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210-045
• 0 Image File Cover Page Project Well History e � ry 9 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. QL Q - 0 4 Well History File Identifier Organizing (done) ❑ Two -sided III 111111 III ❑ Rescan Needed 11 1111111 llI 1 RE AN DIGITAL DATA OVERSIZED (Scannable) /Greyscale Color Items: ❑ Diskettes, No. ❑ Maps: Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: rn1 ❑ Other:: BY: Date: o. /s/ Ill P Project "ect Proofin II I'I 1111 1111 Proofing BY: Maria Date: 97 /o` /s/ rJP f Scanning Preparation 1 x 30 = 30 + 3 = TOTAL PAGES 3 3 (� 7 ! (Count does not include cover sheet) f ry i BY: Maria Date: /s/ Production Scanning I Stage 1 Page Count from Scanned File: 3 (Count does include cover sheet) Page Count Matches Number in Scanning Pre aration: 1, YES NO BY: 410, Date: 60/9...7 / a— /s/ p Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. ll I ReScanned 111111111E III I BY: Maria Date: /s/ Comments about this file: Quality Checked I 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 6/18/2012 Permit to Drill 2100450 Well Name /No. KUPARUK RIV UNIT 3K -09BL2 -01 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 029 - 21656 -62 -00 MD 8955 TVD 6765 Completion Date 6/12/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Sur< DATA INFORMATION Types Electric or Other Logs Run: GR / RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type NJed /Frmt Number Name Scale Media No Start Stop CH Received Comments ED C Lis 19908 Induction /Resistivity 6690 8895 Open 7/27/2010 GR, ROP, RES Log L„-- Induction /Resistivity 2 Col 7150 8895 Open 7/27/2010 MD MPR, GR Log Induction /Resistivity 5 Col 7150 8895 Open 7/27/2010 MD MPR, GR Log — Induction /Resistivity 5 Col 7150 8895 Open 7/27/2010 TVD MPR, GR ED' / C Directional Survey 7740 8955 Open Rpt Directional Survey 7740 8955 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? U Daily History Received? ) 1` N Chips Received? Formation Tops 6/ N Analysis ✓ "- Received? L Comments: Compliance Reviewed By: \- Date: 1 O) Wes- . '- k Z— • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil 0 Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ lb. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 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. orAband.: June 12, 2010 210 - 0450 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 June 6, 2010 50 029 - 21656 - 62 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1234' FSL, 317' FWL, Sec. 35, T13N, R9E, UM June 8, 2010 3K 09BL2 - 01 Top of Productive Horizon: 8. KB (ft above MSL): 69' RKB 15. Field /Pool(s): 927' FSL, 2109' FWL, Sec. 35, T13N, R9E, UM GL (ft above MSL): 30' Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 21' FNL, 877' FWL, Sec. 1, T12N, R9E, UM 8955' MD / 6765' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 529306 y 6008229 Zone 4 8955' MD / 6765' TVD ADL 25519, 25629 TPI: x - 531099 y - 6007928 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 530396 y - 6006977 Zone 4 2183' MD / 2183' TVD 2555, 2562 18. Directional Survey: Yes 0 No ❑ 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) 1700' MD / 1700' 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 GR/Res . 