,271' Total Vertical Depth, SS: 5,111' Location at Total De th 2,094' FNL, 777' FWL, Sec 26, T10N, R7E, UM Nad 1927 Measured De th, RKB: 10,973' Northings: S, 920, 465 Eastings: 462, 400 Total Vertical De th, RKB: 5,800' Total Vertical Depth, SS: 5,959' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401J must (1) include a plat., drmvn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed ia~ell; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of Che proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. -305 Page 2 of 7 Printed: 18-Dec-08 ORIGINAL App~n for Permit to Drill, Well 2N-305A Saved: 18-Dec-08 The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file tirith the conmsission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 ~4AC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 15. 4. Drilling Hazards Information Requirements of 20 AAC 2S.OOS (c)(4) An application for a Permit to Drill must be accompanied by each of the follolving items, except for an item already on file with the commission and Identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The closest offset well data for the Bermuda sand shows a max BHP of 3,253 psi at 5,372' TVD. ~$ Equivalent Mud Weight @ TD = 3,253 / (5,372*.052) = 11.6 ppg ~'~'',~~~~` l~ ~~~ The maximum potential surface pressure (MPSP) while drilling e~~alculated using the predicted 3,253 psi reservoir pressure, a 0.11 psi/ft gas gradient, and an Bermuda sang TAD of 5,271'. MPSP = (5,271 ftTVD)*(0.4 - 0.11 psi/ft) 1,7 psi ~, ~, ~ EC'_ rC. M~~ ~ , (B) data on potential gas -ones; ~ ~..-- The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo pressured sbata, lost circulation =ones, and pones that have a propensity for differential sticking; Please see Attachment 2 -Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An application for a Permit to Drill rnust be accompanied by each of the follo~cing items, except for an item ah~eady on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required muter 20 AAC 25.0300; Drill out surface casing shoe and perform LOT test or FIT in accordance with the Kuparuk LOT /FIT procedure that ConocoPhillips Alaska has on file with the Commission. ORIGINAL 2N-305A APD Page 3 of 7 Printed: 18-Dec-08 Ap~n for Permit to Drill, Well 2N-305A Saved: 18-Dec-08 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on fide with the commission and identzfied in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of arty slotted diner, pre perforated liner, or screen to be installed, Casio and Cementin Pro ram Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (Ibfft) Grade Conn. ft ft (ft) Cement Pro ram " Hydril Cement Top planned @ 6,500' MD / 5-1/2 7-1/2 15.5 L-80 563 9962' 6,500' 9,962' / 5,244' 3,743' TVD. Cemented w/ 540 sx GasBLOK Class "G" Cement Top planned @ 9,613' MD / 3-1/2 4-3/4 12.6 L-80 IBTM 1,211' 9,763' / 5,114' 10,973' / 5,959' 5,030' TVD. Cemented w/ 100 sx GasBLOK w/ Class "G" If drilling in the 5-1/2" casing is sucessful (see proposed drilling program), then the following Casing and Cementing program will be followed. Casio and Cementin Pro ram Hole Top Btm Csg/Tbg Size Weight Length MDlTVD MD/TVD OD in) (in (Ib/ft Grade Conn. ft ft) (ft) Cement Pro ram " Hydril Cement Top planned @ 6,500' MD / 5-1/2 7-1/2 15.5 L-80 563 10,973' 6,500' 10,973' / 5,962' 3,743' TVD. Cemented w/ 690 sx GasBLOK Class "G" 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on Erie with tlae commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this reguirenaent is waived by the commission tauder 20 AAC 25.035(h) (2J; Please reference diverter schematic on file for Doyon 15. (Not necessary for this well) 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c) (8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application.• (8) a drilling~duid program, including a diagram and descriptia2 of the drilling~luid system, as required by ZO AAC 2.1.033; Drilling will be done using mud systems having the following properties: Intermediate (Cs Drl O tion) 3,200' - 9,900' 9,900' -10,973' Density (pp 9.6 - 11.3 ~ 9.6 - 11.3 Yield Point (cP) 18 - 24 18 - 24 Plastic Viscosi (lb/100 s~ 14 - 29 14 - 29 H 9-10 9-10 API filtrate <6 <6 MBT <18 <18 Solids (%) <6 <6 Production (To Set Bermuda) 9,900' -10,973' Densi (pp~ 9.6 - Yield Point (eP) 16 - 22 pH 9.5 - 10 API filtrate 4 - 6 Solids (%) 6 - 7 ORIGINAL ~.. G~ i~K..~ -305 Page 4 of 7 Printed: 18-Dec-08 App~n for Permit to Drill, Well 2N-305A Saved: 18-Dec-08 Diagram of Doyon 15 Mud System is on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. , 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor an item ab~eady on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths ofpredicted abnormally geo pressured strata as required by 20 AAC 25.033(fl; N/A -Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission arad ident~ed in the application.• (10J for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A -Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identfed in the application: (11) for a well drilled from an offshore platform, mobile bottom founded sbzrcture, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); N/A -Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item abeady on file with the conmiission and identified in thz application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met,• Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Doyon 15 on 2N-305 wellhead. Notify AOGCC prior to working on well. 2. Check tubing and IA for pressure. Ensure well is dead. RU circulating lines and test. 3. Pull BPV. Attempt to circulate well with brine through tubing cut placed by the Wells group. - Set BPV. Mark orientation of tree. ND tree. Inspect tubing hanger threads. 4. MU blanking plug in tubing hanger lift threads and NU BOP. 5. Test BOP, manifold, valves, rams, and annular. 6. Pull blanking plug and BPV. 7. Pu113-1/2" tubing and hanger. POOH laying down tubing to the first GLM at 2,715' MD. 8. At the first GLM, MU a storm packer to the tubing. RIH and set storm packer at +/- 100' MD. 9. Pressure test storm packer to 3,500 psi ND 1 NU P. Install test plug in tubing head. Close blind rams. Pressure test below blind rams. roc ~,~-~~ L.~.. •~c~~-~ Q E r~ ~~ ~\ yy J~r/~ ~~~~ /~ 2 - 5A APD o ~ ~ ~ ~ ~ ~ L ~~ ;~ Printed:: 18-Dec 08 App~n for Permit to Drill, WeII 2N-305A .Saved: 18-Dec-08 11. Pull test plug. Release storm packer and POOH laying down storm packer and the remaining 3-1/2" tubing. 12. RU wireline and set a CIBP in the 5-1/2" casing at +/- 3,300'. - Place cement cap on top of the CIBP. 13. POOH and PU 5-1/2" jet cutter. 14. RIH and cut 5-1/2" casing at +/-3,200' MD. 15. POOH with 5-1/2" casing and lay down same. 16. PU openhole whipstock with mills and RIH to the top of the casing stub. ~-~~ 17. TIH to top of 5-1/2" casing stub. 18. When just above the CIBP, displace the well to the intermediate hole drilling mud. 19. Survey the whipstock face with MWD and orient the whipstock to the hieh side. 20. Start sidetracking the well to the planned rat hole length of +/-60'. 21. Perform FIT/LOT to establish an EMW. (The original LOT EMW for the surface casing shoe was 14.7 EMW) 22. POOH with milUsidetrack assembly. 23. PU 6-3/4" bit with Rhino Reamer, Rotary steerable system, MWD/LWD and RIH. 24. Drill to 9,900' MD / 5,201' TVD and condition mud. ~~~ ~~~" 25. POOH laying down the drillpipe and BHA. 26. Run and set storm packer in 7-5/8" casing. 27. Pull wear bushing. Install rams for 5-1/2" casing and test BOP. 28. PU Tesco Casing Drive System, PU 6-3/4" EZCase bit and run casing. 29. After reaching bottom, circulate bottoms up and proceed to drill to the conventional casing top set point at +/- 9,962' MD / 5,244' TVD. 30. Perform a LOT test and, based on the results, proceed forward with one of the next two options. - Option #1 (LOT is less than 12.5 pp~) 1) Batch mix cement. Test cement lines and pump cement job as per the attached Schlumberger program (Intermediate set at 9,962'). 2) Lay down 4" drillstring and PU 2-7/8" drillstring. 3) Drill out float and EZcase bit and 20' of new formation. 4) Perform the LOT as per the CPAI FIT LOT Procedure and AOGCC requirements. 5) Directionally drill the 4-3/4" hole to 10,973' MD / 5,959' TVD according to the directional plan. 6) At TD, condition the well bore for the production liner and POOH. 7) Run 3-1/2" liner to TD with 200' overlap across 5-1/2" shoe. 8) Cement liner according to liner cement procedure. 9) Run 3-1/2" completion with GLM spaced according to design. 10) Backout landing joint. Install BPV. ND stack. 11) NU tree. Pull BPV. Install test plug. Test tree and packoff. Pull test plug. 12) Freeze protect well by pumping diesel down annulus taking returns from tubing. Shut down pumps. -305A A Page 6 of 7 ('1 ~ ~ ~ A i A ~ Printed: 18-Dec-OS • Ap~n for Permit to Drill, Well 2N-305A Saved: 18-Dec-08 13) Shut in well. Monitor and record SICP and SITP. Set BPV. RDMO. Turn well over to Production via Handover Form. - Option #2 (LOT is greater than 12.5 ppg) 1) Proceed to drill to 10,973' MD / 5,959' TVD with the 5-1/2" casing. 2) Upon reaching TD @ 10,973' MD / 5,959' TVD, circulate bottoms up. 3) Batch mix cement. Test cement lines and pump cement job as per the attached Schlumberger program (Intermediate set at 10,973'). Cement volume is based 50% excess and on at least 1,000' of annular fill above top of shoe. Have the casing near bottom before cement leaves the shoe. 4) Lay down 4" drillstring. 5) Run gyro survey and cased hole GR/Neutron Density. 6) Run 3-1/2" completion with GLM spaced according to design. 7) Back out landing joint. Install BPV. ND stack. 8) NIT tree. Pull BPV. Install test plug. Test tree and packoff. Pull test plug. 9) Freeze protect well by pumping diesel down annulus taking returns from tubing. 10) Shut in well. Monitor and record SICP and SITP. Set BPV. RDMO. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, exceptfor an item already onftie with the commission and identified in the application: (1 ~~ a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator interuls io request authorisation under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska does intend to request authorization for the use of this well for annular disposal operations at a later date provided the well meets the regulatory requirements. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summaries 2N-305A AP Page 7 of 7 n ~ /1 ~ * ~ A t Printed: 18-Dec-08 • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2N Pad 2N-305 Plan: 2N-305A Plan: 2N-305a (wp01) Standard Proposal Report 24 September, 2008 HALLiBIJRTQN Sp®rry Drilling Services ORIGINAL REFERENCE INFORMATION Project: Kuparuk River Unit Site: Kuparuk 2N Pad Co-ordinate (N/E) Reference: Well 2N-305, True North Well: 2N-305 Vertical (TVD) Reference: 2N-305A D15 @ 159.30ft (D15 (40+119.3)) Wellbore: Plan: 2N-305A Section (VS) Reference: Slot - (O.OON, O.OOE) Plan: 2N-305a W 01 p ~ Measured Depth Reference: 2N-305A D15 @ 159.30ft (D15 (40+118.3)) l l i M h d Mi i C at on et o : n mum urvature Ca cu CASING DETAILS FORMATION TOP DETAILS NDPath MDPath Formation ND MD Name SIZe 2484.30 3431.50 C80 (K10) 2300.75 3030.32 7 5/8" 7-5/8 2544.30 3577.74 Camp Sand 521426 9919.10 51/2" 5-1/2 3829.30 6709.56 c50 5959.30 10973.40 31/2" 3-1/2 52aa.3o 99sz.za T3 5389.30 10167.30 Base Reservoir KOP: 1700 FSL, 288 FEL -SEC 34, T10N, R07E 0 m U ~ 3600 ev ~ 4200 4800 5400 6000 6600 7200 SECTION DETAILS Sec MD Inc Azi ND +N/-S +E/-W DLeg TFace VSec Target 1 3180.00 61.06 6.12 2373.64 1706.34 239.30 0.00 0.00 1706.34 2 3280.00 63.20 8.50 2420.39 1794.00 250.56 3.00 45.00 1794.00 3 3366.04 65.78 8.71 2457.44 1870.78 262.18 3.00 4.24 1870.78 4 9442.18 65.78 8.71 4950.50 7348.07 1100.81 0.00 0.00 7348.07 5 9962.24 45.00 10.00 5244.30 7768.18 1169.39 4.00 177.42 7768.18 2N-305a T3 (wp01) fi 10973.40 45.00 10.00 5959.30 8472.32 1293.55 0.00 0.00 8472.32 SEC 26, T10N, R07E ~ormation @ 2482 FSL, 651 FWL -SEC 26, T10N, R07E BHL: 2094 FNL, 777 FWL -SEC 26, T10N, R07E 112" u 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 13200 13800 14400 Vertical Section at 0.00° (1500 ft/in) O~, / `y~Q ya COf1000~11~~IpS ry~~o Project: Kuparuk River Unit CASING DETAILS Site: Kuparuk 2N Pad Well: 2N-305 TVD MD 2300.7 3030.3 Name 7 5/8" Size 7-5/8 Wellbore: Plan: 2N-305A 521x.2 9919.0 51/2" 5-1/2 Plan: 2N-305a (wp01) 5959.2 10973.3 3 1/2" 3-1/2 WELL DETAILS: 2N-305 Ground Level: 119.3 +N/-S +E/-W Northing Easting Latittude Longitude SI 0.0 0.0 5912000.60 461063.88 70° 10' 13.902 N 150° 18' 48.111 W x571 77 5571 47 3000 2571 2143 171a ]zx6 x57 T M Azimuths to True North Magnetic North: 17.50° 429 Magnetic Field Strength: 57225.2snT 0 Dip Angle: 79.56° Date: 2/25/2008 Model: BGGM2007 -429 SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 3180.0 61.06 6.12 2373.6 1706.3 239.3 0.00 0.00 1706.3 2 3280.0 63.20 8.50 2420.4 1794.0 250.6 3.00 45.00 1794.0 3 3366.0 65.78 8.71 2457.4 1870.8 262.2 3.00 4.24 1870.8 4 9442.2 65.78 8.71 4950.5 7348.1 1100.8 0.00 0.00 7348.1 5 9962.2 45.00 10.00 5244.3 7768.2 1169.4 4.00 177.42 7768.2 2N-305a T3 (wp01) 610973.4 45.00 10.00 5959.3 8472.3 1293.5 0.00 0.00 8472.3 3 1/2" - -- -- 2N"305a (wp01) P` , 5 l/2" 2N-305 IO° U° Bf1L: 2094 FNL, 77T FWL -SEC 26, TION, R07E T3 Formation @ 2482' FSL, 651' FWL -SEC 26, T10N, R078 9° 5-l/2" Casing @ 2452' FSL, 646' FWL -SEC 26, TION, R07E x_° _ 7s/s" -~~ ~~-~-- 6° KOP: 1700' FSL, 288' FEL -SEC 34, TION, R07E 8° 96° -6857 -6429 -6000 -5571 -5143 -4714 -4286 -3857 -3429 -3000 -2571 -2143 -1714 -1286 -857 -429 -0 429 857 1286 1714 2143 2571 3000 3429 3857 4286 47]4 5143 5571 6000 fi429 fiR57 72xfi 7714 5143 West(-)/East(+) (1500 fUin) ~' ConacoPhillips Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2N Pad W e I I: 2N-305 Wellbore: PIan:2N-305A Design: 2N-305a (wp01) ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: We112N-305 TVD Reference: 2N-305A D15 @ 159.3ft (D15 (40+119.3)) MD Reference: 2N-305A D15 @ 159.3ft (D15 (40+119.3)) . North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2N Pad Site Position: From: Map Position Uncertainty: 0.0 ft Wel I 2N-305 Well Position +N/S 0.0 ft +EI-W 0.0 ft Position Uncertainty 0.0 ft Wellbore PIan:2N-305A Magnetics Model Name BGGM2007 Design 2N-305a (wp01) Audit Notes: Northing: 5,911,970.20ft Latitude: 70° 10' 13.596 N Fasting: 460,932.24ft Longitude: 150° 18' 51.920 W Slot Radius: 0" Grid Convergence: -0.30 ° Northing: 5,912,000.60ft / Latitude: 70° 10' 13.902 N Fasting: 461,063.88 ft Longitude: 150° 18' 48.111 W Wellhead Elevation: ft Ground Level: 119.3ft ' Sample Date Declination Dip Angle Field Strength 2/25/2008 17.50 79.56 57,225 Version: Phase: PLAN Tie On Depth: 3,180.0 Vertical Section: Depth From (TVD) +N/S +El-W Direction (ft) (ft) (ft) (°) 40.0 0.0 0.0 0.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Incli nation Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°) (') (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 3,180.0 61.06 6.12 2,373.6 2,214.3 1,706.3 239.3 0.00 0.00 0.00 0.00 3,280.0 63.20 8.50 2,420.4 2,261.1 1,794.0 250.6 3.00 2.14 2.38 45.00 3,366.0 65.78 8.71 2,457.4 2298.1 1,870.8 262.2 3.00 2.99 0.24 4.24 9,442.2 65.78 8.71 4,950.5 4,791.2 7,348.1 1,100.8 0.00 0.00 0.00 0.00 9,962.2 45.00 10.00 5,244.3 5,085.0 7,768.2 1,169.4 4.00 -3.99 0.25 177.42 10,973.4 45.00 10.00 5,959.3 5,800.0 8,472.3 1,293.5 0.00 0.00 0.00 0.00 9/24/2008 1:52:O1PM Page 2 COMPASS 2003.16 Build 42F ~~~~~~ • s ConocoPhillips ~~~ Standard Proposal Report ~:~. Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 2N-305 Company: ConocoPhillips (Alaska) Inc. -Kup2 ND Reference: 2N-305A D15 @ 159.3ft (D15 (40+119.3)) Project: Kuparuk River Unit MD Refe rence: 2N-305A D15 @ 159.3ft (D15 (40+119.3)) Site: Kuparuk 2N Pad North Reference: True Well: 2N-305 Survey Calculation Method: Minimum Curvature Wellbore: PIan:2N-305A Design: 2N-305a (wp01 ) Planned Survey Measured Vertical Map Map Depth In clination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (° ) (ft) ft (ft} (ft) (ft) (ft) 2,214.34 3,180.0 61.06 6.12 2,373.6 2,214.3 1,706.3 239.3 5,913,705.52 461,311.94 0.63 1,706.34 KOP: 1700' FSL, 288' FEL -SE C 34, T10N, R07E 3,200.0 61.48 6.60 2,383.2 2,223.9 1,723.8 241.2 5,913,722.93 461,313.97 3.00 1,723.76 3,280.0 63.20 8.50 2,420.4 2,261.1 1,794.0 250.6 5,913,793.12 461,323.65 3.00 1,794.00 3,300.0 63.80 8.55 2,429.3 2,270.0 1,811.7 253.2 5,913,810.79 461,326.39 3.00 1,811.70 3,366.0 65.78 8.71 2,457.4 2,298.1 1,870.8 262.2 5,913,869.82 461,335.65 3.00 1,870.78 3,400.0 65.78 8.71 2,471.4 2,312.1 1,901.4 .266.9 5,913,900.40 461,340.50 0.00 1,901.38 3,431.5 65.78 8.71 2,484.3 2,325.0 1,929.8 271.2 5,913,928.78 461,344.99 0.00 1,929.79 C80 (K10) 3,500.0 65.78 8.71 2,512.4 2,353.1 1,991.5 280.7 5,913,990.46 461,354.76 0.00 1,991.53 3,577.7 65.78 8.71 2,544.3 2,385.0 2,061.6 291.4 5,914,060.48 461,365.85 0.00 2,061.61 Camp Sand 3,600.0 65.78 8.71 2,553.4 2,394.1 2,081.7 294.5 5,914,080.52 461,369.02 0.00 2,081.67 3,700.0 65.78 8.71 2,594.5 2,435.2 2,171.8 308.3 5,914,170.59 461,383.29 0.00 2,171.81 3,800.0 65.78 8.71 2,635.5 2,476.2 2,262.0 322.1 5,914,260.65 461,397.55 0.00 2,261.96 3,900.0 65.78 8.71 2,676.5 2,517.2 2,352.1 335.9 5,914,350.71 461,411.82 0.00 2,352.10 4,000.0 65.78 8.71 2,717.6 2,558.3 2,442.2 349.7 5,914,440.78 461,426.08 0.00 2,442.25 4,100.0 65.78 8.71 2,758.6 2,599.3 2,532.4 363.5 5,914,530.84 461,440.35 0.00 2,532.39 4,200.0 65.78 8.71 2,799.6 2,640.3 2,622.5 377.3 5,914,620.90 461,454.61 0.00 2,622.54 4,300.0 65.78 8.71 2,840.6 2,681.3 2,712.7 391.1 5,914,710.97 461,468.88 0.00 2,712.68 4,400.0 65.78 8.71 2,881.7 2,722.4 2,802.8 404.9 5,914,801.03 461,483.14 0.00 2,802.82 4,500.0 65.78 8.71 2,922.7 2,763.4 2,893.0 418.7 5,914,891.09 461,497.40 0.00 2,892.97 4,600.0 65.78 8.71 2,963.7 2,804.4 2,983.1 432.5 5,914,981.15 461,511.67 0.00 2,983.11 4,700.0 65.78 8.71 3,004.8 2,845.5 3,073.3 446.3 5,915,071.22 461,525.93 0.00 3,073.26 4,800.0 65.78 8.71 3,045.8 2,886.5 3,163.4 460.1 5,915,161.28 461,540.20 0.00 3,163.40 4,900.0 65.78 8.71 3,086.8 2,927.5 3,253.5 473.9 5,915,251.34 461,554.46 0.00 3,253.55 5,000.0 65.78 8.71 3,127.9 2,968.6 3,343.7 487.7 5,915,341.41 461,568.73 0.00 3,343.69 5,100.0 65.78 8.71 3,168.9 3,009.6 3,433.8 501.5 5,915,431.47 461,582.99 0.00 3,433.83 5,200.0 65.78 8.71 3,209.9 3,050.6 3,524.0 515.3 5,915,521.53 461,597.25 0.00 3,523.98 5,300.0 65.78 8.71 3,250.9 3,091.6 3,614.1 529.1 5,915,611.60 461,611.52 0.00 3,614.12 5,400.0 65.78 8.71 3,292.0 3,132.7 3,704.3 542.9 5,915,701.66 461,625.78 0.00 3,704.27 5,500.0 65.78 8.71 3,333.0 3,173.7 3,794.4 556.7 5,915,791.72 461,640.05 0.00 3,794.41 5,600.0 65.78 8.71 3,374.0 3,214.7 3,884.6 570.5 5,915,881.79 461,654.31 0.00 3,884.55 5,700.0 65.78 8.71 3,415.1 3,255.8 3,974.7 584.3 5,915,971.85 461,668.58 0.00 3,974.70 5,800.0 65.78 8.71 3,456.1 3,296.8 4,064.8 598.1 5,916,061.91 461,682.84 0.00 4,064.84 5,900.0 65.78 8.71 3,497.1 3,337.8 4,155.0 611.9 5,916,151.98 461,697.10 0.00 4,154.99 6,000.0 65.78 8.71 3,538.2 3,378.9 4,245.1 625.7 5,916,242.04 461,711.37 0.00 4,245.13 6,100.0 65.78 8.71 3,579.2 3,419.9 4,335.3 639.5 5,916,332.10 461,725.63 0.00 4,335.28 6,200.0 65.78 8.71 3,620.2 3,460.9 4,425.4 653.3 5,916,422.17 461,739.90 0.00 4,425.42 6,300.0 65.78 8.71 3,661.2 3,501.9 4,515.6 667.1 5,916,512.23 461,754.16 0.00 4,515.56 6,400.0 65.78 8.71 3,702.3 3,543.0 4,605.7 680.9 5,916,602.29 461,768.43 0.00 4,605.71 6,500.0 65.78 8.71 3,743.3 3,584.0 4,695.9 694.7 5,916,692.35 461,782.69 0.00 4,695.85 6,600.0 65.78 8.71 3,784.3 3,625.0 4,786.0 708.5 5,916,782.42 461,796.95 0.00 4,786.00 6,700.0 65.78 8.71 3,825.4 3,666.1 4,876.1 722.3 5,916,872.48 461,811.22 0.00 4,876.14 9/24/2008 1:52:01PM Page 3 COMPASS 2003.168ui1d 42F ~1 GIl~aL ~~ Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2N Pad Wel I: 2N-305 Wellbore: PIan:2N-305A Design: 2N-305a (wp01) Planned Survey Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Measured Vertical Depth Inclination Azimuth Depth TVDss +N/S (ft) (°) ( °) (ft) ft (ft) 6,709.6 65.78 8.71 3,829.3 3,670.0 4,884.8 C50 6,800.0 65.78 8.71 3,866.4 3,707.1 4,966.3 6,900.0 65.78 8.71 3,907.4 3,748.1 5,056.4 7,000.0 65.78 8.71 3,948.5 3,789.2 5,146.6 7,100.0 65.78 8.71 3,989.5 3,830.2 5,236.7 7,200.0 65.78 8.71 4,030.5 3,871.2 5,326.9 7,300.0 65.78 8.71 4,071.6 3,912.3 5,417.0 7,400.0 65.78 8.71 4,112.6 3,953.3 5,507.1 7,500.0 65.78 8.71 4,153.6 3,994.3 5,597.3 7,600.0 65.78 8.71 4,194.6 4,035.3 5,687.4 7,700.0 65.78 8.71 4,235.7 4,076.4 5,777.6 7,800.0 65.78 8.71 4,276.7 4,117.4 5,867.7 7,900.0 65.78 8.71 4,317.7 4,158.4 5,957.9 8,000.0 65.78 8.71 4,358.8 4,199.5 6,048.0 8,100.0 65.78 8.71 4,399.8 4,240.5 6,138.2 8,200.0 65.78 8.71 4,440.8 4,281.5 6,228.3 8,300.0 65.78 8.71 4,481.9 4,322.6 6,318.4 8,400.0 65.78 8.71 4,522.9 4,363.6 6,408.6 8,500.0 65.78 8.71 4,563.9 4,404.6 6,498.7 8,600.0 65.78 8.71 4,604.9 4,445.6 6,588.9 8,700.0 65.78 8.71 4,646.0 4,486.7 6,679.0 8,800.0 65.78 8.71 4,687.0 4,527.7 6,769.2 8,900.0 65.78 8.71 4,728.0 4,568.7 6,859.3 9,000.0 65.78 8.71 4,769.1 4,609.8 6,949.5 9,100.0 65.78 8.71 4,810.1 4,650.8 7,039.6 9,200.0 65.78 8.71 4,851.1 4,691.8 7,129.7 9,300.0 65.78 8.71 4,892.2 4,732.9 7,219.9 9,400.0 65.78 8.71 4,933.2 4,773.9 7,310.0 9,442.2 65.78 8.71 4,950.5 4,791.2 7,348.1 9,500.0 63.47 8.82 4,975.3 4,816.0 7,399.7 9,600.0 59.47 9.03 5,023.0 4,863.7 7,486.5 9,700.0 55.48 9.27 5,076.8 4,917.5 7,569.7 9,800.0 51.48 9.52 5,136.3 4,977.0 7,649.0 9,900.0 47.49 9.80 5,201.2 5,041.9 7,723.9 9,919.1 46.72 9.86 5,214.3 5,055.0 7,737.7 5-1/2" Casing @ 2452' FSL, 646' FWL -SEC 26, T10N, ROlE - 5 1/2" 9,962.2 45.00 10.00 5,244.3 5,085.0 7,768.2 T3 - 2N -3115a T3 (wp01) 9,962.3 45.00 10.00 5,244.4 5,085.1 7,768.3 T3 Formation @ 2482' FSL, 651' FWL -SEC 26, T10N, R07E 10,000.0 45.00 10.00 . 5,271.0 5,111.7 7,794.5 10,100.0 45.00 10.00 5,341.7 5,182.4 7,864.1 10,167.3 45.00 10.00 5,389.3 5,230.0 7,911.0 Base R eservoir +E/-W (ft) 723.7 ConocoPhillips Standard Proposal Report Well 2N-305 2N-305A D15 @ 159.3ft (D15 (40+119.3)) 2N-305A D15 @ 159.3ft (D15 (40+119.3)) True Minimum Curvature Map Northing (ft) 5,916,881.11 Map Fasting DLS (ft) 3,670.00 461,812.59 0.00 Vert Section 4.884.77 736.1 5,916,962.54 461,825.48 0.00 4,966.28 749.9 5,917,052.61 461,839.75 0.00 5,056.43 763.7 5,917,142.67 461,854.01 0.00 5,146.57 777.5 5,917,232.73 461,868.28 0.00 5,236.72 791.3 5,917,322.80 461,882.54 0.00 5,326.86 805.1 5,917,412.86 461,896.81 0.00 5,417.01 818.9 5,917,502.92 461,911.07 0.00 5,507.15 832.8 5,917,592.99 461,925.33 0.00 5,597.29 846.6 5,917,683.05 461,939.60 0.00 5,687.44 860.4 5,917,773.11 461,953.86 0.00 5,777.58 874.2 5,917,863.18 461,968.13 0.00 5,867.73 888.0 5,917,953.24 461,982.39 0.00 5,957.87 901.8 5,918,043.30 461,996.66 0.00 6,048.02 915.6 5,918,133.36 462,010.92 0.00 6,138.16 929.4 5,918,223.43 462,025.18 0.00 6,228.30 943.2 5,918,313.49 462,039.45 0.00 6,318.45 957.0 5,918,403.55 462,053.71 0.00 6,408.59 970.8 5,918,493.62 462,067.98 0.00 6,498.74 984.6 5,918,583.68 462,082.24 0.00 6,588.88 998.4 5,918,673.74 462,096.51 0.00 6,679.02 1,012.2 5,918,763.81 462,110.77 0.00 6,769.17 1,026.0 5,918,853.87 462,125.03 0.00 6,859.31 1,039.8 5,918,943.93 462,139.30 0.00 6,949.46 1,053.6 5,919,034.00 462,153.56 0.00 7,039.60 1,067.4 5,919,124.06 462,167.83 0.00 7,129.75 1,081.2 5,919,214.12 462,182.09 0.00 7,219.89 1,095.0 5,919,304.19 462,196.36 0.00 7,310.03 1,100.8 5,919,342.19 462,202.37 0.00 7,348.07 1,108.8 5,919,393.75 462,210.60 4.00 7,399.68 1,122.4 5,919,480.45 462,224.67 4.00 7,486.46 1,135.8 5,919,563.59 462,238.50 4.00 7,569.68 1,148.9 5,919,642.79 462,252.01 4.00 7,648.95 1,161.7 5,919,717.64 462,265.14 4.00 7,723.88 1,164.0 5,919,731.43 462,267.61 4.00 7,737.68 1,169.4 5,919,761.90 462,273.10 4.00 7,768.18 1,169.4 5,919,761.97 462,273.12 0.00 7,768.25 1,174.0 5,919,788.15 462,277.87 0.00 7,794.46 1,186.3 5,919,857.71 462,290.51 0.00 7,864.09 1,194.6 5,919,904.55 462,299.01 0.00 7,910.98 9/24/2008 1:52:01PM Page 4 COMPASS 2003.16 Build 42F ORIGINAL ConocoPhillips Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 2N-305 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: 2N-305A D15 @ 159.3ft (D15 (40+119.3)) Project: Kuparuk River Unit MD R eference: 2N-305A D15 @ 159.3ft (D15 (40+119.3)) Site: Kuparuk 2N Pad North Reference: True Well: 2N-305 Survey Calculatio n Method: Minimum Curvature Wellbore: PIan:2N-305A Design: 2N-305a (wp01) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E!-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 5,253.11 10,200.0 45.00 10.00 5,412.4 5,253.1 7,933.7 1,198.6 5,919,927.28 462,303.14 0.00 7,933.73 10,300.0 45.00 10.00 5,483.1 5,323.8 8,003.4 1,210.9 5,919,996.84 462,315.78 0.00 8,003.37 10,400.0 45.00 10.00 5,553.8 5,394.5 8,073.0 1,223.1 5,920,066.41 462,328.41 0.00 8,073.00 10,500.0 45.00 10.00 5,624.5 5,465.2 8,142.6 1,235.4 5,920,135.98 462,341.05 0.00 8,142.64 10,600.0 45.00 10.00 5,695.2 5,535.9 8,212.3 1,247.7 5,920,205.54 462,353.68 0.00 8,212.28 10,700.0 45.00 10.00 5,766.0 5,606.7 8,281.9 1,260.0 5,920,275.11 462,366.32 0.00 8,281.91 10,800.0 45.00 10.00 5,836.7 5,677.4 8,351.5 1,272.3 5,920,344.67 462,378.96 0.00 8,351.55 10,900.0 45.00 10.00 5,907.4 5,748.1 8,421.2 1,284.5 5,920,414.24 462,391.59 0.00 8,421.18 10,973.4 ~ 45.00 10.00 5,959.3 5,800.0 8,472.3 1,293.5 5,920,465.30 462,400.87 0.00 8,472.30 BHL: 2094' FNL, 77T FWL -SEC 26, T10N, R07E - 3-112" Targets Target Name - hiUmiss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (° ) (°) (ft) (ft) (ft) (ft) (ft) 2N-305a T3 (wp01) 0.00 0.00 5,244.3 7,768.2 1,169.4 5,919,761.90 462,273.10 -plan hits target - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (~~) (~~) 3,030.3 2,300.7 7 5/8" 7-5/8 9-7/8 9,919.1 5,214.3 51/2" 5-1/2 6-3/4 10,973.4 5,959.3 31/2" 3-1/2 4-3/4 Formations Measured Vertical Vertica( Dip Depth Depth Depth SS pip Direction (ft) (ft) ft Name Lithology (°) (°) 10,167.3 5,389.3 Base Reservoir 0.00 3,577.7 2,544.3 Camp Sand 0.00 3,431.5 2,484.3 C80 (K10) 0.00 9,962.2 5,244.3 T3 0.00 6,709.6 3,829.3 C50 0.00 Plan Annotations Measured Vertical Local C oordinates Depth Depth +N/S +E/-W (ft) (ft) (ft} (ft) Comment 3,180.0 2,373.6 1,706.3 239.3 KOP: 1700' FSL, 288' FEL -SEC 34, T10N, R07E 9,919.1 5,214.3 7,737.7 1,164.1 5-1/2" Casi ng @ 2452' FSL, 646' FWL -SEC 26, T10N, R07E 9,962.3 5,244.4 7,768.3 1,169.4 T3 Formation @ 2482' FSL, 651' FWL -SEC 26, T10N, R07E 10,973.4 5,959.3 8,472.3 1,293.5 BHL: 2094' FNL, 777' FWL -SEC 26, T10N, R07E 9/24/2008 1:52:01PM Page 5 COMPASS 2003.16 Build 42F ORIGINAL ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2N Pad 2N-305 Plan: 2N-305A 2N-305a (wp01) ~ . ."~' r~rr Drll~n ,'rar~r~r~ .~ ~ _.. Clearance Summary ~ Anticollision Report 1~ 24 September, 2008 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2N Pad - 2N-305 -Plan: 2N-305A - 2N-305a (wp01) Well Coordinates: 5,911,749.55 N, 1,601,097.97E (70° 10' 12.76" N, 150° 18' 59.23" W) Datum Height: 2N-305A D15 @ 159.30ft (D15 (40+119.3)) Scan Range: 3,180.00 to 10,973.52 ft. Measured Depth. Scan Radius is 1,293.35 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIIBURTON Sp®rry Drllling Services SURVEY PROGRAM ConocoPhillips (Alaska) Inc. -Kup2 Date: 2005-02-25700:00:00 Validated: Yes Version: Calculation Method: Minimum Curvature MD, interval: 25.00 Error System: ISCWSA 3180.00 To 10973.52 Depth From Depth To Survey/Plan Tool Scan Method: Trav. Cylinder North Centre Distance: 1293.35 211.18 3180.00 2N-3051tFR(2N-305) MWD+IFR-AK-CAZ-SC Error Surface: Elliptical Conic Plan: 2N-305a (wp01) (2N-305/Plan: 2N-305A 3180.00 10973.52 2N-305a (wpOQ (Plan: 2N-305A) MWD+IFR-AK-CAZ-SC Warning Method: Rules Based GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference /~ ~ -, ~ a I- - -' 2N-30 From Colour To MD 0 3000 3000 4000 4000 5000 5000 6000 6000 7000 7000 8000 8000 9000 9000 --- 10000 10000 11000 so 90 Travelling Cylinder Azimuth (TFO+AZI) ~°~ vs Cen[rc to Centre Separation (30 ft/ink 180 NAD 27 ASP Zone 4 : WELL DETAILS: 2N-305 Ground Level: 119.30 +NI-S +EI-W Northing Easting Latittude 0.00 0.00 5911749.55 1601097.97 70°10'12.759 N 150 Slot SECTION DETAILS Sec MD Inc Azi ND +N/-S +E/-W DLeg TFace VSec Target 1 3180.00 61.06 6.12 2373.64 1706.34 239.30 0.00 0.001706.34 2 3280.00 63.20 8.50 2420.39 1794.00 250.56 3.00 45.001794.00 3 3366.05 65.78 8.70 2457.44 1870.78 262.17 3.00 4.111870.78 4 9442.27 65.78 8.70 4950.49 7348.26 1100.25 0.00 0.00 7348.26 5 9962.35 45.00 10.00 5244.30 7768.39 1168.80 4.00 177.41 7768.39 2N-305a T3 (wp01) 6 10973.52 45.00 10.00 5959.30 8472.53 1292.96 0.00 0.00 8472.53 a e ConocoPhillips (Alaska) Inc. -Kup2 HALLIBURTt]N Kuparuk River Unit Anticollision Report for 2N-305 - 2N-305a (wp01) 0 ^~ V J From To Survey/Plan Survey Tool (ft) (ft) 211.18 3,180.00 MWD+IFR-AK-CAZ-SC 3,180.00 10,973.52 2N-305a (wp01) MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles -Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2N Pad - 2N-305 - Plan: 2N-305A - 2N-305a (wp01) Scan Range: 3,180.00 to 10,973.52 ft. Measured Depth. Scan Radius is 1,293.35 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Site Name Comparison Well Name - Wellbore Name -Design 2N-311A - 2N-311A - 2N-311A (wp03) Kuparuk 2N Pad 2N-302 - 2N-302 - 2N-302 2N-303 - 2N-303 - 2N-303 2N-305 - 2N-305 - 2N-305 2N-305 - 2N-305 - 2N-305 2N-307 - 2N-307 - 2N-307 Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Depth Distance Depth Separation Depth Factor Minimum (ft) (ft) (ft) (ft) ft 3,185.62 230.85 3,185.62 172.31 3,275.00 3.944 Clearance Factor Separation Warning Pass -Major Risk 3,196.87 622.11 3,196.87 551.82 3,375.00 8.850 Clearance Factor Pass -Major Risk 3,184.72 592.89 3,184.72 536.29 3,300.00 10.476 Clearance Factor Pass -Major Risk ...-~~ ® ® - 3,196.07 546.82 3,196.07 448.20 3,425.00 5.545 Clearance Factor Pass -Major Risk 2N-308 - 2N-308 - 2N-308 3,184.53 767.90 3,184.53 649.70 3,350.00 6.497 Clearance Factor Pass -Major Risk 2N-309 - 2N-309 - 2N-309 3,188.93 1,155.79 3,188.93 1,051.47 3,675.00 11.079 Clearance Factor Pass -Major Risk 2N-311 - 2N-311 - 2N-311 3,189.19 218.49 3,189.19 166.39 3,275.00 4.194 Clearance Factor Pass -Major Risk 2N-311 - 2N-311A - 2N-311A 3,186.17 230.88 3,186.17 180.98 3,275.00 4.627 Clearance Factor Pass -Major Risk Survev tool program 24 September, 2008 - 15:37 Page 2 of 4 COMPASS ConocoPhillips ~as~ ConocoPhillips Alaska, Inc. ~ Plan: 2N-305a (wp01) 1/4 Mile Pool Scan "~'""' Sperry Drilling Services September 25, 2008 HALLIBURTON drilling and Formation Evaluation Closest in POOL '+.-y/~ ,.~''~.! ~.~ .~,." ~,„.~. Closest A roach: Reference Well: 2N-305a w 01 Plan Offset Well: 2N -305 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. Depth Incl. An le TRUE Azi. ND E + /W - 0° Comments De th Incl. An le TRUE Azi. ND E + /W _ 0° Comments P L Min Distance POOL Min Distance (367.79 ft) in POOL (367.79 ft) in POOL (5085 - 5230 NDss) (5085 - 5230 TVDss) to 2N-305a (wp01) to 2N-305 (5085 - Plan (5085 - 5527.38 - 367.79 ' z" 'i'i 10150 45 10 5218.06 5919642.3 1602330 7899.08 5527.38 NDss) 10082 59.44 0.74 5399.39 5919538.8 1602028 7794.02 TVDss) Closest A roach: Reference Well: 2N-305a w 01 Plan Offset Well: 2N -311 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An le TRUE Azi. ND E + /W - 0° Comments De th Incl. An le TRUE Azi. ND E + /W - 0° Comments POOL Min Distance POOL Min Distance (2171.64 ft) in POOL (2171.64 ft) in POOL (5085 - 5800.38 (5085 - 5800.38 TVDss) to 2N-311 NDss) to 2N-305a - (5085 -5464.28 (wp01) Plan (5085 - 2171.78 '=' ?' 10450 45 10 5430.19 5919851 1602368 8107.99 TVDss) 8644 45.4 10.87 5455.15 5917703.4 1602046 5979.42 5464.28 NDss) Closest A roach: Reference Well: 2N-305a w 01 Plan Offset Well: 2N -311A Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An le TRUE Azi. ND E + /W - 0° Comments Depth Incl. An le TRUE Azi. ND E + /W - 0° Comments m istance POOL Min Distance (2408.14 ft) in POOL (2408.14 ft) in POOL (5085 - 5230 NDss) (5085 - 5230 TVDss) to 2N-305a (wp01) to 2N-311 A (5085 - Plan (5085 - 5556.09 • 2408.26 I'-i,i3%' 10075 45 10 5165.03 5919590.1 1602321 7846.85 5556.09 NDss) 8275 39.81 324.24 5189.4 5917182.4 1602369 5460.14 TVDss) POOL Summary Templatel 9/25/2008 10:04 AM Project: Kuparuk River Unit Site: Kuparuk 2N Pad Well: 2N-305 Wellbore: PIan:2N-305A Plan: 2N-305a (wp01) C~ ~7 __.. 1000 2000 3000 4- 0 0 0 I ....... ........ .. ........ ~000~ 0 iooo zooo 00 ................... ~~; o o° o° o 0 0 2N-311, 2N-311A, 2N-311AV7--,=~ 2N-305a (wp01) 2N-311, 2N-311, 2N-311 V1 , 3 -~' ~ - 2N-305, 2N-305, 2N-305 V6 o o 0 0 ConocoPhillips Proje Sit We Wellbor Pla ct: Kuparuk River Unit e: Kuparuk 2N Pad ll: 2N-305 e: Plan: 2N-305A n: 2N-305a (wp01 j uz" ~ Y , 8229 ?,~''_go5a (wp01j " 5 I/2 10° 2N-305 7886 0° 7543 7200 6857 6514 6171 2,V,?1t 5829 5486 a ~ 515143 ~ iaLJ __9,.800 "~3~~/ 9° .,.