7749' MD / 6770' TVD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 110' Surf. 110' 24" 1540# Poleset 10.75" 45.5# K -55 Surf. 3172' Surf. 3169' 13.5" 1400 sx AS IV, 125 sx Class G 7" 26# J -55 Surf. 7559' Surf. 6962' 8.5" 910 sx Class G, 175 sx AS I 2.375" 4.7# L -80 6965' 8955' 6456' 6765' 3" solid /slotted liner I 24. Open to production or injection? Yes No P P 1 � ❑ If Yes list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 7050' 6936' MD / 6431' TVD alternating solid / slotted liner from: 6969' - 7164' MD 6459' - 6625' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7320' - 8954' MD 6758' - 6764' TVD COMPLETION DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED f n 033' 17 ppg cement i .. ' +• I_ J AMY 1411iIiiii 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 24, 2010 gas lift oil Date of Test Hours Tested Production for OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GAS - OIL RATIO 6/28/2010 20 hours Test Period - -> 1192 363 50 5 Bean 388 Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 515 psi 30.5 24 -Hour Rate -> 1313 510 _ 59 21.5 deg 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. RECEIVED NONE JUL f ,q GL I.i RE-3DMS ,I�l(� 0 3 417-7 0f & Gas Cons. Commis ; a f Ancherage Form 10-407 Revised 12/2009 • NTINUED ON REVERSE �,L l0 Submit original only 6 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 1700' 1700' needed, and submit detailed test information per 20 AAC 25.071. Top A 8060' 6758' N/A Formation at total depth: Kuparuk A3 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger @ 265 - 1102 ye - 7 x //O Printed N e V. Ca Title: Alaska Wells Manager � / , � t _ A ,� Signature Phone 265 - 6306 Date 7�` Sharon Allsup -Drake 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 la: 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 r KU III 3K- 09BL2 -01 C ocorhii� Well Attributes _ -- Max Angle & MD TD ( " Well8ore APUDWI Feld Name Well Status Inc! (1 MD (ft0B) Act Btm (ftKB) 0 ' 6 `" 500292165662 KUPARUK RIVER UNIT PROD Comment H2S(ppm) D to Annotation End Date KB - Grd (ft) Rig Release Date wen Conag 3K 95,R -01 01010[ AM SSSV TRDP _ 120 2/23/2009 Last WO: 6/17 2010 39.90 10/17/1986 A nnotation l De h RKB End Date Annotation — 0 ;Last Mod .. . End Date $clrema_AGNaI Pt ( I I I Last Tag _ _ _ 6/17/2010 Rev Reason SIDETRACK, GLV C/O Imosbor 6/17/2010 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 13L2 -01 LINER 2 3/8 1.992 6,962.5 8,955.0 4.70 L -80 STL Liner Details Top Depth (TVD) Top Ind Nomi... Top (ftKB) (ftKB) (1 Item Description Comment ID (in) 6,962.5 DEPLOY DEPLOYMENT SLEEVE 1.992 ,.. Perforations & Slots Shot Top (TVD) Min (TVD) Dens 4 Top (MKB) Ban (ftKB) (MB) (ftKB) Zone Dale (sh -. Type Comment 6,969 7,164 6/8/2010 SLOT Alternating solid /slotted pipe - 0.125 "x2.5" @ 4 circumferential HANGER, 35 adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends 7,320 8,954 6/8/2010 SLOT Altemating solid /slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends Notes: General & SafetV 4 --: End Date Annotation ,, 16/17/2010 INOTE' VIEW SCHEMATIC w /Alaska Schematic9 0 CONDUCTOR, - 36 -110 SURFACE, 37 -3,172 TD (3K- 0966.241), 3,172 SLOT„ 6,969 -7,164 PRODUCTION, . � :.. ' 35 -7,559 tii 7 1 r L V 8 t I i nee SLOT, I _." Mandrel rye --- - -__._ 7.320 -8.954 Man �._ dre Details tz.,.. + -- Top Depth Top ___. >_._... Port (TVD) Inc! OD Valve Latch Size TRO Run - Stn Top(pK6) (ftKB) (°) Make Model (in) Sere Tyr ( (Psi) Run Date Corn... 1 2,396.3 CAMCO MMG 1 12 GAS LIFT GLV R -20 0.188 1,339.0 6/16/2010 2 3,532.7 CAMCO MMG 1 12 GAS LIFT GLV R -20 0.188 1,320.0 6/16/2010 3 4,606.5 CAMCO MMG 1 12 GAS LIFT GLV R -20 0.188 1,302.0 6/16/2010 4 5,586.4 CAMCO MMG 1 1/2 GAS LIFT OV rdo-20 0.250 0.0 6/16/2010 5 6,307.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/2/2008 6 6,839.0 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 4/13/2010 66.2 -01 LINER, _. 6,963 -6,955 ConochiIIips Alaska s • ConocoPhilli Alaska p� ) Inc. Kuparuk River Unit Kuparuk 3K Pad 3K- 09BL2 -01 50- 029 - 21656 -62 Baker Hughes INTEQ WM • Definitive Survey Report BAKER y p HUGHES 22 June, 2010 ConocoPhillips - E ConocoPhillips Definitive Survey Report KE R Alaska r I Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 3K - 09 I Project: Kuparuk River Unit TVD Reference: 3K -09 @ 69.00ft (3K -09) Site: Kuparuk 3K Pad MD Reference: 3K -09 @ 69.00ft (3K -09) Well: 3K - 09 North Reference: TRUE Wellbore: 3K - 09 Survey Calculation Method: Minimum Curvature Design: 3K -09 Database: EDM Alaska Prod v16 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 3K -09 Well Position +N/ 0.00 ft Northing: 6,008,228.65ft Latitude: 70° 26' 0.812 N +E/ - 0.00 ft Easting: 529,305.92ft Longitude: 149° 45' 39.960 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 3K 09BL2 - 01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( °) ( °) (nT) BGGM2009 7/15/2010 17.14 79.87 57,394 Design 3K- 09BL2 -01 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,740.33 Vertical Section: Depth From (TVD) +N/-S +E/.W Direction • (ft) (ft) (ft) (1 69.00 0.00 0.00 139.16 i Survey Program From (ft) Date To Survey Survey (ft) Survey (Wellbore) Tool Name Description Staff Date End Date 100.00 7,150.00 3K -09A GyroData (3K -09A) GYD -CT -CMS Description to cont.casing m/s 3/9/2009 7,180.09 7,740.33 3K -096L2 (3K- 096L2) MWD MWD - Standard 6/3/2010 6/4/2010 7,749.00 8,915.57 3K- 096L2 -01 (3K- 09BL2 -01) MWD MWD - Standard 6/6/2010 6/8/2010 6/22/2010 8:19:56AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips E'EN Conoco Phillips Definitive Survey Report BAKER Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 3K - 09 Project: Kuparuk River Unit TVD Reference: 3K -09 @ 69.00ft (3K -09) Site: Kuparuk 3K Pad MD Reference: 3K -09 © 69.00ft (3K -09) Well: 3K - 09 North Reference: TRUE Welibore: 3K - 09 Survey Calculation Method: Minimum Curvature Design: 3K - 09 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Az! TVD TVDSS +N/S +E1-W Northing Easting DLS Section Survey Tool Name Annotation (ft) ( °) ( (ft) (ft) (ft) (ft) (ft) (ft) moor) (ft) • 7,740.33 83.48 241.18 6,768.91 6,699.91 - 303.62 1,799.90 6,007,932.13 531,106.82 12.31 1,406.74 MWD (2) TIP 3K - 096L2 7,749.00 82.94 240.46 6,769.94 6,700.94 - 307.82 1,792.38 6,007,927.90 531,099.32 10.33 1,405.00 MWD (3) KOP; Top of Billet 7,780.38 88.49 239.16 6,772.26 