~i.4i57 14 ~1 29 3086 2743 2400 2057 1714 8° 7 5/8" - 1371 T M Azimuths to True North 1029 Magnetic North: 22.50° 6° 686 Magnetic Field Strength: 57588.6snT 8~ Dip Angle: 80.65° Date: 2/25/2008 343 Model: BGGM2007 0 ° 0 343 686 1029 1371 1714 2057 2400 2743 3086 3429 3771 4114 4457 4800 5143 5486 5R29 fit71 fi514 fiR57 7200 -0 -4800 1!457 -4114 -3771 -3429 -3086 -2743 -2400 -2057 -1714 -1371 -1029 -686 -343 West(-)/East(+) (1200 fUin) ~"~ COIIOCOP~'11~~Ip5 2N-3O5A Drilling Hazards Summary 6-3/4" x 7-1/2" Hole / 5-1/2" Casing Interval Event Risk Level Miti ation Strate High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Hole swabbing/Tight hole on trips Moderate Circulate hole clean prior to trip, proper hole filling (use of trip sheets), umping out of hole as needed Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheolo ,LCM. Use GKA LC decision tree. 4-3/4" Hole / 3-1/2" Liner Interval Event Risk Level Miti ation Strate Differential Sticking Low Periodic wiper trips. Do not leave pipe static for extended period of time. Lube pills will be ready to be spotted if a stuck ipe incidents occurs. Difficulties getting liner to bottom Moderate Pump out of hole on final trip out prior to running liner to ensure hole is clean. Insufficient or undetermined LOT Low Importance of LOT communicated to all parties, all parties familiar with LOT procedure. Test will be carried out until leak off is observed or to an FIT of 16 ppg MW equivalent High ECD /Tight hole on trips/ Moderate Condition mud & clean hole prior to trips. Monitor ECDs Swabbing with PWD tool while drilling across reservoir interval. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of trip sheets) Lost circulation Moderate Keep hole clean -use PWD to monitor hole cleaning. If losses occur -reduce pump rates and mud rheology, use LCM 2N-305A Hazards.doc ~}, ~ ~ Prepared by Mike Greener tt \ll[ Page 1 of 1 Maunder, Thomas E (DOA) Page 1 of 1 From: Greener, Mike R. [Mike.R.Greener@conocophillips.com] Sent: Thursday, January 08, 2009 11:23 AM To: Maunder, Thomas E (DOA) Subject: RE: 2N-305A Attachments: Greener Mike.vcf; 2N-305A Schematic.jpg; 2N-305A Schematic casing drlg.jpg The drawings had the wrong TOC for the new 5-1 /2" casing strings. I have corrected that mistake and have attached the two drawings in jpeg format to this email. Thanks for catching that mistake. Mike Greener From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, January 07, 2009 5:56 PM To: Greener, Mike R. Subject: 2N-305A Mike, Thanks for the message earlier today. I was looking at the cement calculations and based on the basis you state, it does not appear that sufficient cement is planned to put the TOC at 4300'. I calculate the gauge volume necessary for 5662' of 7.5" x 5.5" annulus at 143 bbls or 685 sx. Would you look into the calculation? Thanks in advance. Tom Maunder, PE AOGCC 1/8/2009 • 2N-305A SIDETRACK ~_x ~..w: Drill in 5-1/2" Casing 7-5/8" 29.7# L-80 @ 3,025' MD / 2,296' TVD Sidetrack KOP off cement plug @ +/- 3,200' MD Whipstock in 5-%z" csg stub @ +/- 3,200' Baker "K-1" CIBP set @ +/- 3,300' MD in 5-''/z" csg Tubing chemical cut @ +/- 6,500' MD Tubing cmt retainer @ +/- 6,550' MD Est. TOC on original 5-1/2" csg. @ 4,300' MD (using 10% wash out) TOL @ 9,383' MD 5-''/z" 15.5# L-80 9,383' MD / 5,210' TVD Bttm of tubing @ i<: ;: <:: ; : ><:::::: ......................: 9,365' MD Perfs @ 9,724' - 9,734' 10,328' MD / 5,679' TVD GL114 Placement ' 3-'iz" x 1" KBMG GLM (inside 7" csg.) ;' 3-%z" x 1"KBG2-9 GL~t (inside 5-1/2" csg.) 3-%z" x 1"KBG2-9 GLM (inside 5-1/2" csg.) 3-%" x 1"KBG2-9 GLM (inside 5-1/2" csg.) 3-'~4" x ]" KBG2-9 GLM (inside 5-1/2" csg.) mar~clrel will hm~e the unruzlus to tubing shear) TOC on 5-''/z" @ +/- 6,500' MD +/- 9,700' Tubing 3-''/z" 9.3#, L-80, IBTM w/ 3.865" O.D. Special Clearance couplings 2.75" "X"Nipple In tubing tail 3-1/2" x 5-1/2" Production Packer @ 9,700' MD / 5,076' TVD Estimated BHP 12.6 PPG 5-1/2" Hydril 563 15.5# set @ 10,973' MD / 5,959' TVD U 2N-305A SIDETRACK 7-5/8" 29.7# L-80 @ 3,025' MD / 2,296' TVD Sidetrack KOP off whipstock @ +/- 3,200' MD Whipstock in 5-%z" csg stub @ +/- 3,200' Baker "K-1" CIBP set @ +/- 3,300' MD in 5-%" csg • GL1Vi Placement ' 3-'/" x 1" KBh9G GLM (inside 7" csg.) ' 3-'/" x 1" KBG2-9 GLM (inside 5-1/2" csg ) ' 3-'/" x 1" KBG2-9 GLM (inside 5-1J2" csg.) ' 3-' ~" x 1 " KBG2-9 GLM (inside 5-1 /2" csg ) ' 3-'iz" x 1" KBG2-9 GLM (inside 5-1/2" csg.) maralrel tvi11 hm~e the annulzrs to tzrbing shear) TOC on 5-%" @ +/- 6,500' MD +/- 9,700' Tubing Est. TOC on original 3-'h" 9.3#, L-80, IBTM w/ Tubing chemical cut 5-1/2" csg. @ 4,300' 3.865" O.D. Special Clearance @ +/- 6,500' MD MD (using 10% wash couplings out) Tubing cmt retainer :: @ +/- 6,550' MD ~: 2.7,'• ..h„Nipple z": TOL @ 9,383' MD 1n tubing tail 5-%z" 15.5# L-80 9,383' MD / 5,210' TVD 3-1/2" x 5-1/2" Bttm of tubing @ Liner Hanger 9,365' MD @ 9,700' MD / 5,076' TVD Perfs @ 5-1/2" H dril 563 15.5# 9,724' - 9,734' y set @ 9,900' MD / 5,214' TVD Estimated BHP 11.3 PPG 3-1/2" Hydril 511 or IBTMOD or SLHT 3-1/2" 9.3# L-80 9.3# liner 10,328' MD / 5,679' TVD set @ 10,973' MD / 5,959' TVD 2N-305 SIDET~i~CK Drill in 5-%" Casing ~.~,~5~. ~q.7~ L-fi[7 iii: 3,Q'?~` h~tU ~ ?,29fi T~'D 1~, Sidetrack kct~ ~ / /.r~. nff"een~ettt ~lu~ l ~. G_ `•~,~=..~....~-~<-µ °--=~..~ Whipstock i~ -''z" G53 slci~ fit; +a'- ~, ~ 4Y()' f3ukar "t:- l ° C}BP sat ~i~~ -.- _*.3fiQ' I~iD in S_'..~~" cs 'Cubing chemical cut Cuhin~ crt~t tetaii~er iii; . - fi,;±;±CM' M l) x.x~x' ~-',~F„ ~ }" i=L~`~~fts%~}_~9 iit~ti~.ls::' ,:s~.} ?l.*:xx' 3 ~" x t" F:};3(i'-~ ~::mL~9 )ir~~i+3a ?-}" i~~.l ~.~xx' ~ ~~.~ ~ i" E4}#fs~-~ t;=E_~4i tinis~c ~-I;'g" c~~;.) ~.xxx" .." ~ i" k~,I3li~-~ tt_~# tir~~ia3a~ 5-If?" ~k~?.j (7"ha. rra~a~€~~€r' ~~ r~, ,~ca,r,a; r)ec~ ~r~~rttlr¢t~~ Pia rr~~trtys* t~6c'zrr.~ pct. TC)C an nri~!inal ~-i- 9,?p[I' Tubing -1r~2=' ~~~. Frii 4,3}?tl' ~ ~ ,;~,• ~.3~+, L-'34. IBTht 4vl rtFiD Rusitt~, l0'?rn wash 3.Sfi5" O.D. Spacial ~Eauranaa out} c_ouplitags \~ \ \ ~~ ~.i5" ~ ' t~ipCala T(lL ~u! 0.353' h^iD 1€~ ~~thtt~~~ tai} '~..~~.~' 44I); ?,210° 141.) t3ttm \11) {il -1,'2~' X ~-E1~'. l~t'ntt!!i'tle?li 1'aCk~r Pads 4it~: :'ii, 9,;(IC)" 1411) ,' 3,~17fi' i \`l) 9,72' - 9,73{' [~stirzi.~tet1 QHP 1 Z.6 PPU lf),.i2:~' t411) ,' S,f~~'t?' 1'VI) 5-I ~"~" l l~'dril 5(,~ 15.5 set (cL~ 1 f~),~}7;t' '4113 ;` i,y5~-' 1'4' l) • ~~~~{~~~ ~T~ET~ta-~.~ ?-5.'~"'9,7~ is-:its iu: • ~UP~~t~l~~t:. iC ~~~ si~ett~ck ~oP ~~t~~~trips,c,4k Whipstuek in ~-`i„ ~:s~: 5tekb Baker "'K¢1" C']Bt' set t{%: +; . i,~()CI' ;11 D IR ~-!'~'• ES° Ll (:t.'k( tytee~nt r,e`~a" t,+:'~ x !" i4F~4`1t€ (iI_~S•t ~ikasr~~e ``•, s`s.l .w ~~ ~:.axx r-'- z t t~.~g~ at~L~~~kr~ite5=~~'"c*~~_t x,e~~' _;.+~TM,~ I"tCf~(€'-'}f~L'+1t#ik~~~~:SNi~"~ti+~_t ~.x~x' ~ 1 ;.. *e I'" ! t#C;?.~ t~LR~ i ika;e j= ~ ~{~ cM~~_l x,xxx° ,_' :_" °~ I'" tti F3t:c~ +) tt_h(1 kk~ie ~x 1;~,~ L,;a~ .f (t~lftl:4' lTft1FE:.tfB`i'J' k~'tif':~3ti'4: f1~fE` ali3.fffFldt.S rt? f~F~F.?t,~ }~it'fk?',l `Cn~' ofi 5-~.`,' fad i ;'- 4,;+(if)' t~1 A} ~~k-1'- ~1,YQC}~ TLS~112~ t~st t~C- ~>it ~}ri~if~al ~.'~:," 9.3~', L•;3C1. IBT{~4 ~c= Tubing c.lten~icnl crft ~ ; 2" cs~. faz, ~i,3(t0' ~~ . 3_RC>~" C}.C}. Spzcia! C'izaran.,e ~cr -f-,`- {~,:~GO' A~1D 1) tusin~ EO'!~~ v.`ach ccruglif~gs t+rfr t Tubirte crnt rct~irrer . , ,~ , ".x~' ~;il,l~l~ ,: :~:~: T("1L ru;:9,_;~i~~" n~D Itr trt,i:~~t~l !),jk3' hi[) i,?l(J' TVD 3-t:`?" x 5-t;?" Btttrr c?i'tikl~irrs r" Liner I lr7na;er c}.;6 j' yt (~t'.;' s;?"7C1[1" h•1D .~' *.()76' TVD tfC'1'tS rfL. y r~~, - 9,7;t-~' 4- I:2" ti}'brit 7(i3 15_Su set (u 9,90f)' M D ,~ ~,? I ~" T V D «<~~ Etin~ated BHP 11.3 i'PC C~:~;~:':;ii~`//»?:~ ;~-L+~'"t1}~(ttl~I1 urlti`I"L~TO!)clrSt.t17' k i0,3?8".4D; ~,F7')' TVD ~,~, ~,,,~ ~ V ~ ~ ~ set (~~ ltl,~?73' A~11) ~,~;'s9''I'~`1) • Rig: Doyon 15 Location: Tarn Client: ConocoPhillips Alaska, Inc. Revision Date: 10/2/2008 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Previous Csg. < 7 5/8", 29.7#casing at 3,030' MD < Top of Tail at 6,500' MD -~~ < 5 1/2", 15.5#casing in 71Y2"OH '.fir ~~~ TD at 10,975' MD ~~ (5,962' TVD) CemCADE Preliminary Job Design 5.5" Lon strin Casin Preliminary Job Design based on limited input data. For estimate purposes only. i Schlumberger Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 4475' MD above the intermediate casing shoe. Maximum dynamic pressure experienced during cement job is expected to be 15.0 ppg. Tail Slurry Minimum thickening time: 250 min. (Pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D600G + 0.1% B155 + 0.2 gps D047 + 0.35% D065 @ 15.8 ppg - 1.17 ft3/sk 0.1418 ft3/ft x 4475' x 1.25 (25% excess) = 793.2 ft3 0.1336 ft3/ft x 80' (Shoe Joint) = 10.7 ft3 793.2 ft3 + 10.7 ft3 = 803.9 ft3 803.9 ft3/ 1.17 ft3/sk = 687.1 sks Round up to 690 sks BHST = 126`F, Estimated BHCT = 100`F. (BHST calculated using a gradient of 2.2`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Cumulative Rate Volume Time Time Stage (bpm) (bbl) (min) (min) Comments Drop Bottom Plug 10.0 10.0 Mud PUSH II 4 40 10.0 20.0 Start Pumping Spacer Tail Slurry 4 144 36.0 56.0 Mix and Pump Tail Slung Drop Top Plug 5.0 61.0 Switch to Rig Pump 5.0 66.0 Displacement 4 199 49.8 115.8 Start Displacement 3 20 6.7 67.7 2 20 10 76 1 20 20 135.8 Slow Rate to Bump Plug MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, T„ < 22. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.5 ppg MudPUSH" II, Pv = 19-22, T„ = 22-29 Centralizers: Recommend 2 per joint across zones of interest for proper cement placement. ORIGINAL • Rig: Doyon 15 Location: Tarn Client: ConocoPhillips Alaska, Inc. Revision Date: 12/10/2008 Prepared by: Domenica Mendoza Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 748-0170 email: dmendoza2@slb.com Previous Csg. < 7 5/8", 29.7# casing at 3,030' MD < Top of Tail at 6,500' MD h < 5 1/2", 15.5# casing in 7 1/2" OH TD at 9,962' MD (5,244' TVD) •.. 5cbl~~nb~erger CemCADE Preliminary Job Design 5.5" Intermediate Casin reliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 3462' MD above the intermediate casing shoe. Maximum dynamic pressure experienced during cement job is expected to be 14.2 ppg. Tail Slurry Minimum thickening time: 220 min. (Pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D600G + 0.1 % B155 + 0.2 gps D047 + 0.35% D065 @ 15.8 ppg - 1.17 ft3/sk 0.1418 ft3/ft x 3462' x 1.25 (25% excess) = 613.6 ft3 0.1336 ft3/ft x 80' (Shoe Joint) = 10.7 ft3 613.6 ft3 + 10.7 ft3 = 624.3 ft3 624.3 ft3/ 1.17 ft3/sk = 533.6 sks Round up to 540 sks BHST = 125°F, Estimated BHCT = 105°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Cumulative Rate Volume Time Time Stage (bpm) (bbl) (min) (min) Comments Drop Bottom Plug 10.0 10.0 MudPUSH II 4 40 10.0 20.0 Start Pumping Spacer Tail Slurry 4 113 28.3 48.3 Mix and Pump Tail Slurry Drop Top Plug 10.0 58.3 Switch to Rig Pump 5.0 63.3 Displacement 5 215 43.0 106.3 Start Displacement 2 20 10.0 116.3 Slow Rate to Bump Plug MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 20, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.0 ppg MUDPUSH II, Pv ~ 25, TY ~ 25 Centralizers: Recommend 3 every 2 joints across zones of interest for proper cement placement and 2 centralizers per joint on the last 2 joints of the shoe. e~isiNt~~ Rig: Nordic 3 Location: Tarn Client: ConocoPhillips Alaska Revision Date: 10/1/2008 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Top of Tail at < 9,613' MD < LinerTop at 9,763' MD Previous Csg. 5 1/2", 15.5#casing at 9,963' MD < 3 1/2", 9.3# casing in 4 3/4" OH TD at 10,975' MD (5,962' TVD) ' Mark of Schlumberger ~ •• . CemCADE Preliminary Job Design 3 1/2" Liner Preliminary Job Design based on limited input data. For estimate purposes only. Schlumberger Volume Calculations and Cement Svstems Volumes are based on 50% excess. Displacement is calculated with a 3.5"- 15.5# drill string. Cement job is designed to seal off liner top by bringing cement 200' above liner top, with 15.8 ppg G cement (cement type as per client's request). Maximum dynamic pressure experienced during cement job is expected to be 15.0 ppg. Tail Slurrv Minimum thickening time: min. (pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D600G + 0.1 % 8155 + 0.2 gps D047 + 0.35% D065 15.8 ppg - 1.17 ft3/sk Liner Cap: 0.0668 ft3/ft x 150' x 1.00 (no excess) = 10 ft3 Liner Lap: 0.0668 ft3/ft x (9963' - 9763') x 1.00 (no excess) = 13.4 ft3 Annular Volume: 0.0562 ft3/ft x (10975' - 9963') x 1.50 (50% excess) = 85.3 ft3 Shoe Volume: 0.0488 ft3/ft x 80' x 1.00 (no excess) = 4.4 ft3 Totals: 10 ft3+13.4ft3+85.3ft3+4.4ft3= 113.1 ft3 113.1 ft3/ 1.17 ft3/sk = 96.7 sks Round up to 100 sks BHST = 126`F, Estimated BHCT = 100`F. (BHST calculated using a gradient of 2.2/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Cumulatnre Rate Volume Time Time Stage (bpm) (bbl) (min) (min) Comments MudPUSH II 4 25 6.3 6.3 Start Pumping Spacer Tail Slurry 4 21 5.3 11.6. Mix and Pump Tail Slurry Drop Wiper Dart 3.0 14.6 Displac®ment 4 59 14.8 29.4 Start Displacement Slow to Bump 2 15 7.5 36.9 MUD REMOVAL Recommended Mud Properties: 11.4 ppg, Pv < 15, TY < 22. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.5 ppg MudPUSH* II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 2 per through zones of interest. e~iciNn~ TRANSMITTAL LETTER CHECKLIST WELL NAME /~~~ 2~/- 3~'S~ PTD# Zo ~ ~ Z©Z' / Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~ '~ /S "''~ POOL:~~~ ~,~ ~~ l Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Companv Name) must contact the Commission to obtain advance approval of such water well testing rogram. Rev: 1 / 11 /2008 1(4'ELL PERMl7 CHECKLIST Field & Pool KUPARUK RIVER, TARN OIL _490165_ __ _ _ Well Name: KUPARUK RIV U TARN 2N-305A -...Program DEV _ ___ ____ Well bore seg ~ _', PTD#:2082020 Company CONOCOPHILLIPS ALASKA INC ___ . _ Initial Class/Type _ DEV! PEND GeoArea 890 - _ _ Unit 11160 __ __ OnlOff Shore On _ Annular Disposal Administration ,1 Pe[mit_fee attached. _ - _ N? - Appr Date SFD 12/22/2008 Engineering Appr Date TEM 1!8!2009 - - _ - 35 Geology '36 Appr Date ',37 ~, SFD 12/22/2008 38 ', 39 Geologic Commissioner: Lease number appropriate. Yes - Surface locaiton in ADL 375074; along section of wellbore passes.through ADL-380054 top pay interval and. TD Unique well. name and number _ Yes _ _ _ _ _ in ALl) 380053._ _ . - _ Well located in a_defined-pool. _ - _ _ _ - - - - Yes _ _ . KUPARUK RIVER,_TARN OIL - 490165, gov_emed by C0 430A. _ _ _ _ Well located proper distance from drilling unitboundary Yes Well will lie withinthe KRU about 9000' from the KRIJ boundary and 3750' from_the CO 430A_area-boundary. Well located proper distance from other wells. Yes Conforms lo_Conservation Order No. 430A Rule 3,_which specifies 10-acre spacing. Sufficient acreage_available in_drilling unit- _ _ _ _ Yes If deviated,.is.we_Ilbore plat_included _ _ - - - _ _ _ _ - Yes _ _ _ _ . Operator only affected party Yes Operatorhas appropriate-bond in force _ - . _ _ _ _ - Yes _ _ _ - - - - - - - - - - - - - - - - - - - Permit can be issued without conservation order - - - _ _ Yes _ . - - - - - - - - - - Permit can be issued without administ[ative_approval _ _ _ Yes _ _ - _ . _ - - - - Can permit be approved before 15-day wait Yes Well located within area and_strata authorized by_ Injection Order # (put 10# in oomments) (For. NA All wells_withi_n 114. mile area. of review identified (For service well only) NA_ _ _ Pre-produced injector: dur_ation_of pre-production less than 3 months. (For service well only) _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ N_onconyen,gos conforms to AS31.05,030(j.1_.A),f.2.A-D) -- __ Conductor stung provided - _ _ - _ _ - NA - . _ _- - Conductor set. in 2N-305 (200135).. _ Surface casing. protects all_known USDWS . NA- All aquifers exempted,_40CFR 147.102 (b)(3), CMT VOI_ adequate to circulate on conductor & surf csg NA Surface casing set in 2N-305. CMT. vol adequate-to tie-in long string to-surf csg _ _ _ _ No _ _ CMT will cover-all known_productiye horizon_s_ Yes _ _ Casing desgns adequate f_o[ C,.T, B &-permafrost Yes . - Adequate tankage. or reserve pit Yes Rig equipped with steel pits. No reserve pit planned.. All waste to approved disposal well(s).or annuli. If_a_re-drill, has a 10-403 for abandonment been approved Yes - - - 308.4.50 - - Adequate wellbore separation_ptoposed - - Yes Proximity analysis performed. Nearest segment is P&A portion of 2N-305 and_pathsdiverge. - - . If diverter required, does it_meet regulations- NA_ BOP stack will already be.in place, Drilling fluid program schematic-& equiptist adequate Yes . Maximum expected formation pressure 11.6 EMW.. MW planned up to 12.1 ppg. BOPES,.do they meet regulation - Yes _ BOPE press rating appropriate; test t_o.