6,703.28 - 323.55 1,765.34 6,007,912.07 531,072.35 18.16 1,399.22 MWD (3) Interpolated AZI 7,800.41 91.50 238.34 6,772.28 6,703.28 - 333.94 1,748.22 6,007,901.61 531,055.27 15.57 1,395.88 MWD (3) 7,830.71 96.09 234.05 6,770.28 6,701.28 - 350.75 1,723.11 6,007,884.70 531,030.23 20.71 1,392.18 MWD (3) 7,860.60 95.90 231.83 6,767.15 6,698.15 - 368.67 1,699.39 6,007,866.70 531,006.58 7.41 1,390.22 MWD (3) 7,890.99 94.79 227.87 6,764.32 6,695.32 - 388.17 1,676.27 6,007,847.10 530,983.53 13.48 1,389.86 MWD (3) 7,920.71 92.15 224.57 6,762.52 6,693.52 - 408.69 1,654.86 6,007,826.50 530,962.20 14.20 1,391.38 MWD (3) 7,950.19 89.91 222.07 6,761.99 6,692.99 - 430.13 1,634.64 6,007,804.98 530,942.07 11.39 1,394.38 MWD (3) 7,980.75 92.70 219.73 6,761.30 6,692.30 - 453.22 1,614.64 6,007,781.82 530,922.16 11.91 1,398.77 MWD (3) 8,010.41 92.92 215.71 6,759.84 6,690.84 - 476.65 1,596.52 6,007,758.32 530,904.14 13.56 1,404.64 MWD (3) 8,040.22 92.61 212.08 6,758.40 6,689.40 - 501.36 1,579.91 6,007,733.55 530,887.63 12.21 1,412.48 MWD (3) 8,070.06 90.25 208.98 6,757.66 6,688.66 - 527.05 1,564.76 6,007,707.80 530,872.59 13.05 1,422.01 MWD (3) 8,100.17 87.48 206.44 6,758.25 6,689.25 - 553.70 1,550.77 6,007,681.10 530,858.70 12.48 1,433.01 MWD (3) 8,130.83 86.62 207.69 6,759.83 6,690.83 - 580.97 1,536.84 6,007,653.78 530,844.87 4.94 1,444.53 MWD (3) 8,160.58 87.27 212.90 6,761.42 6,692.42 - 606.61 1,521.85 6,007,628.09 530,830.00 17.62 1,454.13 MWD (3) 8,190.57 90.43 216.04 6,762.02 6,693.02 - 631.32 1,504.89 6,007,603.31 530,813.13 14.85 1,461.73 MWD (3) • 8,220.55 90.49 220.48 6,761.78 6,692.78 - 654.85 1,486.33 6,007,579.70 530,794.66 14.81 1,467.40 MWD (3) 8,250.60 89.26 223.47 6,761.85 6,692.85 - 677.19 1,466.23 6,007,557.29 530,774.66 10.76 1,471.16 MWD (3) 8,280.46 88.28 219.28 6,762.49 6,693.49 - 699.59 1,446.51 6,007,534.82 530,755.02 14.41 1,475.20 MWD (3) 8,310.70 87.60 215.84 6,763.57 6,694.57 - 723.54 1,428.09 6,007,510.80 530,736.70 11.59 1,481.28 MWD (3) 8,340.04 88.43 211.95 6,764.59 6,695.59 - 747.87 1,411.74 6,007,486.40 530,720.45 13.55 1,489.00 MWD (3) 8,370.02 89.36 207.33 6,765.17 6,696.17 - 773.92 1,396.92 6,007,460.30 530,705.73 15.72 1,499.01 MWD (3) 8,400.55 93.96 206.06 6,764.29 6,695.29 - 801.18 1,383.21 6,007,432.99 530,692.13 15.63 1,510.67 MWD (3) 8,430.36 95.74 203.04 6,761.76 6,692.76 - 828.19 1,370.87 6,007,405.93 530,679.90 11.73 1,523.04 MWD (3) 8,460.37 92.03 198.95 6,759.73 6,690.73 - 856.13 1,360.15 6,007,377.95 530,669.29 18.38 1,537.16 MWD (3) 8,490.57 90.61 194.92 6,759.03 6,690.04 - 885.01 1,351.36 6,007,349.04 530,660.61 14.14 1,553.26 MWD (3) 8,520.65 91.04 195.49 6,758.60 6,689.60 - 914.03 1,343.47 6,007,319.99 530,652.84 2.37 1,570.06 MWD (3) 8,550.68 91.75 200.17 6,757.87 6,688.87 - 942.60 1,334.28 6,007,291.39 530,643.76 15.76 1,585.67 MWD (3) 8,580.65 90,98 204.23 6,757.16 6,688.16 - 970.34 1,322.96 6,007,263.61 530,632.55 13.78 1,599.25 MWD (3) 6/22/2010 8:19:56AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips ConocoPhill ps Definitive Survey Report HUGHES Alaska Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: 3K -09 Project: Kuparuk River Unit TVD Reference: 3K -09 © 69.00ft (3K -09) Site: Kuparuk 3K Pad MD Reference: 3K -09 © 69.00ft (3K -09) Wall: 3K - 09 North Reference: TRUE Wel 'bore: 3K - 09 Survey Calculation Method: Minimum Curvature Design: 3K - 09 Database: EDM Alaska Prod v16 Survey MD Inc Azi TVD TVDSS +N/-S +F/ -W Map Map DLL Vertical Northing Fasting Section Survey Tool Name Annotation (ft) ( °) ( °) (ft) (ft) on (ft) (ft) (ft) MOO') (ft) • 8,610.00 91.07 208.31 6,756.63 6,687.63 - 996.65 1,309.98 6,007,237.26 530,619.67 13.90 1,610.66 MWD (3) 8,630.04 87.73 210.91 6,756.84 6,687.84 - 1,014.07 1,300.08 6,007,219.80 530,609.84 21.12 1,617.36 MWD (3) 8,660.53 86.81 215.47 6,758.29 6,689.29 - 1,039.55 1,283.41 6,007,194.26 530,593.28 15.24 1,625.74 MWD (3) 8,694.72 88.28 218.16 6,759.76 6,690.76 - 1,066.89 1,262.94 6,007,166.84 530,572.92 8.96 1,633.04 MWD (3) 8,720.23 88.47 222.03 6,760.48 6,691.48 - 1,086.39 1,246.52 6,007,147.27 530,556.58 15.18 1,637.06 MWD (3) 8,750.57 87.91 226.10 6,761.44 6,692.44 - 1,108.18 1,225.44 6,007,125.41 530,535.58 13.53 1,639.75 MWD (3) 8,780.51 87.79 230.49 6,762.56 6,693.56 - 1,128.08 1,203.11 6,007,105.42 530,513.33 14.66 1,640.20 MWD (3) 8,810.62 88.37 230.79 6,763.57 6,694.57 - 1,147.16 1,179.84 6,007,086.25 530,490.14 2.17 1,639.43 MWD (3) I 8,845.57 89.20 224.28 6,764.32 6,695.32 1,170.74 1,154.08 6,007,062.57 530,464.47 18.77 1,640.42 MWD (3) 8,875.55 90.67 221.92 6,764.35 6,695.35 -1,192.63 1,133.60 6,007,040.60 530,444.08 9.27 1,643.58 MWD (3) 8,905.51 90.31 217.28 6,764.09 6,695.09 -1,215.70 1,114.50 6,007,017.45 530,425.08 15.53 1,648.56 MWD (3) 8,915.57 89.42 215.72 6,764.12 6,695.12 - 1,223.79 1,108.52 6,007,009.34 530,419.13 17.85 1,650.76 MWD (3) 8,955.00 89.42 215.72 6,764.52 6,695.52 -1,255.80 1,085.50 6,006,977.25 530,396.24 0.00 1,659.93 PROJECTED to TD • 6/22/2010 8 :19 :56AM Page 4 COMPASS 2003.16 Build 69 3K -09B + Completed CTD Sidetrack 3 -1/2" TRMAXX -5E SCSSV @2,183' MD ID = 2.812" 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface ID = 2.992" I 3 -1/2" Camco MMG gas lift mandrels @ 2396' 3533' 16" 62# H-40 shoe ■ 4607' @ 110' MD 5586' 6307' 10 -3/4" 45.5# K -55 f ; s 6839' shoe @ 3172' MD „, • iliatatt- 3 -1/2” X Nipple @ 6888' MD (2.813" profile) Baker PBR @ 6922' MD (4" ID) Baker KBH -22 Anchor Seal Assembly @ 6935' MD (3.0" ID) Top of liner 6965' K Baker SAB3 Packer @ 6936' MD (4.0" ID) 2.813 " 'XN' Nipple @ 6984' MD (milled out to 2.80" min ID) . Perfs for Cement - 7033' - 7035' WLEG @ 7049' MD Tubing Tail @ 7050' MD 1 I2 - 5/8" Openhole anchor /whipstock @ 7150' Top of liner 7193' � � � � : \ \ South Laterals Top of Billet - 7749' I3K- 09BL2 -01: 8955' 2 -5/8" Openhole anchor /whipstock @ 7201' l ' I 7250' - Bottom of Pilot Hole - -- North Laterals A3 - sand er 72 79' ::%.-"s::::: 3K- 096L2: 8879' P Top of Billet - 7863' - 7297' MD - 1 I A2 -sand perfs 7310' 1 ' - -_- __ 3K- 09BL1: 10,034' - 7326' MD \.\\.\\\ -- - -- II 7333' 7339' — — \ \ \\ 1 1 of Billet - 8059' _ \ \ � 3K -09B: TD - 9610' 7348' - 7352' I BOL - 9510' 7359' - 7363' 7" 26# J -55 shoe @ - ' i , <i us 1 I3K- 09BL1 -01: 8897' �_ 7559' MD - `'' 1.1111■- • 3K -09B Well Events Summary DATE SUMMARY • 4/11/10 TAG @ 7398' SLM w /10'x 2" DD BAILER, SAMPLE OF FRAC SAND. PERFORM 30 MIN SBHP @ 7340' RKB =3089 PSI, 162 DEG F; 15 MIN GRADIENT STOP @ 7222' = 3053 PSI. SET 2.81" CAT SV @ 6983' RKB, PULL OV @ 6839' RKB & GLVs @ 5586' & 3532' RKB, IN PROGRESS. 