(put prig in-comments}. Yes MASP calculated at2583 psi.. 3500 psi BOP test planned.- Chokemanifold complies wlAPl_ RP-53 (May 84) Yes Work will occur without operationshutdown_ _ Yes _ _ _ .. - _ - _ Is presence of H2S gas. probable- - . . - - - - Yes - H2S is reported_at 2N pad.. Mudshould preclude H2S on rig. -Rig has sensors and alarms. . . MechanicaLconditon of wells within AOR verified (For service well only) _ NA _ Permit can be issued wlo hydrogen. sulfide measures No 2N-305_ measured from 100 m H2S on 10-13-06 pp Data.p_resented on potential overRressur_e zones. Yes Expected reservoirpressure is 11,6 ppg; mud program cal_IS for 11.3. ppg mud -.flagged for drilling-engineer. Seismic analysis of shallow gas. zones. NA Re-drill. Seabed condition survey (rfcff-shore) _ _NA_ Contactnamelphoneforweekly-progress reports [exploratoryonlyj ---------------- NA-__ __---_.-----___..--. _--._-.__---.-.-.._.-_--.--.--.-...__-._-..__---- Engineering Date: Commissioner: Date ~~~~ 8-~~ Date /- 8'-°~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~ ~ 2n-305a.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 02 11:59:24 2009 Reel Header Service name ............. LISTPE Date . ................... 09/04/02 Ori9in ................... 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 . ...................09/04/02 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................5T5 LIS writing Library. scientific Technical services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: 2N-305A API NUMBER: 501032034901 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 02-APR-09 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: MW0006247153 Mw0006247153 Mw0006247153 LOGGING ENGINEER: P. ORTH P. ORTH S. POLAK OPERATOR WITNESS: F. HERBERT F. HERBERT M. THORTON MWD RUN 5 JOB NUMBER: Mw0006247153 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: M. THORTON SURFACE LOCATION SECTION: 3 TOWNSHIP: 9N RANGE: 7E FNL: 6 FSL: FEL: 529 FWL: Page 1 ~0~-202 l~ g/3 . i ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 2n-305a.tapx 160.45 119.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 3032.0 4.750 5.500 9920.0 • 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF OF A CEMENT PLUG OUT OF THE 7.625" CASING SHOE (3032'MD/2302'TVD) IN 2N-305. 4. MWD RUNS 1-3,5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY(DGR/GM)UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4(EWR4). RUNS 1-3 ALSO INCLUDED GEOPILOT ROTARY-STEERABLE BHA(GP), DRILLSTRING DYNAMICS SENSOR (DDSR), AND PRESSURE WHILE DRILLING(PWD). RUN 4 WAS A DRILLING WITH CASING RUN - NO MWD TOOLS WERE IN THE BHA. ROP DATA OVER THE RUN 4 INTERVAL WERE MERGED WITH RUN 5 DATA. 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL DATED 3/25/09 FROM P. PERFETTA (CPAI) TO B. BURINDA (SDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-5 REPRESENT WELL 2N-305A WITH API#: 50-103-20349-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10335'MD/5509'TVD. 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 - DEEP RESISTIVITY. File Header Service name... .......STSLIB.001 service Sub Level Name... Page 2 • 2n-305a.tapx version Number. ........1.0.0 Date of Generation.......09/04/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLi6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPS RPM RPX ROP FET 1 clipped curves; all bit runs merged. .5000 START DEPTH 3072.5 3079.5 3079.5 3079.5 3079.5 3130.5 3130.5 STOP DEPTH 10276.0 10290.5 10290.5 10290.5 10290.5 10335.0 10290.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 1 3072.5 2 3663.0 3 6123.0 5 9783.0 REMARKS: MERGED MAIN PASS. MERGE BASE 3663.0 6123.0 9783.0 10335.0 Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ................ ..... Datum Specification Block sub-type...0 Name service order DEPT RPD MWD RPM MWD RPS MWD RPX MWD FET MWD GR MWD ROP MWD units size Nsam Rep code offset FT 4 1 68 0 OHMM 4 1 68 4 OHMM 4 1 68 8 OHMM 4 1 68 12 OHMM 4 1 68 16 HR 4 1 68 20 API 4 1 68 24 FPH 4 1 68 28 Page 3 Channel 1 2 3 5 6 7 8 2n-305a.tapx First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3072.5 10335 6703.75 14526 3072.5 10335 RPD MWD OHMM 1.1 1607.97 5.28147 14068 3079.5 10290.5 RPM MWD OHMM 1.4 1572.49 4.54383 14068 3079.5 10290.5 RPS MWD OHMM 1.46 1918.64 5.70096 14068 3079.5 10290.5 RPX MWD OHMM 1.46 958.75 4.36564 14068 3079.5 10290.5 FET MWD HR 0.36 82.56 2.15402 13966 3130.5 10290.5 GR MWD API 46.89 224.69 118.508 14079 3072.5 10276 ROP MWD FPH 0.01 264.34 70.062 14410 3130.5 10335 First Reading For Entire File..........3072.5 Last Reading For Entire File...........10335 File Trailer Service name... .......STSLIB.001 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......09/04/02 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EoF File Header Service name... .......STSL2B.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/04/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 3072.5 3605.5 SEDP 3079.5 3612.5 SEMP 3079.5 3612.5 SEXP 3079.5 3612.5 SESP 3079.5 3612.5 SROP 3130.5 3663.0 SFXE 3130.5 3612.5 LOG HEADER DATA DATE LOGGED: 25-FEB-09 SOFTWARE SURFACE SOFTWA RE VERSION: Insite Page 4 C 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: 2n-305a.tapx 74.11 Memory 3663.0 3130.0 3663.0 58.3 67.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 EleCtrOmag Re515. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) 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 Loggin Direction ................. Down optical log depth units........... Feet Data Reference Point .............. Undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth units ......... .. ... ..... Datum specification Block sub-type ...0 Name Service Order Units Size Nsam DEPT FT 4 1 RPD MWDO10 OHMM 4 1 RPM MWDO10 OHMM 4 1 RPS MWDO10 OHMM 4 1 RPX MWDO10 OHMM 4 1 FET MWDO10 HR 4 1 TOOL NUMBER 11209853 11212348 6.750 3032.0 Fresh water Gel 9.20 120.0 10.5 1500 5.2 2.000 65.0 1.550 86.0 1.750 65.0 2.200 65.0 Rep code offset channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 Page 5 • 2n-305a.tapx GR MWDO10 API 4 1 68 24 7 ROP MwD010 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3072.5 3663 3367.75 1182 3072.5 3663 RPD MwD010 OHMM 1.55 12.93 5.10309 1067 3079.5 3612.5 RPM MwD010 OHMM 1.4 10.8 3.96499 1067 3079.5 3612.5 RPS MWDO10 OHMM 1.69 11.5 4.31417 1067 3079.5 3612.5 RPX MWDO10 OHMM 1.95 12.9 4.25499 1067 3079.5 3612.5 FET MwD010 HR 0.55 7.37 1.66788 965 3130.5 3612.5 GR MwD010 API 48.53 141.89 103.889 1067 3072.5 3605.5 RoP MwD010 FPw 0.12 161.26 65.8024 1066 3130.5 3663 First Reading For Entire File..........3072.5 Last Reading For Entire File...........3663 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/04/02 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSL2B.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/04/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.002 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 SGRC 3606.0 6065.0 SEXP 3613.0 6072.0 SFXE 3613.0 6072.0 SEMP 3613.0 6072.0 SEDP 3613.0 6072.0 SESP 3613.0 6072.0 SROP 3663.5 6123.0 LOG HEADER DATA Page 6 • 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: 2n-305a.tapx 28-FEB-09 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) 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 Loggin Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ......... .. ... ..... Datum specification Block sub-type...0 Insite 74.11 Memory 6123.0 3663.0 6123.0 65.5 67.7 TOOL NUMBER 11209853 11212348 6.750 3032.0 Fresh water Gel 9.20 49.0 10.5 1500 5.2 1.600 65.0 1.550 86.0 1.000 65.0 1.400 65.0 Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 Page 7 • 2n-305a.tapx RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3606 6123 4864.5 5035 3606 6123 RPD MWD020 OHMM 2.76 10.86 4.48525 4919 3613 6072 RPM MWD020 OHMM 2.19 8.02 3.55462 4919 3613 6072 RPS MWD020 OHMM 2.28 8.09 3.87538 4919 3613 6072 RPX MWD020 OHMM 2.22 7.94 3.84704 4919 3613 6072 FET MWD020 HR 0.44 18.59 1.62414 4919 3613 6072 GR MWD020 API 53.54 154.15 107.577 4919 3606 6065 ROP MWD020 FPH 0.19 136.86 69.7191 4920 3663.5 6123 First Reading For Entire File..........3606 Last Reading For Entire File...........6123 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/04/02 Maximum Physical Record..65535 File Type ................L0 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.......09/04/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH SGRC 6065.5 SESP 6072.5 SFXE 6072.5 SEMP 6072.5 SEXP 6072.5 SEDP 6072.5 SROP 6123.5 header data for each bit run in separate files. 3 .5000 STOP DEPTH 9725.0 9732.0 9732.0 9732.0 9732.0 9732.0 9783.0 Page 8 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 EWR4 Electromag BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 2n-305a.tapx RAY Resis. 4 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units .. .. ..... Datum Specification Block sub-type...0 • 06-MAR-09 Insite 74.11 Memory 9783.0 6123.0 9783.0 47.7 67.0 TOOL NUMBER 11209853 11212348 6.750 3032.0 Fresh water Gel 9.80 45.0 9.5 600 4.4 1.100 74.0 .640 131.0 1.300 74.0 1.100 74.0 Name service order units size Nsam Rep Code offset Channel Page 9 • 2n-305a.tapx DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 RoP MWD030 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 6065.5 9783 7924.25 7436 6065.5 9783 RPD MWD030 OHMM 1.96 8.72 4.60896 7320 6072.5 9732 RPM MWD030 OHMM 1.66 8.07 3.63196 7320 6072.5 9732 RPS MWD030 OHMM 1.7 9.17 3.89344 7320 6072.5 9732 RPX MWD030 OHMM 1.66 10.24 3.85869 7320 6072.5 9732 FET MWD030 HR 0.36 46.3 2.03253 7320 6072.5 9732 GR MWD030 API 46.89 2 24.69 126.957 7320 6065.5 9725 ROP MWD030 FPH 0.91 2 64.34 77.0548 7320 6123.5 9783 First Reading For Entire File..........6065 Last Reading For Entire File...........9783 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/04/02 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.005 Physical EoF File Header Service name... .......sTSLI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/04/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH SROP 9783.5 SGRC 9883.5 SEMP 9910.0 SEXP 9910.0 STOP DEPTH 10335.0 10276.0 10290.5 10290.5 Page 10 • • 2n-305a.tapx SESP 9910.0 10290.5 SEDP 9910.0 10290.5 SFXE 9910.0 10290.5 LOG HEADER DATA DATE LOGGED: 14-MAR-09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10335.0 TOP LOG INTERVAL (FT): 9943.0 BOTTOM LOG INTERVAL (FT): 10335.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 43.8 MAXIMUM ANGLE: 45.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 78005 EWR4 ELECTROMAG. RESIS. 4 171169 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.750 DRILLER'S CASING DEPTH (FT): 9920.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) 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 Depth units ....................... Page 11 Fresh water Gel 12.00 52.0 9.3 400 3.8 1.500 68.0 .820 129.4 1.210 68.0 2.100 68.0 • 2n-305a.tapx Datum Specificat ion Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FPH 4 1 68 28 8 First Last Name Service Unit Min Mdx Mean Nsam Reading Reading DEPT FT 9783.5 10335 10059.3 1104 9783.5 10335 RPD MWD050 OHMM 1.1 1607.97 17.1316 762 9910 10290.5 RPM MWD050 OHMM 1.45 1572.49 20.4998 762 9910 10290.5 RPS MWD050 OHMM 1.46 1918.64 36.7913 762 9910 10290.5 RPX MWD050 OHMM 1.46 958.75 12.7384 762 9910 10290.5 FET MWD050 HR 1.51 82.56 7.35727 762 9910 10290.5 GR MWD050 API 79.02 161.58 128.022 786 9883.5 10276 ROP MWD050 FPH 0.01 58.84 29.3375 1104 9783.5 10335 First Reading For Entire File..........9783.5 Last Reading For Entire File...........10335 File Trailer Service name... .......STSLI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/04/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................09/04/02 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ...................09/04/02 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library Scientific Technical services scientific Technical services Page 12 Physical EOF Physical EOF End Of LIS File 2n-305a.tapx Page 13 r1 LJ ConocoPhillips Alaska, Inc. FINAL WELL REPORT MUDLOGGING DATA Kuparuk River Unit 2N-305A Provided by: €~ EPOCH • Approved by: Compiled by: Josh Dubowski Peter Dykema Date: March 14, 2009 Distribution: March 23, 2009 a~ ~ M ~Ot'lOC0~1#~~I~35 • Alaska,lnc. 2N-305A TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ............................................................... ................................. 3 1.1 Equipment Summary ..................................................................................... ................................. 3 1.2 Notes .............................................................................................................. .................................3 1.3 Crew ............................................................................................................... ................................. 3 2 WELL DETAILS .................................................................................................... .................................4 2.1 Well Summary ................................................................................................ .................................4 2.2 Hole Data ....................................................................................................... ................................. 4 3 GEOLOGICAL DATA ............................................................................................ .................................5 3.1 Mud Log Summary ......................................................................................... .................................5 3.2 Connection Gas Summary ............................................................................. ................................. 8 3.3 Trip/Wiper Gas Summary .............................................................................. ................................. 8 3.4 Sampling Program /Sample Dispatch ........................................................... ................................. 9 4 DRILLING DATA ................................................................................................... ...............................10 4.1 Daily Activity Summary :................................................................................. ...............................10 4.2 Survey Data ................................................................................................... ...............................14 4.3 Bit Record ...................................................................................................... ...............................18 4.4 Mud Record ................................................................................................... ...............................19 5 DAILY REPORTS ................................................................................................. ...............................21 Enclosures 2"/100' Formation Log (MD and TVD) 2"/100' LWD / Lithology Log (MD and TVD) • 2"/100' Drilling Dynamics Log (MD and TVD) 2"/100' Gas Ratio Log (MD and TVD) 2"/100' FIT Gas Log (MD) • ~f ~~~~LZ 2 ConocoPhillips Alaska, Inc. 2N-305A • • • 1 MUDLOGGING EQUIPMENT 8~ CREW 1.1 Equipment Summary Parameter Equipment Type /Position TO~i Downtime Comments QGM Agitator (Mounted in possum Ditch gas belly) 5.5 hrs Moving Unit Flame ionization total gas & chromato rah . Effective Circulating Density From Sperry-Sun 2080' to TD 5.5 hrs Moving Unit ECD Hook Load / Wei ht on bit Totco Sensors 5.5 hrs Movin Unit Mud Flow In Totco Sensors 5.5 hrs Movin Unit Mud Flow Out Totco Sensors 5.5 hrs Movin Unit Mudlogging unit computer HP Compaq Pentium 4 (X2, DML & 5.5 hrs Moving Unit s stem Ri watch Mudlogging unit DAC box In-unit data collection/distribution 5.5 hrs Moving Unit center Pit Volumes, Pit Gain/Loss Totco Sensors 5.5 hrs Movin Unit Pum Pressure Totco Sensors 5.5 hrs Movin Unit Pum stroke counters Totco Sensors 5.5 hrs Movin Unit Totco Well Monitoring Totco RigWatch Sensors 5.5 hrs Moving Unit Components Rate of penetration Totco Sensors 5.5 hrs Movin Unit RPM Totco Sensors 5.5 hrs Movin Unit Torque Totco Sensors 5.5 hrs Movin Unit 1.2 Notes March 2, 2009 -Rigged down and moved unit as per company mans instructions. No data gathered for about 5.5 hours. 