4/12/10 PULL GLV @ 2396' RKB, SET DVs @ 2396', 3532' & 5586' RKB, CIRC. 243 BBLS DIESEL DOWN TBG UP IA, ATTEMPT 2500PSI CMIT, FAILED, IN PROGRESS, 4/13/10 CMIT TO 2500 PSI; PASSED. SET DV @ 6839' RKB; MITT TO 2500 PSI, PASSED. PULL SV @ 6972' RKB. COMPLETE. 4/15/10 PERFORMED PERFORATIONS- MIDDLE OF FIRST FULL JOINT ABOVE TUBING TAIL. CORRELATED TO K1 MARKER ON SCHLUMBERGER CBL LOG DATED 14- NOV -86. PERFORATED 7035' - 7037'; 2 -INCH BH HSD GUNS, 6SPF, 60 DEG. 4/17/10 (PRE -CTD) T- POT - PASSED; T- PPPOT- FAILED; IC- POT - PASSED; IC PPPOT- PASSED; MITOA- PASSED; PT SV- PASSED; MV- PASSED; SSV- PASSED; DD TEST SV- PASSED; MV- PASSED; SSV- PASSED; SSSV- PASSED 4/19/10 TAGGED @ 7390' SLM. LOG CALIPER f/ 7380' - 6300' SLM. DATA NOT GOOD, CALIPER ARMS STUCK IN DUE TO VISCOUS / TAR -LIKE COATING. 4/20/10 MIRU; RD FOR SAFETY STAND DOWN. IN PROGRESS. 4/21/10 BRUSHED & FLUSHED TBG f/ 6500' - 7370' SLM. LOGGED CALIPER SURVEY f/ 7360' - 6500' SLM. RECOVERED DATA GOOD. COMPLETE. 4/22/10 MILL 2.75" XN NIPPLE @ 6983' RKB TO 2.80 ". WELL READY FOR SLICKLINE TO DRIFT NIPPLE & SET FRAC SLEEVE. IN PROGRESS. 4/23/10 GAUGED TBG TO 2.79" THRU XN TO 7100' SLM. ATTMEPTED DRIFT FOR FRAC SLEEVE; TIGHT COLLAR @ 41' SLM. RD FOR CTU. 4/23/10 MILL TIGHT COLLAR © 57' CTMD W/ 2.87" JUNK MILL. DRIFT DRY TO SSSV @ 2183' RKB. TURN WELL OVER TO SLICKLINE, IN PROGRESS. 4/23/10 GAUGED TBG TO 2.86" TO SSSV. SET 3.5" TRMAXX -5E FRAC SLEEVE IN SSSV @ 2183' RKB (OAL =80 ", MIN ID= 2.30 "). COMPLETE. 4/24/10 LOAD WELL WITH HEATED SEAWATER. LAY IN 25 BBLS OF 17 PPG CEMENT & PERFORM HESITATION SQZ UP TO 2000 PSI, HELD FOR 1 HOUR. CLEAN OUT CEMENT W/ BIOZAN & SEAWATER TO TOC @ 7033' RKB. WELL FREEZE PROTECTED W/ DIESEL TO 2500' RKB. ALLOW 72 HOURS FOR CEMENT TO CURE PRIOR TO TAG & PT. IN PROGRESS. 4/27/10 MIT TBG 1635 PSI, GOOD TEST. TAGGED CEMENT @ 7010' SLM. PULLED FRAC SLEEVE @ 2153' SLM - 2183' RKB. COMPLETE. 6/15/10 GAUGED TBG TO 2.74" TO 2 -3/8" LINER TOP @ 6957' RKB. MEASURED BHP @ 6957' RKB: 4274 PSI. SET CATCHER @ 5695' SLM. REPLACED DV @ 5586' RKB WITH OV. PULLED DV @ 4606' RKB. IN PROGRESS. 6/16/10 SET GLV @ 4606' RKB. REPLACED DVs @ 3533' & 2396' RKB WITH GLVs. PULLED CATCHER @ 5695' SLM. COMPLETE. • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/06/2010 24 hr Summary RIH setting liner on bottom 8880', TOL 7749'. POOH displacing KWF. At surface perform function test on BOP's. PU drilling BHA (1.1 AKO, Hughes bit). RIH displace well to Flo -Pro. Sidetrack BL2 -01 Lateral at 7749'. Drill BL2 -01 Lateral 7749'- 8130'. 00:00 00:30 0.50 0 0 COMPZ CASING PUTB P Continue running liner 00:30 01:45 1.25 0 7,044 COMPZ CASING RUNL P RIH 01:45 02:00 0.25 7,044 7,077 COMPZ CASING DLOG P Tie in depth to EOP flag, Close EDC, Record up and down weights. correct +32', 23K PUW, 02:00 02:15 0.25 7,076 8,886 COMPZ CASING RUNL P Continue RIH, EOP flag on depth 02:15 02:45 0.50 8,886 7,170 COMPZ CASING RUNL P Liner on bottom, pump off liner 02:45 03:15 0.50 7,170 7,170 COMPZ CASING DLOG P Tie in depth to RA marker -4.5' correction Liner Depths: BOL= 8881.5', TOL= 7749.5' 03:15 04:45 1.50 7,170 0 COMPZ CASING RUNL P POOH, circulating KWF 04:45 05:00 0.25 0 0 COMPZ CASING SFTY P At surface, PJSM, Monitor well for flow 05:00 06:00 1.00 0 0 COMPZ CASING PUTB P LD BHA 18 Function test BOP's 06:00 07:18 1.30 0 0 PROD5 STK PULD P PU BHA # 19. 