1.3 Crew Unit Type Arctic Unit Number ~ ML030 Years experience as Mudlogger "~ Days at wellsite between rig up and rig down of logging unit. Mudloggers Years Days Sample Catchers Years Days Technician Days Josh Dubowski 1 28/31 Dean Kekeaualua 2 13 Allen Williams 0/xx Peter D kema 5 31/31 James Cha man 0.5 17 R an Boothe 0.5 12 Stephan Castle 7 20 L ^ ~~~C~ • Conoa Phillips Alaska, Ina 2 N-3O5A 2 WELL DETAILS 2.1 Well Summary Well: KRU 2N-305A API Index #: 50-103-20349-01 Field: Kuparuk River Unit Surface Co-Ordinates: 6' FNL, 529' FEL, Sec 3, T9N, R7E, UM Borough: North Slope Borough Primary Targets: Tarn Oil Pools State: Alaska Primary Target Depth: 9,929' MD/ 5,218' TVD Rig Name /Type: Doyon 15/Arctic/Triple TD Depth: 10,335' MD / 5,509' TVD Spud Date: 2/18/2009 Ground Elevation: 119' MSL TD Date: 3/14/2009 KB Elevation: 149' MSL Days Drilling: 15 TD Formation: Base of Bermuda Completion Status: Complete w/ 3 %" Liner Days Evaluating: 16 Classification: Sidetrack Producer 2.2 Hole Data • Maximum De th Shoe D e th FIT Hole TD Mud Dev. Casing/ (ppg) Section MD TVD Formation Weight a. (inc) Liner MD TVD MD (ft) (ft) (ppg) (ft) (ft) ft 2N-305 025' 3 2,302' Colville 9.3 62.25 7 5/8" 3,025 2,302' cased Section , Intermediate 9,923' 5,219' Seabee 9.7 44.52 5'/" 9,923 5,219 17.5 Production 10,335' 5,509' Seabee 12.0 44.85 3 %" 10,33 5' 5,509' E~~C1Z Conoc Phillips Alaska, Inc.. 2N-305A 3 GEOLOGICAL DATA 3.1 Mud Loa Summary C80 K10 3 428' MD 2 485' TVD Drill Rate ft/hr Total Gas units) Maximum Minimum Avera a Maximum Minimum Average 128.2 10.1 73.1 104 18 63.8 This section is comprised of sandstone and claystone. The sandstone demonstrates bright white mineral fluorescence on 5-10% of samples, and very slow and poor milky white cut. No odor or other hydrocarbon indicators. CLAYSTONE/SANDSTONE --Light gray to light medium gray; poor induration; soft to easily friable; crumbly to slightly brittle; irregular fracture; amorphous cuttings habit; dull to slightly earthy luster; moderate to poor cohesion; poor to moderate adhesion; mushy to slightly clumpy; massive and interbedded with thin layers of sand and a silty sandstone; dark lithics and a black carbonaceous material are common; disseminated pyrite; the sandy siltstone is commonly moderately hard and shows moderate induration. Campian Sandstone 3.589' MD 759 (2.550' TVD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Avera a Maximum Minimum Avera e 148 2.1 69 155 0 28 • This section is comprised of sandstone. It demonstrates bright white fluorescence on approximately 5% of the sample, and very poor, slow, milky white cut to no cut. No odor or other hydrocarbon indicators. SANDSTONE --Tight medium gray to light gray with light olive hues commonly lower fine to upper very fine; occasionally lower medium to upper fine grained; moderate to poor sphericity; sub angular to angular to occasionally sub rounded; well sorted locally; overall moderate to poor sorting; unconsolidated to poorly consolidated; commonly argillaceous; grain supported; texturally immature; moderate compositional maturity; dominantly translucent to clear to rarely milky white quartz; black to dark gray lithics rare disseminated pyrite and a black carbonaceous material; poor to moderate visual porosity and poor to moderate permeability. C50 6.759' MD (3.821' TVDI Drill Rate ft/hr Total Gas units) Maximum Minimum Avera a Maximum Minimum Avera e 126 11.2 68.9 73 1 29.8 This interval was comprised of sandstone and siltstone. It demonstrated pale gold mineral fluorescence on less than 5% of the samples. No odor or other hydrocarbon indicators. SILTSTONE/SANDSTONE -Medium gray to medium dark gray with brownish hues; moderate to poor induration; irregular fracture; amorphous cuttings habit; dull to slightly earthy; silty to gritty to clayey; crumbly to crunchy; commonly argillaceous; occasionally clotted to curdy; moderately hydrophilic moderate adhesiveness; moderate to good cohesiveness; appears thick and interbedded with thin layers of moderately hard and well cemented sandstone. • ~~~C~ Conoc~iflips Alaska.lnc. 2N-3O5A • C40 7.341' MD (4.052' TVD1 Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Avera a Maximum Minimum Avera e 127 5.9 79 125 1 61.2 This interval is comprised of thin interbedded carbonaceous shale and siltstone. It demonstrated no fluorescence or other oil indicators. CARBONACEOUS SHALE -Dark gray to medium dark gray with brownish gray secondary hues; moderately hard; siliceous cement; grain supported; thin lenticular bedding with occasional black micro-thin carbonaceous stringers on bedding planes; cuttings are bladed often elongated curved and pdc bit etched; earthy, gritty texture, non calcareous; includes coarse lithics of quartz and pyrite; same also as thin partings. SILTSTONE --Medium gray to dark medium gray with occasional brownish hues; poorto moderate induration; crumbly to crunchy; amorphous cuttings habit earthy to dull luster; irregular fracture; argillaceous in part moderately hydrophilic; also moderate amounts of shale and a moderately hard sandstone; trace amounts of disseminated pyrite, inoceramus prisms and a black carbonaceous material. C37 7 892' MD 4 275' TVD Drill Rate ft/hr Total Gas units) Maximum Minimum Avera a Maximum Minimum Avera e 136 8 82 510 1 55 • This interval was comprised of sandstone, siltstone and shale. It demonstrated no odor or other hydrocarbon indicators. SANDSTONE -- Medium light gray to light gray with light greenish gray secondary hues; very fine upper to fine upper, occasional clasts up to pebble sized; poorto fair sorting; angular to well rounded, predominantly sub rounded; moderate to high sphericity; much is re-worked, aggregate grains appear frosted yielding an overall sucrosic texture; grain supported; clasts include quartz, chert framboidal pyrite and glauconite; locally common white to yellowish gray to clear inoceramus prisms; non calcareous. SILTSTONE/SHALE --Medium gray to dark medium gray with occasional brownish hues; irregular to planar fracture; amorphous to platy cuttings habit; silty to clayey to gritty texture; crumbly to crunchy and occasionally flakes apart when prodded; alternating thin layers of siltstone and shale. T7 9.222' MD (4.817' TVDI Drill Rate ft/hr) Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 270 5 89 232 4 54 This interval was comprised of sandstone. It demonstrated no odor or other hydrocarbon indicators. SANDSTONE -- Medium gray to medium light gray with yellowish gray secondary hues; very fine upper to fine upper, mostly fine lower; angular to rounded, mostly sub rounded; generally well sorted; moderate to high sphericity; samples are unconsolidated; "clean" quartz sandstone; quartz is mostly clearwith translucent light shades of gray and light brown; lithic clasts up to medium grained include quartz, feldspar, glauconite and calcite. • C ^ L~~~C 6 Conoc Phillips Alaska, lnc. 2N-3O5A T4 9.868' MD (5.174' TVD) Drill Rate (ft/hr Total Gas units) Maximum Minimum Avera a Maximum Minimum Avera e 38 15 31 67 3 33 This interval was comprised of sandstone. Fluorescence is impossible to determine due to heavy mud additive contamination. No odor or other hydrocarbon indicators were observed. SANDSTONE --Sample is polluted with almost 100% mud additives; light gray to light medium gray; moderate to poor sphericity; sub angular to sub rounded to occasionally rounded; lower medium to upper fine grained; argillaceous in part; grain supported; moderate compositional maturity; poor to moderate textural maturity; rare disseminated pyrite; sandstone is dominated by translucent to clear quartz. T3 -Top of Reservoir (Bermuda) 9.929' MD (4.817' TVDI Drill Rate ft/hr Total Gas (units Maximum Minimum Avera a Maximum Minimum Avera e 57 6 35 1002 3 141 This section is comprised of sandstone. It demonstrates traces scattered light yellowish white fluorescence, and dull, slow, streaming, straw colored cut fluorescence on rare consolidated sandstone samples. SANDSTONE -- Light gray to very light gray; very fine lower to very fine upper; fair to well sorted; angular to sub rounded, mostly sub angular; 50% reworked; moderate sphericity; grain supported; moderate to high textural maturity; moderate compositional maturity; fairly clean quartzose; common medium to coarse angular quartz clasts, and traces of chert, jasper, calcite, citrine. T2 -Base of Reservoir (Bermuda) 10 138' MD 5 368' TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Avera a Maximum Minimum Avera e 57 6 35 1002 3 141 This section is comprised of sandstone. It demonstrates traces scattered light yellowish white fluorescence, and dull, slow, streaming, straw colored cut fluorescence on rare consolidated sandstone samples. SANDSTONE -- Light gray to very light gray; very fine lower to very fine upper; fair to well sorted; angular to sub rounded, mostly sub angular; moderate to high sphericity; grain support; predominantly clear quartz grading to light gray translucent with trace fine to medium lithic clasts including jasper, glauconite, feldspar, calcite, citrine; note clast size increasing with depth to very coarse at 10,140' MD; clear silica cement; 95% unconsolidated in sample; rare very pale blue to white clay partings; 70-80%. ~ ~ EPOCH • ConocoRhllips Alaska, Inc. 2N-305A 3.2 Connection Gas Summary 1unit = 0.05% Methane Equivalent Depth (ft) MD/TVD Background Gas (Units) Units Above Background 3,295'/2,430' S0 159 3,484'/2,507' S5 32 3,579'/2,545' 67 20 7,543'/4,133' 49 33 7,636'/4,170' 65 63 7, 731 '/4,209' 68 57 7,829'/4,249' 37 38 8,581'/4,553' 56 9 8,961'/4,710' 37 17 10,229'/5,435' S0 1428 10,285'/5,473' 70 110 10,291'/5,477' 150 575 3.3 Trip/Wiper Gas Summary • 1 Unit = 0.05% Methane Eauivalent Depth (ft) MD/TVD Trip to (ft) MD/TVD Maximum Gas Units Downtime hours 3,661'/2,578' 281 5 hr 6,119'/3,564' 225 39 hrs 9,323'/4,860' 375 20 min 9,323'/4,860' 680 15 min 9,323'/4,860' 668 15 min 9,323'/4,860' 305 9,783'/5,115' 235 35 min 9,923'/5,209' 110 1 hr 10,265'/5,459' 10,197'/5,413' 1957 2 hr 10,335'/ E~~~1Z • • ., .~ Catoc Phillips Alaska. Inc. 2N-305A 3.4 Sampling Program /Sample Dispatch Set Sample Type Frequency* Interval Dispatched To: ConocoPhillips Alaska, Inc. ABV 100 Processed: 50' 950' 3,050' - 9 619 East Ship Creek Ave. 2 Washed and 10' ' , 9,960' - 10,200' ' ' Suite 102 Anchorage, Ak 99502 Dried 10 - 10,335 10,250 Attn: D. Przywojski 907 263-4859 Isotech Laboratories, Inc. 1308 Parkland Court Iso-tube Gas As directed Champaign, IL 61821 1 Samples in well plan. 9,950 - 10,335' Attn: Steve Pelphrey (217) 398-3490 (Phone) (217) 398-3493 (Fax) Isotech Laboratories, Inc. 1308 Parkland Court Gas Bag ' ' ' Champaign, IL 61821 1 Samples 500 3,500 - 9,500 Attn: Steve Pelphrey (217) 398-3490 (Phone) (217) 398-3493 Fax ~~~~~ Conoc Phillips Alaska, Inc. 2N-305A 4 DRILLING DATA 4.1 Daily Activity Summary: February 16, 2009 rigging up to pull 3 %" production tubing, testing BOPE February 17, 2009 February 18, 2009 Cont' to RIH w/ scraper on 3.5 tubing t/ 9396', Circ. Bottoms up and POOH. February 19, 2009 M/U cement retainer. RIH to 9378' MD. Cement lines. Pfm infectivity test (NO GO). Pull out of plug and spot cement on Plug 5 bbl H2O, 10 Bbls cement, 3.6 bbls H2O and chase with 73 bbls of seawater. POOH. Lay down #1 running tools, M/U #2 running tools. February 20, 2009 L/D 3.5"tubing; L/D running tool, L/D 4 stands tubing out derrick, R/D GBR, R/U for casing test; Perform casing test and clean rig floor; R/D test equipment, B/D mud lines; PJSM for R/U SWS Jet Cutting; TIH w/ Jet Cutter; POOH w/Jet cutter; R/D jet cutter; PJSM for diesel displacement; Attempt to displace diesel, unable to circulate; Pull wear bushing, TIH w/ pack off retrieving tool, close annular, pressure up, bleed off, retrieve pack off tool and L/D; M/U spear, TIH and spear casing; Work casing free, unable to circulate, continue to work casing to establish circulation; Break out double and L/D, blow down top drive. February 21, 2009 L/D hanger and spear, R/U 5.5" handling tools to pull casing; PJSM for POOH w/5.5" casing; POOH on elevators from 3,370' MD to 2,975' MD, attempt to establish circulation every 3 joints; Circulate through choke at 2,975' MD due to high gas (5000 units, totco); Open hydrill and circulate at 5bpm; Continue to circulate hole clean; R/U test equipment, perform LOT (14.0 ppg EMW), R/D test equipment; Circulate 40bb1 sweet, monitor well (breathing), circulate and monitor well, hole swabbing when POOH; POOH on elevators from 2,300' MD to 550' MD, establish circulation every 3 joints due to swabbing. February 22, 2009 Continue to POOH and establishing circ every 3 joints; Monitor well (static), R/D 5.5" handling equipment, B/D lines, R/U to test BOPE, test Hydril, R/D test equipment, install wear bushing; PJSM for P/U clean out run BHA, M/U clean out run assembly; TIH on elevators with clean out BHA; Continue to TIH with clean out BHA; TIH to 3,020' MD with clean out BHA, CBU (460 units gas), monitor well (static); Pump in hole from 3,020' MD to 3,358' MD; BROOH to 3,020' MD, CBU (300 units gas), monitor well (static), B/D top drive; R/U test equipment, perform LOT (13.7 ppg EMW), R/D test equipment; TIH to 3,374' MD and tag liner top, rotate 1/4 turn and TIH to 3,384' MD; CBU (126 units gas), monitor well (static); POOH on elevators from 3,324' MD to 475' MD; L/D BHA, clear and clean rig floor. February 23, 2009 Continue to single in hole from 287' MD to 885' MD; R/D 2 7/8" handling equipment, R/U 4" handling equipment, single in hole with 4" DP from 885' MD to 3,022' MD, CBU (112 units gas); POOH 10 stands, rack back in derrick, single in with 30 joints of 4" DP, rack back 10 stands in derrick, single in with 30 joints of 4" DP; Continue to single in with 4" DP and rack back stands in derrick; TIH to bottom, CBU (160 units gas); Pump cement, mud push; POOH on elevators to 885' MD; R/U 2 7/8" handling equipment, POOH with 2 7/8" DP; R/U Halliburton wireline tools for caliper log run; RIH with junk basket BHA on wireline; C/O wireline BHA, RIH with caliper BHA, log out of hole. • ~i E~~c 10 Conut Phillips Alaska. Inc. 2N-305A February 24, 2009 Check caliper data (good); C/O lower rams, R/U test equipment, test rams, R/D test equipment, pull wear bushing, test plug; P/U BHA #3; Continue to P/U BHA #3; P/U BHA #3, upload MWD, continue to P/U BHA to 648' MD, shallow test MWD and break in GeoPilot seals; TIH on elevators from 648' MD to 2,917' MD; Service traveling equipment; PJSM for cut and slip drill line, slip and cut drill line, , R/U test equipment; Test casing to 1200 psi for 30 min (good); TIH from 2,907' MD to 2,925' MD (TOC), rotate and wash down from 2,925' MD to 3,130' MD; Drill ahead 7 1/2" hole from 3,130' MD to 3,185' MD, POOH to 3,010' MD; R/U testing equipment, perform LOT, R/D testing equipment, B/D -ines; Drop ball and activate rhino reamer, ream to bottom, POOH to 3,145' MD for PWD baseline; Drill ahead from 3,185' MD to 3,457' MD. February 25, 2009 Drill ahead from 3,457' MD to 3,621' MD; Drill ahead from 3,621' MD; Drill ahead from 3,621' MD to 3,663' MD; Rotate and reciprocate while circulating sweep out of hole from 3,663' MD to 3,573' MD, monitor well; POOH on elevators for BHA inspection (poor ROP); UD BHA #3, download BHA; Service rig, clear and clean rig floor, service GeoPilot; P/U BHA #4 to 255' MD, shallow test MWD, continue to P/U BHA #4 from 255' MD to 653' MD; TIH with 4" DP from 653' MD to 3,580' MD; Drill ahead from 3,580' MD to 3,674' MD. February 26, 2009 Drill ahead from 3,674' MD to 4,768' MD, and beyond. February 27, 2009 Drill ahead from 4,768' MD to 4,890' MD, and beyond. February 28, 2009 Drilled from 5651' MD to 6100' MD; Pump out of hole 10 stands for short wiper trip and TIH to bottom; Drill ahead from 6,100' MD to 6,123' MD; Monitor well ;Pumped 20 bbl slug and POOH on elevators, rack back BHA, download MWD; Clean and clear rig floor, pull wear bushing; Test BOPE. March 1, 2009 Continue to test BOPE; R/D test equipment, B/D lines and install wear bushing; Perform rig maintenance while waiting on Phase 3 weather. March 2, 2009 Weather conditions improved and drilling operations continued. P/U BHA #5, upload MWD, shallow test MWD and RIH with 4" DP; CBU at 4,520' MD and 6„123' MD. Drilling ahead from 6,123' MD to 6,380' MD; Pull up off bottom and troubleshoot pressure loss; Drill ahead from 6,380' MD to 6,734' MD. NOTE: From approximately 18:00 to 23:30 Epoch had to shut down and rig down in order to move the logging to allow Halliburton access to a well house. March 3, 2009 Drilled ahead from 6,734' MD to 7,165' MD; POOH for 5 stand wiper trip; Drilled ahead from 7,165' MD to 7,708' MD. March 4, 2009 Drilling ahead from 7,708' MD to 8,486' MD; Rack back one stand, change out swivel packer; Drill ahead from 8,486' MD to 8,977' MD. March 5, 2009 Drilled ahead from 8978' MD to 9323' MD. Lost 12% flow out. Check flow -falling steady. Monitor well. Static losses 30-40 BPH. Lost full returns. Pumped 60 bbls 20 ppb LCM sweep. Regained partial returns. Pumped second LCM sweep. Lost full returns. Built dry job, attempt to POOH, swabbing, pump out of hole to establish circulation and begin reducing mud weight. Staging in hole 9.7 ppg. • Drill ahead from 8.977' MD to 9,324' MD; Lost returns (12% flow out), falling steady, static Tosses 30-40 E~~~l~ 11 ColnocoYPhiUips Alaska, Inc. 2N-3O5A bbl/hr, lost full returns; Pumped 60 bbls 20 ppb LCM sweep; lower mud weight from 11.2 ppg to 9.7 ppg; Regained partial returns. Pumped second LCM sweep. Lost full returns; Built dry job, POOH from 9,250' MD to 4,901' MD, hole swabbing, pump out of hole; Establish full returns at 4,901' MD, circulate @ 4 bpm - staging to 330 gpm; B/D top drive, C/O saver sub; TIH 10 stands, CBU -staging to 330 gpm; Continue to TIH and staging circulation to 330 gpm over 10 stands March 6, 2009 Continue TIH and staging circulation to 330 gpm every 10 stands (currently 9,235' MD); Drill ahead from 9,324' MD to 9,783' MD (intermediate TD); Circulate hole clean; Condition mud to 9.7 ppg; B/D top drive, monitor well (slight flow); Rotate and reciprocate while circulating; Monitor well (static), B/D top drive, Pump dry job and POOH racking back 30 stands in derrick. March 7, 2009 Continue to POOH, laying down 4" DP; PJSM, cut drill line at shoe; Cut and slip drilling line; POOH laying down 4" DP; UD BHA #5, download MWD; Clear and clean rig floor, remove wear bushing, C/O saver sub; PJSM, TIH with 5.5" casing drilling assembly. March 8, 2009 Continue to TIH with 5 1/2" casing drilling assembly; CBU at 5,406' MD and lost 80 bbls. Shut off pumps and gained 40 bbls in returns. Circulated again and lost an average of 20-25 bbl/hr. RIH and drilled from 9,783' MD to 9,923' MD. CBU, add LCM to mud and attempt to stabilize losses; prep for LOT. March 9, 2009 Continue to circulate, add LCM (10 ppb) and attempt to stabilize losses; Unable to stabilize losses enough for LOT, R/U and prepare to cement 5.5" casing; Cementing 5.5" casing; Wait on cement, B/D top drive, R/D Tesco, R/D GBR, C/O saver sub; PJSM, N/D stack, set emergency slips, cut 5.5" casing, C/O and test BOP. March 10, 2009 Set stack; Perform infectivity test and test BOPE; Continue to set slips, change rams and test BOP; P/U BHA #7 and TIH w/ 2 7/8" DP. March 11, 2009 Continue to P/U BHA #7 and TIH; TIH singling in to bottom; Perform casing integrity test; Tagged cement at 9,840' MD; Drill out cement, float collar and 20' of new hole from 9,923' MD to 9,943' MD; CBU at report time. March 12, 2009 Circulate bottoms up; B/D top drive, R/U for LOT; Perform LOT (Mud wt. 9.7 ppg showed 17.5 EMW); Monitored well (static), pumped 12.0 ppg dry job before POOH with 2 7/8" DP. POOH to surface; UD BHA #7; Clean and clear rig floor, P/U and M/U BHA #8/MWD; Shallow test MWD, continue to P/U BHA #8, TIH to bottom and preparing to displace 9.7 #/gal mud to 12.0 #/gal LSND; Wash and ream from 9,800' MD to 9,943' MD. March 13, 2009 Take deviation surveys; PJSM -Pre-reservoir meeting, monitor well (static); Pump 20 bbl steel tube sweep, chased with 60 bbl 9.7 ppg mud, followed by swap to 12.0 ppg mud; Drill ahead 4 3/4" hole from 9,943' MD to 9,967' MD; Continue to drill ahead from 9,967' MD; 0600 Drill ahead from 9,967' MD to 10,259' MD. March 14, 2009 Drill ahead from 10,259' MD to 10,265' MD; L/D kelly joint, B/D top drive, C/O liner gasket on pumps; Drill ahead from 10,265' MD to 10,335' MD. TD well at 10,335' MD / 5,509' TVD @ 10:54 on 3/14/2009. ~i E~~~1Z 12 Conoc~illips Alaska, Inc. 2N-3O5A March 15, 2009 @ 10,335' circulate bottoms up x 2. Max gas = 1422 units. Increase fluid density in mud to 12.5ppg. POOH 10 stands to 9,920'; monitor well (static); TIH, circulate bottoms up, check for gas - 202 units max. - static; pump dry job, POOH laying down 2 7/8" drill pipe. March 16, 2009 Clean and clear rig floor; PJSM for running 3'/' 511 Hydril, 9.2 ppf L-80 liner; C/O elevators, M/U hanger; RIH to 740' circulate 2 x liner volumes t^ ~~~C~ 13 Conoc Phillips Alaska, lnc. 2N-305A 4.2 Survey Data 4.2.1 Surface Hole: 2N-305 Original Track • • Measured Depth ft Incl. (deg) Azim. (deg) True Vertical Depth (ft) Northings (ft) Eastings (ft) Vertical Section ft Dogleg Rate °/100ft 41.15 0 0 41.15 0 0 0 0 212.33 0.56 101.99 212.33 -0.17 0.82 -0.17 0.33 242.71 0.54 86.86 242.71 -0.20 1.11 -0.20 0.48 280.22 0.61 73.11 280.21 -0.13 1.47 -0.13 0.41 311.65 1.02 48.30 311.64 0.11 1.84 0.11 1.69 342.51 1.92 26.26 342.49 0.75 2.28 0.75 3.39 372.76 3.15 19.24 372.71 1.99 2.77 1.99 4.19 403.47 4.54 13.87 403.35 3.97 3.34 3.97 4.67 433.85 5.35 10.68 433.62 6.53 3.90 6.53 2.81 463.63 6.39 6.62 463.24 9.54 4.34 9.54 3.76 494.01 7.68 4.07 493.39 13.24 4.68 13.24 4.37 524.78 8.95 4.32 523.84 17.68 5.01 17.68 4.13 554.96 9.67 6.63 553.62 22.54 5.48 22.54 2.69 585.92 9.61 7.66 584.14 27.68 6.12 27.68 0.59 617.06 10.10 8.24 614.82 32.96 6.86 32.96 1.61 646.22 10.89 9.06 643.50 38.21 7.66 38.21 2.76 678.11 11.68 10.29 674.77 44.36 8.71 44.36 2.59 707.04 12.90 11.16 703.03 50.41 9.86 50.41 4.27 739.55 14.29 11.30 734.63 57.91 11.35 57.91 4.28 830.95 15.87 13.56 822.88 81.12 16.49 81.12 1.84 891.29 16.35 13.75 880.85 97.39 20.44 97.39 0.80 940.32 18.21 14.82 927.67 111.50 24.04 111.50 3.85 1000.26 19.51 14.81 984.39 130.23 29.00 130.23 2.17 1065.19 20.84 14.14 1045.33 151.91 34.59 151.91 2.08 1128.38 22.08 13.13 1104.14 174.38 40.03 174.38 2.05 1197.35 24.83 12.23 1167.41 201.16 46.05 201.16 4.02 1286.31 28.04 11.71 1247.06 239.90 54.25 239.90 3.62 1349.73 29.21 11.73 1302.72 269.65 60.42 269.65 1.84 1381.28 30.65 11.54 1330.07 285.07 63.60 285.07 4.57 1444.28 32.54 10.38 1383.73 317.47 69.86 317.47 3.15 1507.69 34.94 10.03 1436.45 352.13 76.10 352.13 3.80 1571.07 38.10 9.73 1487.38 389.29 82.57 389.29 4.99 1634.09 40.48 8.91 1536.15 428.66 89.02 428.66 3.87 1697.49 42.54 8.33 1583.63 470.21 95.31 470.21 3.31 1760.30 44.46 8.25 1629.18 512.99 101.55 512.99 3.06 1823.41 45.64 8.44 1673.77 557.18 108.03 557.18 1.88 1886.25 47.44 8.35 1716.99 602.30 114.69 602.30 2.87 1952.21 49.22 7.67 1760.84 651.09 121.55 651.09 2.81 2013.13 51.33 7.16 1799.78 697.55 127.59 697.55 3.52 2076.52 53.68 6.94 1838.36 747.46 133.76 747.46 3.72 2139.95 55.90 7.13 1874.93 798.89 140.11 798.89 3.51 ~ ~~ocH 14 Conoc~hillips Alaska, Inc. 2N-305A 2203.51 57.67 6.30 1909.74 851.70 146.33 851.70 2.99 Measured Depth ft Incl. (deg) Azim. (deg) True Vertical Depth (ft) Northings (ft) Eastings (ft) Vertical Section ft Dogleg Rate °/100ft 2266.46 59.09 7.27 1942.75 904.93 152.66 904.93 2.61 2328.83 60.64 6.70 1974.06 958.47 159.22 958.47 2.61 2392.25 61.13 6.73 2004.92 1013.49 165.70 1013.49 0.77 2455.33 61.81 5.68 2035.04 1068.59 171.69 1068.59 1.82 2518.48 61.88 5.68 2064.84 1123.99 177.20 1123.99 0.11 2582.63 62.58 5.70 2094.73 1180.47 182.82 1180.47 1.09 2646.20 62.75 6.20 2123.92 1236.64 188.68 1236.64 0.75 2709.41 62.66 5.55 2152.91 1292.52 194.43 1292.52 0.92 2772.71 62.78 6.23 2181.92 1348.48 200.20 1348.48 0.97 2835.93 62.62 6.23 2210.92 1404.32 206.30 1404.32 0:25 2899.05 62.36 6.04 2240.07 1459.99 212.28 1459.99 0.49 2989.77 62.25 6.83 2282.24 1539.81 221.28 1539.81 0.78 3085.92 60.50 5.87 2328.30 1623.68 230.62 1623.68 2.02 3130.45 58.31 5.27 2350.96 1661.83 234.35 1661.83 5.05 3166.02 59.33 6.51 2369.38 1692.10 237.47 1692.10 4.14 3259.85 63.10 9.91 2414.56 1773.45 249.25 1773.45 5.12 3354.00 65.35 12.55 2455.50 1856.59 265.78 1856.59 3.48 3449.38 67.10 6.90 2493.98 1942.58 280.49 1942.58 5.72 3499.06 66.62 8.87 2513.51 1987.83 286.75 1987.83 3.77 3543.02 66.45 9.04 2531.01 2027.66 293.03 2027.66 0.52 3637.00 66.30 7.15 2568.68 2112.90 305.15 2112.90 1.85 3732.63 65.94 8.28 2607.39 2199.55 316.89 2199.55 1.14 3826.56 66.01 8.50 2645.63 2284.43 329.41 2284.43 0.23 3921.07 66.90 10.70 2683.39 2369.84 343.86 2369.84 2.33 4015.51 67.07 12.49 2720.32 2454.99 361.33 2454.99 1.75 4110.17 67.01 11.97 2757.24 2540.17 379.80 2540.17 0.51 4203.74 67.65 10.07 2793.31 2624.92 396.30 2624.92 1.99 4298.46 66.06 9.39 2830.54 2710.75 411.02 2710.75 1.80 4391.75 66.20 8.96 2868.29 2794.97 424.62 2794.97 0.45 4486.66 66.9 9.05 2906.06 2880.97 438.25 2880.97 0.74 4581.70 66.76 8.22 2943.45 2967.35 451.37 2967.35 0.82 4676.17 65.72 7.18 2981.52 3053.03 462.96 3053.03 1.49 4770.72 66.00 7.50 3020.18 3138.61 473.98 3138.61 0.43 4864.42 65.86 7.54 3058.40 3223.42 485.18 3223.42 0.15 4958.59 67.02 7.52 3096.04 3309.00 496.49 3309.00 1.23 5053.04 66.14 7.67 3133.58 3394.91 507.94 3394.91 0.94 5148,29 66.56 7.25 3171.79 3481.42 519.27 3481.42 0.60 5241.79 66.96 6.28 3208.68 3566.73 529.39 3566.73 1.04 5335.51 66.34 7.01 3245.83 3652.20 539.34 3652.20 0.97 5430.95 66.21 7.86 3284.23 3738.84 550.65 3738.84 0.83 5526.15 66.19 7.07 3322.65 3825.20 561.97 3825.20 0.76 5619.39 65.74 6.87 3360.62 3909.73 572.30 3909.73 0.52 ~^ E~~C~1 15 Concx~hillips Alaska, Inc_ 2N-305A Measured Depth ft Incl. (deg) Azim. (deg) True Vertical Depth (ft) Northings (ft) Eastings (ft) Vertical Section ft Dogleg Rate °/100ft 5714.43 65.48 7.92 3399.87 3995.56 583.44 3995.56 1.04 5808.90 65.61 8.68 3438.98 4080.66 595.85 4080.66 0.75 5902.91 65.46 8.85 3477.91 4165.23 608.89 4165.23 0.23 5995.83 66.75 11.32 3515.56 4248.86 623.78 4248.86 2.80 6091.10 66.33 10.61 3553.48 4334.66 640.40 4334.66 0.81 6185.40 66.91 9.32 3590.91 4419.91 655.38 4419.91 1.40 6280.07 66.05 7.57 3628.69 4505.76 668.13 4505.76 1.92 6374.95 66.17 7.53 3667.11 4591.76 679.53 4591.76 0.13 6469.86 66.63 6.85 3705.11 4678.05 690.41 4678.05 0.82 6564.45 66.06 7.16 3743.06 4764.04 700.98 4764.04 0.67 6658.00 66.29 6.84 3780.85 4848.98 711.41 4848.98 0.40 6752.62 66.83 6.69 3818.49 4935.19 721.63 4935.19 0.59 6846.69 66.81 7.09 3855.52 5021.04 732.01 5021.04 0.39 6941.35 66.40 8.23 3893.10 5107.14 743.58 5107.14 1.19 7036.40 66.26 9.15 3931.26 5193.20 756.74 5193.20 0.90 7130.62 66.29 10.13 3969.17 5278.23 771.18 5278.23 0.95 7224.19 67.22 8.89 4006.10 5363.03 785.38 5363.03 1.57 7319.15 66.63 7.85 4043.32 5449.46 798.10 5449.46 1.18 7413.00 66.07 8.94 4080.97 5534.50 810.65 5534.50 1.22 7507.77 66.75 8.72 4118.90 5620.32 823.98 5620.32 0.75 7602.82 65.96 9.59 4157.02 5706.28 837.83 5706.28 1.18 7697.90 66.08 9.70 4195.66 5791.93 852.39 5791.93 0.16 7792.36 65.88 8.98 4234.11 5877.06 866.39 5877.06 0.73 7886.55 65.45 8.35 4272.92 5961.90 879.32 5961.90 0.76 7980.40 65.38 8.44 4311.97 6046.33 891.78 6046.33 0.11 8075.40 65.94 8.59 4351.12 6131.93 904.60 6131.93 0.61 8168.69 66.75 11.13 4388.56 6216.11 919.23 6216.11 2.64 8263.15 66.14 10.78 4426.31 6301.12 935.69 6301.12 0.73 8357.49 66.56 10.86 4464.15 6386.00 951.91 6386.00 0.45 8451.83 66.95 9.50 4501.39 6471.32 967.23 6471.32 1.39 8546.01 65.99 5.55 4539.00 6556.90 978.55 6556.90 3.98 8640.10 65.74 5.98 4577.47 6642.33 987.17 6642.33 0.49 8735.08 65.86 7.40 4616.41 6728.37 997.26 6728.37 1.37 8827.86 65.34 8.35 4654.74 6812.06 1008.84 6812.06 1.09 8923.39 64.94 9.56 4694.9 6897.68 1022.33 6897.68 1.22 9018.46 65.47 10.11 4734.77 6982.72 1037.07 6982.72 0.77 9112.10 66.37 9.71 4772.97 7066.93 1051.78 7066.93 1.04 9207.25 66.48 8.93 4811.03 7152.99 1065.91 7152.99 0.76 9300.90 64.44 8.06 4849.92 7237.24 1078.50 7237.24 2.34 9395.55 62.99 7.91 4891.84 7321.28 1090.28 7321.28 1.54 9490.13 58.57 7.67 4938.00 7403.04 1101.47 7403.04 4.68 9584.88 54.64 11.04 4990.15 7481.07 1114.27 7481.07 5.10 E~~C1Z 16 • ConotoPhillips Alaska, Inc. 2N-305A Measured Depth ft Incl. (deg) Azim. (deg) True Vertical Depth (ft) Northings (ft) Eastings (ft) Vertical Section ft Dogleg Rate °/100ft 9629.88 53.01 10.92 5016.71 7516.73 1121.19 7516.73 3.63 9678.61 51.06 10.18 5046.68 7554.49 1128.23 7554.49 4.18 9747.71 47.70 9.20 5091.66 7606.18 1137.07 7606.18 4.98 9841.95 45.36 8.84 5156.50 7673.73 1147.79 7673.73 2.50 9937.86 44.52 8.46 5224.38 7740.70 1157.99 7740.70 0.92 10,031.07 44.23 8.56 5291.01 7805.17 1167.63 7805.17 0.32 10,064.84 44.01 8.87 5315.25 7828.41 1171.19 7828.41 0.91 10,159.61 44.02 9.10 5383.41 7893.45 1181.48 7893.45 0.17 10,192.04 43.83 8.76 5406.76 7915.68 1184.97 7915.68 0.93 10,286.16 44.81 7.71 5474.10 7980.75 1194.38 7980.75 1.30 10,300.61 44.85 7.19 5484.35 7990.86 1195.70 7990.86 2.55 10,335.00 44.85 7.19 5508.73 8014.92 1198.74 8014.92 0 Li ~~~~ 17 CanocoPhillips Alaska. Inc. 2N-305A 4.3 Bit Record • Bit Size Type Ser. No. Jets/TFA In Out Ftg. Hrs Wear Reason " Hycalog 2 925 621 3 9.14 0-0-No- 1 6'/<< RSX513M- 220620 12 / 0.552 , MD , MD 696 A-X-I-No TD 61 1-1-PN- 2 6 3/ Smith MDI- JX5910 3 x 16 / 3,663 6,123 2 460' 46.32 N-X-O- Problem 613 0.589 MD MD , No-PR 3 6'/" Hughes 4 x 10 9'783 9'923 140' 4.78 N/A L.O.T. EZcase MD MD 4 6 $/<" Hughes 7016129 3x14 6,123 9,783 3 660' 54.8 1-1-No- TD HCD503ZX MD MD , A-X-I-No Hughes 9 923 943 9 ' 5 6 3/" STX-1 5140097 3 x 16 , MD , MD 20 1.5 N/A Plan M it Itooth 1-1-No- 6 4 /" Hughes 7010257 4x12/0.442 9,943 10335 392' 17.86 All-X-I- TD HC404ZX MD MD No ~i ~~~CH 18 • 4.4 Mud Record Contractor: MiSwaco-LSND Intermediate Hole: 7 %" Drilled section Conocoill%ps tom. 2N-305A Date Depth MW (pp9) FLT ~ oF) VIS (s/qt) PV YP Gels FL FC Sols ("~o) O/W Ratio Sd ("~a) MBT pH CI- (ml/I) Ca+ (ml/1) 2/17/2009 3018 9.0 76 47 9 21 8/9/9 9.4 2/- - - - - 10.0 400 80 2/18/2009 3018 9.0 64 45 9 20 8/9/9 9.2 2 - - - - 10.0 440 120 2/19/2009 3018 9.0 64 45 9 20 8/9/9 9.2 2 - - - - 10.0 440 120 2/20/2009 3018 9.0 68 55 9 18 7/9/9 8.4 2/- 3.5 /97 - 3.75 9.8 800 120 2/21/2009 3018 8.9 62 47 9 18 6/8/9 6.3 1/- 4 2/94 - 3.75 9.5 1000 80 2/22/2009 3018 9.0 72 50 6 18 6/7/8 7.0 2/- 3 2/95 Tr 3.5 9.7 1600 80 2/23/2009 3018 9.0 72 50 6 18 6/7/8 7.0 2/- 3 2/95 Tr 3.5 9.7 1600 80 2/24/2009 3186 9.3 68 51 9 21 7/9/10 6.0 1 /- 4 5/92 Tr 3 10.1 1200 60 2/25/2009 3672 9.3 75 54 11 24 8/11 /13 5.4 1 /- 4 4/93 Tr 8 8.4 1250 160 2/26/2009 4771 9.3 75 46 11 17 6/8/10 4.8 1 /- 5 2/93 Tr 12.5 9.5 1300 40 2/27/2009 5654 9.2 75 46 12 20 6/7/9 5.4 1 /- 4 4/92 Tr 12 9.2 1100 20 2/28/2009 6123 9.3 85 55 11 22 8/12/14 4.5 1/- 6 2/92 Tr 15 9.2 800 20 3/1 /2009 6123 9.2 85 50 12 18 7/11 /14 4.5 1 /- 6 2/92 Tr 15 9.4 800 20 3/2/2009 6738 9.3 85 53 14 22 9/14/19 4.5 1/- 6 2/92 Tr 17.5 9.4 800 60 3/3/2009 7316 9.3 85 49 11 18 6/8/12 4.8 1/- 6 2/92 Tr 17.5 9.5 800 80 3/4/2009 8050 10.4 85 45 14 15 4/6/8 4.4 1/- 7 2/92 Tr 18 9.5 600 60 3/5/2009 9323 9.7 80 48 11 17 4/6/8 5.2 1 /- 7 2/91 Tr 14.5 9.5 500 40 3/6/2009 9783 9.7 80 53 15 21 6/8/10 4.2 1/- 8 1/91 Tr 15 9.3 500 40 3/7/2009 9783 9.7 80 54 17 18 6/8/10 4.5 1 /- 8 3/90 Tr 17.5 9.7 400 40 3/8/2009 9923 9.7 73 52 15 14 5/7/9 3.8 1/- 8 3/89 Tr 15 9.5 400 40 3/9/2009 9923 9.7 72 54 17 16 4/6/8 3.8 1 /- 7 3/90 Tr 12 9.5 400 40 3/10/2009 9923 12.0 70 49 17 16 4/5/6 4.2 1/- 9 2/90 Tr 10 9.2 400 20 Abbreviations MW =Mud Weight FL =Water or Filtrate Loss Ca =Hardness Calcium YP =Yield Point Gels =Gel Strength CI =Chlorides PV =Plastic Viscosity FLT =Flow Line Sand =Sand content ECD =Effective Circulating Density VIS =Funnel Viscosity FC =Filter Cake Sols =Solids O/W =Oil to Water ratio E~O~1Z 19 Contractor: MiSwaco--LSND Production Hole: ConocoPhillips . Fem. 2N-305A Date Depth MW (pp9) FLT ("F) VIS (s/qt) PV YP Gels FL FC Sols (,~o) O/W Ratio Sd ("~o) MBT PH CI- (ml/I) Ca+ (ml/I) 3/11 /2009 9943 9.7 72 48 11 15 4/6/8 4.8 1 /- 7 2/91 Tr 15 9.2 400 20 3/12/2009 9943 9.7 70 48 12 14 4/9/8 4.8 1/- 7 2/91 Tr 15 9.2 400 20 3/13/2009 10259 12.0 60 52 19 23 7/9/11 3.8 1/- 7 2/83 Tr 12.5 9.3 400 tr 3/14/2009 10335 12.2 60 56 28 27 9/13/15 3.8 1/- 18 3/79 Tr 17.5 10.2 400 20 3/15/2009 10335 12.5 75 64 29 33 11/15/17 3.8 1/- 18 2/80 Tr 17.5 10.0 400 20 3/16/2009 10335 12.5 75 65 29 30 11/13/14 3.8 1/- 18 2/80 Tr 15 9.8 400 20 3/17/2009 10335 12.5 70 65 27 33 11/13/14 3.6 1/- 18 2/80 Tr 15 9.6 400 20 Abbreviations MW =Mud Weight FL = Water or Filtrate Loss Ca =Hardness Calcium YP =Yield Point Gels =Gel Strength CI =Chlorides PV =Plastic Viscosity FLT =Flow Line Temp Sand =Sand content ECD =Effective Circulating Density VIS =Funnel Viscosity FC =Filter Cake Sols =Solids O/W =Oil to Water ratio ~ EPOCH 20 5 DAILY REPORTS EP~~H 21 ConocoPhillips Alaska Inc. 2N-305A Daily Report • Report for: A. Belanger M.Thorton S. Lapine Date: 2/16/09 Time: 2359hrs Current Depth (MD): 0' Current Depth (TVD): 0' 24 hr Footage (MD): 0' Ilrillinn P~r~mcfore Current Preparing to pull tubing Operations: ROP: Current: n/a Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties ~ 19:00 (Seawater MW: 8.4 FV: 26 PV: YP: FL: Gels: Sol: H: CI- Ca" Temp: 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data - usin tri tank Ditch Gas: Current: Avera e: Max: De th MD/1VD MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Trip Gas none Conn. Gases Other Gas Samples No. De th MD/lVD Units C1 C2 C3 C41 C4N C51 C5N none Lithologies: Current: No new footage drilled Last 24 hrs: Operational Summary: rigging up to pull 3'/" production tubing, testing BOPE. Calibrations: Chromatograph Failures: NONE Daily Cost: $ 3350 • ~ EPOCH m • ConocoPhillips Alaska Inc. 2N-3O5A Daily Report Report for: A. Belanger M. Thorton S. Lapine Date: 2/17/09 Time: 2359hrs Current Depth (MD): 8500' Current p/U scraper Current Depth (TVD): 3200' Operations: 24 hr Footage (MD): 0' flrillinn Paramatarc ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Pro erties 19:00 MW: 9.0 FV: 47 PV: 9 YP: 21 FL: - Gels: 8/9/9 Sol: - H: 10.0 CI- 400 Ca++ 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Avera e: Max: De th MD/lVD (`_~c Cvcn+c MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Trip Gas none Conn. Gases Other Gas Sam les: No. Depth (MD/TVD) Units C1 C2 C3 C41 C4N C51 C5N I I none I I I I I ~ i i i Lithologies: Current: No new footage drilled Last 24 hrs: Operational Summary: Calibrations: Chromatograph Failures: NONE Daily Cost: $ 3985 • ~ EPOCH ConocoPhillips Alaska Inc. 2N-305A Daily Report • Report for: A. Belanger M.Thorton S. Lapine Date: 2/18/09 Time: 2359hrs Current Depth (MD): 8500' Current RIH w/CIBP Current Depth (TVD): 3200' Operations: 24 hr Footage (MD): 0' Ilrillinn P~r~mc+crc ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: SurF-Surf: Strokes: Time: ECD: Current: Max: Mud Properties Cc~ 19:00 MW: 9.0 FV: 45 PV: 9 YP: 20 FL: 9.2 Gels: 8/9/9 Sol: - H: 10.0 CI- 440 Ca+' 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Avera e: Max: De th MD/11/D MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas none Conn. Gases Other 8500' MD 2727 33051 63777 72163 10682 25257 4159 4725 Gas Samples No. De th MD/1VD Units C1 C2 C3 C41 C4N C51 C5N none Lithologies: Current: No new footage drilled Last 24 hrs: Operational Summary: Cont' to RIH w/ scraper on 3.5 tubing t/ 9396', Circ. Bottoms up and POOH. Calibrations: NONE Failures: NONE Daily Cost: $ 3985 :7 ~ EPOCH ConocoPhillips Alaska Inc. 2N-305A Daily Report Report for: A. Belanger M.Thorton S. Lapine Date: 2/19/09 Time: 2359hrs Current Depth (MD): 8500' Current M/U #2 CIBP Current Depth (TVD): 3200' Operations: 24 hr Footage (MD): 0' rlrillinn P~r~mc~crc ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Pro erties 19:00 MW: 9.0 FV: 45 PV: 9 YP: 20 FL: 9.2 Gels: 8/9/9 Sol: - H: 10.0 CI 440 Ca++ 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data (_~e Gvcn+e MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Trip Gas none Conn. Gases Other Gas Sam les: No. Depth (MD/TVD) Units C1 C2 C3 C41 C4N C51 C5N I I none I I I I I I I I i Lithologies: Current: No new footage drilled Last 24 hrs: M/U cement retainer. RIH to 9378' MD. Cement lines. Pfm infectivity test (NO Operational Summary: GO). Pull out of plug and spot cement on Plug 5 bbl H2O, 10 Bbls cement, 3.6 bbls H2O and chase with 73 bbls of seawater. POOH. Lay down #1 running tools, M/U #2 running tools. Calibrations: NONE Failures: NONE Daily Cost: $ 3985 ~ EPOCH ConocoPhillips Alaska Inc. 2N-305A Daily Report • Report for: P.Perfetta M. Thorton S. Lapine Date: 2/20/09 Time: 2359hrs Current Depth (MD): 3400' Current L/D Grapple Assembly Current Depth (TVD): 3400' Operations: 24 hr Footage (MD): 0' f)rillinn ParamatPrc ROP: Current: Max: Tor ue: Current: ~ Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Pro erties 22:30 MW: 9.0 FV: 55 PV: 9 YP: 18 FL: 8.4 Gels: 7/9/9 Sol: 3.5 H: 9.8 CI- 800 Ca+' 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Avera e: Max: De th MD/11/D C~ac Fvontc MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas none Conn. Gases Other 3400' 1756 116086 1095 250 520 555 1422 1384 Gas Sam les: No. De th MD/11/D Units C1 C2 C3 C41 C4N C51 C5N none Lithologies: Current: No new footage drilled Last 24 hrs: Pressure test cement retainer (good). RIH to 3400' MD. Set CIBP and release. Operational Summary: Displace well over to LSND mud. POOH, L/D tubing and running tool. Perform casing test (good). R/U and run SWS, cut at 3370' MD. Attempt to Displace Diesel (cant circulate). R/U to pull casing free (still cant pump). L/D grappling assembly. Calibrations: NONE Failures: NONE Daily Cost: $ 4535 ~i E~QC~ ConocoPhillips Alaska Inc. 2N-305A Daily Report Report for: P. Perfetta • M.Thorton S. Lapine Date: 2/21/09 Time: 2359hrs Current Depth (MD): 3400' Current POOH with casing Current Depth (TVD): 3400' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Pro erties 22:30 MW: 8.9 FV: 47 PV: 9 YP: 18 FL: 6.3 Gels: 6/8/9 Sol: 4 H: 9.5 CI 1000 Ca+' 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Avera e: Max: De th MD/11/D Gas Events MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Trip Gas none Conn. Gases Other Gas Sam les: No. Depth (MD/TVD) Units C1 C2 C3 C41 C4N C51 C5N I I none I I I I I I I I I Lithologies: Current: No new footage drilled Last 24 hrs: Attempt to circulate out 7 5/8" x 5.5" casing at 4 depths. Established circulation in Operational Summary: surface casing shoe. Perform LOT. POOH 5.5" casing to 1300' MD fill pipe every 3 joints Calibrations: NONE Failures: NONE Daily Cost: $ 4535 • ~I EPOCH ConocoPhillips Alaska Inc. • 2N-305A Daily Report Report for: P.Perfetta F. Herbert S. Lapine Date: 2/22/09 Time: 2359hrs Current Depth (MD): 3400' Current P/U 2 7/8" Hydril Current Depth (TVD): 3400' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Pro erties 22:30 MW: 8.9 FV: 47 PV: 9 YP: 18 FL: 6.3 Gels: 6/8/9 Sol: 4 H: 9.5 CI- 1000 Ca" 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Gas Events MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas none Conn. Gases none Other 3400 2230 212711 1360 234 494 505 1049 1035 Gas Sam les: No. De th MD/11/D Units C1 C2 C3 C41 C4N C51 C5N none Lithologies: Current: No new footage drilled Last 24 hrs: Continue to L/D 5.5" casing, filling every 3 joints. R/D 5.5 handling equipment. R/U Operational Summary: to test Hydril and R/D. M/U clean out BHA and RIH to 3020' MD. CBU. POOH to the shoe, CBU wash down to 3384' MD. BROOH to 3020' MD, CBU, L/D BHA and run 2 7/8" hydril. Calibrations: NONE Failures: NONE Daily Cost: $ 4535 • ~ EPOCH ConocoPhillips Alaska Inc. 2N-305A Daily Report Report for: P.Perfetta F. Herbert S. Lapine Date: 2/23/09 Time: 2359hrs Current Depth (MD): 3400' Current Caliper log Current Depth (TVD): 3400' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: - Max: - Tor ue: Current: - Max: - WOB: Current - Max: - RPM: Current: - Max: - PP: Current: - Max: - La Strokes: - Time: - Surf-Surf: Strokes: - Time: - ECD: Current: - Max: - Mud Pro ernes 22:30 MW: 9.0 FV: 50 PV: 6 YP: 18 Gels: 6/7/8 Sol: 3 H: 9.7 CI- 16 MW Change: Depth: From: To: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Avera e: Max: De th MD/11/D • none Comas Fvents FL:~7 aa" 80 Reason: MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Trip Gas none Conn. Gases none Other none Gas Sam les: No. De th MD/l1/D Units C1 C2 C3 C41 C4N C51 C5N none Lithologies: Current: No new footage drilled Last 24 hrs: Continue to run 2 7/8" hydril to 885' MD, P/U and rack back stands of 4" DP. RIH Operational Summary: to 3025' MD, CBU. RIH to 3374' MD, R/U to pump cement while circulating. Pumped cement. POOH to 2995' MD and circulate pipe clean. POOH UD 2 7/8" DP. R/U and run wireline Gamma ray caliper log. Calibrations: NONE Failures: NONE Daily Cost: $ 4535 ~ EPOCH ConocoPhillips Alaska Inc. 2N-3O5A Daily Report Report for: P.Perfetta F. Herbert G. Rizek Date: 2/24/09 Time: 2359hrs Current Depth (MD): 3439' Current DRILLING Current Depth (TVD): 2497' Operations: 24 hr Footage (MD): 421' Drilling Parameters • ROP: Current: 81 Max: 619 Tor ue: Current: 3677 Max: 5265 WOB: Current 9.1 Max: 14 RPM: Current: 121 Max: 123 PP: Current: 1234 Max: 1457 La Strokes: 1058.7 Time: 14.3 Surf-Surf: Strokes: 7219 Time: 97.6 ECD: Current: 10.25 Max: - Mud Properties C~ 23:00 MW: 9.2 FV: 49 PV: 10 YP: 22 FL: 5.2 Gels: 8/11/ Sol: 5 H: 10.5 CI-~ 1500 Ca+" 220 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Current: Average: Max: Depth (MD/TVD): Gas: 103 81.3 362 3030 Gas Events (MD/TVD) Units above C1 C2 C3 C41 C4N C51 C5N back round Conn. Gases 3295 159 N/A N/A N!A N/A N/A N/A N/A MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas none Other none Gas Sam les: No. Depth (MD/TVD) Units C1 C2 C3 C41 C4N C51 C5N I I none I I I I I I I I I Lithologies: Current: Sandstone 40%claystone 30% siltstone 30% Last 24 hrs: Sand 50% sandstone 20% siltstone 20% claystone 10% Check Caliper data (good). R/D wireline. Change and test rams. P/U BHA #3. RIH Operational Summary: to 2917' MD. Slip and cut drill Tine. R/U and test casing. Wash to bottom and drill to 3185' MD. POOH to 3125' MD and perform LOT (EMW 14.2 ppg) ream to bottom and drill to 3457' MD at report time Calibrations: NONE Failures: NONE Daily Cost: $ 4535 ~ EPOCH ConocoPhillips Alaska Inc. 2N-305A Daily Report Report for: P.PerFetta F. Herbert G. Rizek Date: 2!25/09 Time: 2359hrs Current Depth (MD): 3670' Current DRILLING Current Depth (TVD): 2582' Operations: 24 hr Footage (MD): 231' Drilling Parameters ROP: Current: 7 Max: 148 Tor ue: Current: 4276 Max: 5355 WOB: Current 6.1 Max: 20 RPM: Current: 120 Max: 140 PP: Current: 1255 Max: 1645 La Strokes: 1152 Time: 15.3 Surf-Surf: Strokes: 7055 Time: 94.1 ECD: Current: 10.52 Max: - Mud Pro erties 23:00 MW: 9.3 FV: 54 PV: 11 YP: 24 FL: 5.4 Gels: 8/11/13 Sol: 4 H: 8.4 CI-~ 1250 Ca+'~ 160 MW Change: Mud Loss event: Gas Data Depth: Depth: None None From: To: Reason: Volume: Ditch Current: Average: Max: Depth (MD/TVD): Gas: 18 53.6 114 3605' ras Fvpntc (MD/TVD) Units above C1 C2 C3 C41 C4N C51 C5N back round Conn. Gases 3484' 32 N/A N/A N/A N/A N/A N/A N/A 3579' 20 N/A N/A N/A N/A N/A N/A N/A MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas 3663' 281 17313 145 209 137 140 27 34 Other none Gas Sam les: No. Depth (MD/TVD) Units C1 C2 C3 C41 C4N C51 C5N I I none I I I I I I I I I Lithologies: Current: Claystone 70% sand 15% siltstone 15% (Samples highly contaminated with mud additives) Last 24 hrs: Claystone 70% sand 15% siltstone 15% Drill from 3457' MD to 3663' MD. Pumped 30 bbl sweeps to help minimize the Operational Summary: effects of bit balling. Rotated and reciprocated while pumping sweeps to surface. POOH to L/D BHA #3 and P/U BHA #4. RIH. Drilling ahead. Calibrations: NONE Failures: NONE . Daily Cost: $ 4535 ~ EPOCH ConocoPhillips Alaska Inc. 2N-305A Daily Report • Report for: P. Perfetta F. Herbert G. Rizek Date: 3/02/09 Time: 2359hrs Current Depth (MD): 6736' Current Drilling Current Depth (TVD): 3811' Operations: 24 hr Footage (MD): 613' Drilling Parameters ROP: Current: 52 Max: 119 Tor ue: Current: 7537 Max: 8414 WOB: Current 4.1 Max: 8 RPM: Current: 130 Max: 133 PP: Current: 2040 Max: 2417 La Strokes: 2366 Time: 30.1 Surf-Surf: Strokes: 8835 Time: 113.3 ECD: Current: 10.55 Max: - Mud Pro ernes 23:00 MW: 9.3 FV: 53 PV: 14 YP: 22 FL: 4.5 Gels: 9/14/19 Sol: 6 H: 9.4 CI"~ 800 Ca"~ 60 MW Change: Mud Loss event: Gas Data Depth: Depth: None None From: To: Reason: Volume: Ditch Current: Average: Max: Depth (MD/TVD): Gas: 27 8 34 6717 Gas Events (MD/TVD) Units above C1 C2 C3 C41 C4N C51 C5N back round Conn. Gases none MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas none Other none Gas Sam les: No. De th MD/TVD Units C1 C2 C3 C41 C4N C51 C5N none Lithologies: Current: Siltstone 40% sandstone 40% claystone 20% Last 24 hrs: Siltstone 40% sandstone 40% claystone 20% Weather conditions improved and drilling operations continued. P/U BHA and RIH with 4" DP. CBU at 4520' MD and 6123' MD. Drilling ahead from 6736' MD at Operational Summary: report time. NOTE: From approximately 18:00 to 23:30 Epoch had to shut down and rig down in order to move the logging to allow Haliburton access to a well house. Calibrations: NONE Failures: NONE Daily Cost: $ 4535 ~ EPOCH ConocoPhillips Alaska Inc. 2N-305A Daily Report Report for: P. Perfetta M.Thorton G. Rizek Date: 3/03/09 Time: 2359hrs Current Depth (MD): 7700' Current Drilling Current Depth (TVD): 4197' Operations: 24 hr Footage (MD): 964' Drillinn ParamPtPrs ROP: Current: 76 Max: 127 Tor ue: Current: 8311 Max: 9831 WOB: Current 3.2 Max: 9 RPM: Current: 132 Max: 134 PP: Current: 2234 Max: 2410 La Strokes: 2714 Time: 34.8 Surf-Surf: Strokes: 9649 Time: 123.7 ECD: Current: 10.29 Max: - Mud Pro erties 23:00 MW: 9.3 FV: 49 PV: 11 YP: 18 FL: 4.8 Gels: 6/8/12 Sol: 6 H: 9.5 CI-` 800 Ca'+` 80 MW Change: Mud Loss event: Gas Data Depth: Depth: None None From: To: Reason: Volume: Ditch Current: Average: Max: Depth (MD/TVD): Gas: 65 40.8 100 7636' Gas Events (MD/TVD) Units above C1 C2 C3 C41 C4N C51 C5N back round Conn. Gases 7543 33 n/a n/a n/a n/a n!a n/a n/a 7636 63 n/a n/a n/a n/a n/a n/a n/a MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas none Other none Gas Samnles~ No. De th MD/TVD Units C1 C2 C3 C41 C4N C51 C5N 7000 32 5614 82 7500 60 8609 283 428 Lithologies: Current: Siltstone 40% sandstone 30%claystone 30% Last 24 hrs: Siltstone 40% sandstone 20% claystone 20% shale 20% Operational Summary: Drilled ahead from 6736' MD to 7700' MD at report time. Calibrations: NONE Failures: NONE Daily Cost: $ 4535 ~ EPOCH ConocoPhillips Alaska Inc. 2N-3O5A Daily Report Report for: P. Perfetta .] r M.Thorton G. Rizek Date: 3/04/09 Time: 2359hrs Current Depth (MD): 8978' Current Drilling Current Depth (TVD): 4718' Operations: 24 hr Footage (MD): 1278' Drilling Parameters ROP: Current: 53 Max: 136 Tor ue: Current: 9105 Max: 11792 WOB: Current 6.7 Max: 12 RPM: Current: 130 Max: 137 PP: Current: 2809 Max: 2889 La Strokes: 3209 Time: 40.6 Surf-Surf: Strokes: 9278 Time: 117.4 ECD: Current: 10.29 Max: - Mud Pro erties 23:00 MW: 10.4 FV: 45 PV: 14 YP: 15 FL: 4.4 Gels: 4/6/8 Sol: 7 H: 9.5 CI ' 600 Ca+''` 60 MW Change: Mud Loss event: Gas Data Depth: Depth: None None From: To: Reason: Volume: Ditch Current: Average: Max: Depth (MD/TVD): Gas: 35 61 510 8457 Gas Events (MD/TVD) Units above back round C1 C2 C3 C41 C4N C51 C5N Conn. Gases 7731 57 n/a n/a n/a n/a n/a n/a n/a 7826 38 n/a n/a n/a n/a n/a n/a n/a 8581 9 n/a n!a n/a n/a n/a n/a n/a 8961 17 n/a n/a n/a n/a n/a n/a n/a MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas none Other none Gas Samples: No. De th MD/TVD Units C1 C2 C3 C41 C4N C51 C5N 8000 24 3243 169 303 8500 47 5831 308 131 Lithologies: Current: Sandstone 60% sand 30% siltstone 10% Last 24 hrs: Sandstone 60% sand 30% siltstone 10% Operational Summary: Drilled ahead from 7700' MD to 8978' MD at report time. Calibrations: NONE Failures: NONE El" ~~~ Daily Cost: $ 4535 ~J • EPOCH ConocoPhillips Alaska Inc. 2N-305A Daily Report Report for: P. Perfetta M. Thorton G. Rizek Date: 3/05/09 Time: 2359hrs Current Depth (MD): 9323' Current Drilling Current Depth (TVD): 4718' Operations: 24 hr Footage (MD): 1278' Drilling Parameters l~.J • ROP: Current: - Max: 110 Tor ue: Current: - Max: 11272 WOB: Current - Max: 10 RPM: Current: - Max: 135 PP: Current: - Max: 3170 La Strokes: 3392 Time: 44.9 Surf-Surf: Strokes: 8601 Time: 107.5 ECD: Current: 10.47 Max: - Mud Pro erties 23:00 MW: 9.7 FV: 48 PV: 11 YP: 17 FL: 5.2 Gels: 4/6/8 Sol: 7 H: 9.5 CI-~ 500 Ca++~ 40 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: 9323' Volume: Lost 12% of flow out Gas Data Ditch Gas: Current: Average: Max: Depth (MD/TVD): - 30.4 58 9052' Gas Events (MD/TVD) Units above C1 C2 C3 C41 C4N C51 CSN back round Conn. Gases none MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas 9323 425 44835 348 406 9323 680 75184 837 141 Gas Sam les: No. De th MD/TVD Units C1 C2 C3 C41 C4N C51 C5N 9000' 33 4096 176 Lithologies: Current: Sandstone 90% siltstone 10% Last 24 hrs: Ssandstone 80% siltstone 20% Drilled ahead from 8978' MD to 9323' MD. Lost 12% flow out. Check flow -falling steady. Monitor well. Static losses 30-40 BPH. Lost full returns. Pumped 60 bbls Operational Summary: 20 ppb LCM sweep. Regained partial returns. Pumped second LCM sweep. Lost full returns. Built dry job, attempt to POOH, swabbing, pump out of hole to establish circulation and begin reducing mud weight. Staging in hole 9.7 ppg. Calibrations: NONE Failures: NONE Daily Cost: $ 4610 ~ EPOCH ConocoPhillips Alaska Inc. 2N-305A Daily Report • Report for: P. Perfetta M.Thorton G. Rizek Date: 3/06/09 Time: 2359hrs Current Depth (MD): 9783' Current POOH Current Depth (TVD): 5115' Operations: 24 hr Footage (MD): 460' rlrillinn P~rnmc+nrc ROP: Current: - Max: 269 Tor ue: Current: - Max: 12161 WOB: Current - Max: 16 RPM: Current: - Max: 133 PP: Current: - Max: 3110 La Strokes: 3572 Time: 46 Surf-Surf: Strokes: 8601 Time: 107.5 ECD: Current: 9.7 Max: - Mud Pro erties 23:00 MW: 9.7 FV: 53 PV: 15 YP: 21 FL: 4.2 Gels: 6/8/10 Sol: 8 H: 9.3 CI-~ 500 Ca++~ 40 MW Change: Mud Loss event: Gas Data Depth: None Depth: From: To: Reason: Volume: Ditch Current: Average: Max: Depth (MD/TVD): Gas: - 61.7 232 9464' (MD/TVD) Units above back round C1 C2 C3 C41 C4N C51 C5N Conn. Gases none MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas 9323 305 Gas Sam les: No. De th MD/TVD Units C1 C2 C3 C41 C4N C51 C5N 9500 74 9176 407 212 Lithologies: Current: Sandstone 50% siltstone 40% shale 10% Last 24 hrs: Sandstone 50% siltstone 40% shale 10% Operational Summary: Drilled to 9783' MD and CBU. Condition mud to 9.7 ppg. Monitor well (static). Pumped dry job and POOH. Calibrations: NONE Failures: NONE Daily Cost: $ 4610 E~Q~~ IP'1 ~~ ConocoPhillips Alaska Inc. 2N-305A Daily Report Report for: P. Perfetta M. Thorton G. Rizek Date: 3/07/09 Time: 2359hrs Current Depth (MD): 9783' Current RIH with 5 Y2" casing Current Depth (TVD): 5115' Operations: 24 hr Footage (MD): 0' rlrillinn Parama+prc ROP: Current: - Max: - Tor ue: Current: - Max: - WOB: Current - Max: - RPM: Current: - Max: - PP: Current: - Max: - La Strokes: - Time: - Surf-Surf: Strokes: - Time: - ECD: Current: - Max: - Mud Properties Ca) 23:00 MW: 9.7 FV: 54 PV: 17 YP: 18 FL: 4.5 Gels: 6/8/10 Sol: 8 H: 9.7 CI"~ 400 Ca'+` 40 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Current: Average: Max: Depth (MD/TVD): Gas: r_~~ G.,o.,+~ (MD/TVD) Units above back round C1 C2 C3 C41 C4N C51 C5N Conn. Gases none MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas none Gas Sam les: No. De th MD/TVD Units C1 C2 C3 C41 C4N C51 C5N none Lithologies: Current: No new footage drilled Last 24 hrs: Operational Summary: Laying down 4" DP and cut and slip drill line. L/D BHA and R/U for casing run. Currently RIH with 5 / casing at report time. Calibrations: NONE Failures: NONE Daily Cost: $ 4610 • ~ EPOCH ConocoPhillips Alaska Inc. 2N-305A Daily Report • Report for: P. Perfetta M. Thorton G. Rizek Date: 3/08/09 Time: 2359hrs Current Depth (MD): 9923' Current Circulating Current Depth (TVD): 5219' Operations: 24 hr Footage (MD): 140' rlrillinn Paramc+nrc ROP: Current: - Max: 64 Tor ue: Current: - Max: 11516 WOB: Current - Max: 8 RPM: Current: - Max: 85 PP: Current: - Max: 938 La Strokes: 2226 Time: 85.6 Surf-Surf: Strokes: 8408 Time: 323.4 ECD: Current: 11.36 Max: - Mud Properties Caa 23:00 MW: 9.7 FV: 52 PV: 15 YP: 14 FL: 3.8 Gels: 5/7/9 Sol: 8 H: 9.5 CI-~ 400 Ca"` 40 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: Volume: C:ac rlafa Ditch w Current: Average: Max: Depth (MD/TVD): Gas: 28 38 67 9897' (MD/TVD) Units above back round C1 C2 C3 C41 C4N C51 C5N Conn. Gases none Gas Sam les: No. De th MD/TVD Units C1 C2 C3 C41 C4N C51 C5N none Lithologies: Current: No new footage drilled Last 24 hrs: Continued RIH with 5'/" casing. CBU at 5406 and lost 80 bbls. Shut off pumps Operational Summary: and gained 40 bbls in returns. Circulated again and lost an average of 20-25 bbl/hr. RIH and drilled from 9783' MD to 9923' MD. CBU and prep for LOT. MD/TVD Units C1 C2 C3 C41 C4N C51 CSN Tri Gas 9783' 235 n/a n/a n/a n/a n!a n/a n/a 9923' 102 n/a n/a n/a n/a n/a n/a n/a Calibrations: NONE Failures: NONE Daily Cost: $ 4610 ~ EPOCH ConocoPhillips Alaska Inc. 2N-305A Daily Report Report for: P. Perfetta M.Thorton G. Rizek Date: 3/09/09 Time: 2359hrs Current Depth (MD): 9923' Current Nipple down stack Current Depth (TVD): 5219' Operations: 24 hr Footage (MD): 0' rlrillinn D~~~rr~n+nrc ROP: Current: - Max: - Tor ue: Current: - Max: - WOB: Current - Max: - RPM: Current: - Max: - PP: Current: - Max: - La Strokes: - Time: - Surf-Surf: Strokes: - Time: - ECD: Current: 9.7 Max: - Mud Properties L'a) 23:00 MW: 9.7 FV: 54 PV: 17 YP: 16 FL: 3.8 Gels: 4/6/8 Sol: 7 H: 9.5 CI-~ 400 Ca'+~ 40 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Current: Average: Max: Depth (MD/TVD): Gas: roc Gvnn+c (MD/TVD) Units above back round C1 C2 C3 C41 C4N C51 C5N Conn. Gases none MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas 9923' 110 n/a n/a n/a n/a n/a n/a n/a Gas Sam les: No. De th MD/TVD Units C1 C2 C3 C41 C4N C51 C5N none Lithologies: Current: No new footage drilled Last 24 hrs: Operational Summary: R/U cement equipment, cement casing. R/D cementing equipment. Currently preparing rig for drilling production hole. Calibrations: NONE Failures: NONE Daily Cost: $ 4610 • EPOCH ConocoPhillips Alaska Inc. 2N-3O5A Daily Report Report for: P. Perfetta M. Thorton G. Rizek Date: 3/10/09 Time: 2359hrs Current Depth (MD): 9923' Current RIH w/ BHA #7 Current Depth (TVD): 5219' Operations: 24 hr Footage (MD): 0' rlrillinn D~r~mn4nrc ROP: Current: - Max: - Tor ue: Current: - Max: - WOB: Current - Max: - RPM: Current: - Max: - PP: Current: - Max: - La Strokes: - Time: - Surf-Surf: Strokes: - Time: - ECD: Current: 9.7 Max: - Mud Properties Ca) 23:00 MW: 12.0 FV: 49 PV: 17 YP: 16 FL: 4.2 Gels: 4/5/6 Sol: 9 H: 9.2 CI-~ 400 Ca++` 20 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Current: Average: Max: Depth (MD/TVD): Gas: (~~c Gvcn+c MD/TVD ( ) Units above back round C1 C2 C3 C41 C4N C51 C5N Conn. Gases none (MD/TVD) Units ~ C1 ~ C2 ~ C3 ~ C41 ~ C4N ~ C51 ~ C5N ~ Gas I none Gas Samples: No. De th MD/TVD Units C1 C2 C3 C41 C4N C51 C5N none Lithologies: Current: No new footage drilled Last 24 hrs: Operational Summary: Set stack. Perform infectivity test and test BOPE. P/U BHA and RIH w/ 2 7/8" DP at report time. Calibrations: NONE Failures: NONE Daily Cost: $ 4710 • ~ E~ocH ConocoPhillips Alaska Inc. 2N-3O5A Daily Report Report for: P. Perfetta M. Thorton M. Brouillet Date: 3/11/09 Time: 2359hrs Current Depth (MD): 9943' Current Circulating Current Depth (TVD): 5223' Operations: 24 hr Footage (MD): 20' rlrillinn Parama+arc ROP: Current: - Max: 37.7 Tor ue: Current: - Max: 10017 WOB: Current - Max: 10 RPM: Current: - Max: 82 PP: Current: - Max: 2710 La Strokes: 1765 Time: 65.4 Surf-Surf: Strokes: 9970 Time: 369.2 ECD: Current: 11.15 Max: - Mud Properties (a~ 23:00 MW: 9.7 FV: 48 PV: 11 YP: 15 FL: 4.8 Gels: 4/6/8 Sol: 7 H: 9.2 CI"~ 400 Ca+'~ 20 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: Volume: f~ac r)afa Ditch Current: Average: Max: Depth (MD/TVD): Gas: - 7 37 9924' r_~~ c.,en*~ (MD/TVD) Units above back round C1 C2 C3 C41 C4N C51 C5N Conn. Gases none MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas 9923' 134 n/a n/a n/a n/a n/a n/a n/a Gas Sam les: No. De th MD/TVD Units C1 C2 C3 C41 C4N C51 C5N none Lithologies: Current: No new footage drilled Last 24 hrs: Operational Summary: Finished picking up BHA and 2 7/8" DP. Tagged at 9840' MD. Drilled float equipment, cement and 20' of new hole. CBU at report time Calibrations: NONE Failures: NONE Daily Cost: $ 4610 E~~C~ ConocoPhillips Alaska Inc. 2N-305A Daily Report Report for: P. Perfetta M. Thorton M. Brouillet Date: 3/12/09 Time: 2359hrs Current Depth (MD): 9943' Current Prep for mud Current Depth (TVD): 5223' Operations: displacement 24 hr Footage (MD): 0' rlrillinn Parama+arc • ROP: Current: - Max: - Tor ue: Current: - Max: - WOB: Current - Max: - RPM: Current: - Max: - PP: Current: - Max: - La Strokes: 1758 Time: 54.9 Surf-Surf: Strokes: 10255 Time: 320.5 ECD: Current: 11.37 Max: - Mud Properties Ccia 23:00 MW: 9.7 FV: 48 PV: 12 YP: 14 FL: 4.8 Gels: 4/6/8 Sol: 7 H: 9.2 CI"~ 400 Ca++~ 20 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Current: Average: Max: Depth (MD/TVD): Gas: (~~c Cvnn4c (MD/TVD) Units above back round C1 C2 C3 C41 C4N C51 C5N Conn. Gases none (MD/TVD) Units C1 ~ C2 ~ C3 ~ C41 ~ C4N ~ C51_ ~ C5N ~ Trip Gas ~ none I I I I I I I ( I Gas Sam les: No. De th MD/TVD Units C1 C2 C3 C41 C4N C51 C5N none Lithologies: Current: No new footage drilled Last 24 hrs: Circulated bottom's up and then performed LOT. Mud wt. 9.7 ppg showed 17.5 Operational Summary: EMW. Monitored well (static), pumped 32.0 ppg dry job before POOH with 2 7/8" DP. Laid down BHA for BHA #8 with 4 / PDC. RIH and preparing to displace 9.7 #/gal mud to 12.0 #/gal LSND @ report time. Calibrations: NONE Failures: NONE Daily Cost: $ 4610 ~ EPOCH ConocoPhillips Alaska Inc. 2N-305A Daily Report Report for: P. Perfetta M.Thorton M. Brouillet Date: 3/13/09 Time: 2359hrs Current Depth (MD): 10262' Current Current Depth 5455' Operations: Drilling (TVD): 24 hr Footage (MD): 319' nrillinn D~r~mn+nrc ROP: Current: 13 Max: 44.8 Tor ue: Current: 3445 Max: 5117 WOB: Current 11 Max: 16 RPM: Current: 56 Max: 67 PP: Current: 3655 Max: 4365 La Strokes: 1805 Time: 56.4 Surf-Surf: Strokes: 9069 Time: 283.4 ECD: Current: 14.56 Max: - Mud Pro erties 23:00 MW: 12.0 FV: 52 PV: 19 YP: 23 FL: 3.8 Gels: 7/9/11 Sol: 15 H: 9.3 CI"~ 400 Ca++` tr MW Change: Mud Loss event: (.`.ac na+a Depth: None Depth: From: To: Reason: Volume: Ditch M Current: Average: Max: Depth (MD/TVD): Gas: 55 119.6 1444 10105' MD r_.,~ o.,e..+~ (MD/TVD) Units above back round C1 C2 C3 C41 C4N C51 CSN Conn. Gases 10071' 641 n/a n/a n/a n/a n/a n/a n/a 10133' 709 n/a n/a n/a n!a n/a n/a n/a 10228' 1396 n/a n/a n/a n/a n/a n/a n/a MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas none Other 10262' 1447 97592 18650 15224 3027 6822 1208 1413 10265' 1950 51801 21944 31955 8331 21082 4322 5325 C:ac Samnloc• • No. MD/TVD Units No. MD/TVD Units 9950 16 10150 78 9970 16 10180 38 10000 14 10200 29 10030 14 10229 1412 10060 140 10262 1447 10090 469 10265 1950 10120 442 Lithologies: Current: Sandstone 90% siltstone 10% Last 24 hrs: Sandstone 90% siltstone 10% ~ EPOCH TIH t/9940' MD and monitored well (static). PJSM for reservoir drilling and mud Operational Summary: displacement. Displaced 9.7 ppg to 12.0 ppg LSND. Monitored well (static) drilling to TD at report time. Calibrations: NONE Failures: NONE Daily Cost: $ 4610 E~QC~ ConocoPhillips Alaska Inc. 2N-3O5A Daily Report Report for: P. Pertetta M.Thorton M. Brouillet Date: 3/14/09 Time: 2359hrs Current Depth (MD): 10335' Current Weighting mud up to Current Depth 5509' Operations: 12.5 ppg (TVD): 24 hr Footage (MD): 73' rlrillinn Paramo+arc ROP: Current: - Max: 43.2 Tor ue: Current: - Max: 4609 WOB: Current - Max: 1705 RPM: Current: - Max: 74 PP: Current: - Max: 4408 La Strokes: 1835 Time: 70.6 Surf-Surf: Strokes: 8653 Time: 332.8 ECD: Current: 15.47 Max: - Mud Properties Cad 23:00 MW: 12.2 FV: 56 PV: 28 YP: 27 FL: 3.8 Gels: 9/13/15 Sol: 18 H: 10.2 CI"~ 400 Ca++~ 20 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: Volume: C~ac ^ata Ditch Current: Average: Max: Depth (MD/TVD): Gas: 55 201.7 1326 10265' MD (MD/TVD) Units above C1 C2 C3 C41 C4N C51 C5N back round Conn. Gases as Events MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas none Other 10335' 1444 98752 17565 15534 3521 6822 1204 1486 Gas Samples: No. Depth Units MD/TVD 10300 142 10335 53 Lithologies: Current: Sandstone 60% siltstone 40% Last 24 hrs: Sandstone 60% siltstone 40% Drilled to 10335' MD and called TD. Circulated and conditioned mud. Monitor well Operational Summary: (static). BROOH and CBU @ 9913' MD. Monitored well (static). Serviced rig. TIH to circulate and condition. Gas in returns. Weighting up mud from 12.2 ppg to 12.5 ppg at report time. Calibrations: NONE Failures: NONE Daily Cost: $ 4610 ~ EPOCH ConocoPhillips Alaska Inc. 2N-3O5A Daily Report Report for: P. Perfetta M. Thorton M. Brouillet Date: 3/15/09 Time: 2359hrs Current Depth (MD): 10335' Current Current Depth 5509' Operations: Circulating at 3838' (TVD): 24 hr Footage (MD): 0' r)rillinn Parama+ars Mud Properties @ 23:00 MW: 12.5 FV: 64 PV: 29 YP: 33 FL: 3.8 Gels: 11/15/17 Sol: 18 pH: 10.0 CI ~ 400 Ca ~ 20 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: Volume: C,as Data ROP: Current: - Max: 43.2 Torque: Current: - Max: 4609 WOB: Current - Max: 1705 RPM: Current: - Max: 74 PP: Current: - Max: 4408 Lag: Strokes: 1835 Time: 70.6 Surf-Surf: Strokes: 8653 Time: 332.8 ECD: Current: 15.47 Max: - Ditch _ Current: Average: Max: Depth (MD/TVD): Gas: 55 201.7 1326 10265' MD ias Events • (MD/TVD) Units above C1 C2 C3 C41 C4N C51 C5N background Conn. Gases (MD/TVD) Units C1 C2 C3 C41 C4N C51 C5N Trip Gas none Other 10335' 1444 98752 17565 15534 3521 6822 1204 1486 Gas Samples: No. Depth Units (MD/TVD) 10300 142 10335 53 Lithologies: Current: Sandstone 60% siltstone 40% Last 24 hrs: Sandstone 60% siltstone 40% Monitor well (static). BROOH and CBU @ 9913' MD. Monitored well (static). Operational Summary: Serviced rig. TIH to circulate and condition. Gas in returns. Mud at 12.5 ppg at report time. Calibrations: NONE Failures: NONE Daily Cost: $ 4610 ~~~~~ ConocoPhillips Alaska Inc. 2N-3O5A Daily Report Report for: P. Perfetta M.Thorton M. Brouillet Date: 3/16/09 Time: 2359hrs Current Depth (MD): 10335' Current Tripping tubing into the Current Depth 5509' Operations: hole. (TVD): 24 hr Footage (MD): 0' rlrillinn P~r~mntnrc Ditch Current: Average: Max: Depth (MD/TVD): Gas: Mud Pro erties 23:00 MW: 12.5 FV: 65 PV: 29 YP: 30 FL: 3.8 Gels: 11/13/14 Sol: 18 H: 9.8 CI ~ 400 Ca`+~ 20 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: Volume: Gas Data ROP: Current: - Max: 43.2 Tor ue: Current: - Max: 4609 WOB: Current - Max: 1705 RPM: Current: - Max: 74 PP: Current: - Max: 4408 La Strokes: 1835 Time: 70.6 Surf-Surf: Strokes: 8653 Time: 332.8 ECD: Current: 15.47 Max: - as Events • MD/TVD Units above C1 C2 C3 C41 C4N C51 C5N ( ~ back round Conn. Gases Gas Sam les: No. Depth Units MD/TVD Lithologies: Current: Sandstone 60% siltstone 40% Last 24 hrs: Sandstone 60% siltstone 40% Monitor well (static). BROOH and CBU @ 9913' MD. Monitored well (static). Operational Summary: Serviced rig. TIH to circulate and condition. Gas in returns. Mud at 12.5 ppg at report time. NOTE: Sample catchers are gone. MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas none Other 1060' 390 Calibrations: NONE Failures: NONE Daily Cost: $ 3510 ~~~~~ ConocoPhillips Alaska Inc. 2N-305A Daily Report Report for: P. PerFetta M.Thorton M. Brouillet Date: 3/17/09 Time: 2359hrs Current Depth (MD): 10335' Current Tripping out after Current Depth 5509' Operations: cementing casing (TVD): 24 hr Footage (MD): 0' rlrillinn P~~~mctcrc • • ROP: ~ Current: - Max: 43.2 Torque: Current: - Max: 4609 WOB: Current Max: 1705 RPM: Current: - Max: 74 PP: Current: - Max: 4408 Lag: Strokes: 1835 Time: 70.6 Surf-Surf: Strokes: 8653 Time: 332.8 ECD: Current: 15.47 Max: - Mud Properties 23:00 MW: 12.5 FV: 65 PV: 27 YP: 33 FL: 3.6 Gels: 11/13/14 Sol: 18 pH: 9.6 CI"~ 400 Ca ~ 20 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Current: Average: Max: Depth (MD/TVD): Gas: (MD/TVD) Units above C1 C2 C3 C41 C4N C51 C5N background Conn. Gases as Events (MD/TVD) Units C1 C2 C3 C41 C4N C51 C5N Trip Gas none Other 10450' 823 Gas Samples: No. Depth Units (MD/TVD) Lithologies: Current: Sandstone 60% siltstone 40% Last 24 hrs: Sandstone 60% siltstone 40% Monitor well (static). BROOH and CBU @ 9913' MD. Monitored well (static). Operational Summary: Serviced rig. TIH to circulate and condition. Gas in returns. Mud at 12.5 ppg at report time. NOTE: Sample catchers are gone. Calibrations: NONE Failures: NONE Daily Cost: $ 3510 EPOCH