07:18 08:54 1.60 0 6,700 PROD5 STK TRIP P RIH 08:54 09:12 0.30 6,700 6,747 PROD5 STK DLOG P Tie in at RA, +28'. close EDC 09:12 11:12 2.00 6,747 7,030 PROD5 STK DISP P Continue RIH to 7400', circulate out the KWF pulling up above window 11:12 11:42 0.50 7,030 7,749 PROD5 STK TRIP P RIH and dry tag billet at 7748.7' 11:42 14:06 2.40 7,749 7,770 PROD5 STK KOST P Start time milling at 1 FPH for 1' from 7748.7' @ 1.3 BPM, 3900 CTP, 4550 BHP, 400 WHP, 11K RIW. Increase to 2 FPH for 1'. Increase to 3 FPH for 1', increase to 15FPH 14:06 16:54 2.80 7,770 7,910 PROD5 DRILL DRLG P PU at 22K PUW and ream past billet then drift with pump down. Looks good. Driling ahead, 1.3 BPM, 4000 CTP, 4520 BHP, 390 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 16:54 17:54 1.00 7,910 7,910 PROD5 DRILL WPRT P Wiper trip, 22K PUW 17:54 19:06 1.20 7,910 7,991 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4000 CTP, 4520 BHP, 390 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 19:06 19:51 0.75 7,991 7,991 PROD5 DRILL WPRT P Goe wiper 22K PUW 19:51 21:06 1.25 7,991 8,055 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4125 CTP, 4520 BHP, 280 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 21:06 22:36 1.50 8,055 8,055 PROD5 DRILL WPRT P Wiper trip, 22K PUW 22:36 00:00 1.40 8,055 8,130 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4200 CTP, 4520 BHP, 270 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work Page 22 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/07/2010 24 hr Summary Drill BL2 Lateral 8130' - 8647', Encountering ankerite for slow ROP's 00:00 01:00 1.00 8,130 8,205 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4300 CTP, 4550 BHP, 390 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 01:00 01:45 0.75 8,205 8,205 PROD5 DRILL WPRT P Wiper trip, 22K PUW 01:45 01:51 0.10 7,170 7,180 PROD5 DRILL DLOG P Tie in Depth -4' Correction 01:51 02:36 0.75 7,180 8,205 PROD5 DRILL TRIP P RIH 02:36 04:06 1.50 8,205 8,355 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4300 CTP, 4550 BHP, 280 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 04:06 06:06 2.00 8,355 8,355 PROD5 DRILL WPRT P Wiper trip back to window, 23K PUW 06:06 16:06 10.00 8,355 8,505 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4100 CTP, 4620 BHP, 350 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 16:06 18:06 2.00 8,505 8,505 PROD5 DRILL WPRT P Wiper to window, 21K PUW 18:06 00:00 5.90 8,505 8,647 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4100 CTP, 4620 BHP, 350 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 06/08/2010 TD BL2 Lateral @ 8955, Lay in liner pill & KWF. Start Skate repairs 00:00 02:00 2.00 8,647 8,655 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4100 CTP, 4620 BHP, 350 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 02:00 03:00 1.00 8,655 7,170 PROD5 DRILL WPRT P Wiper Trip to window, 22K PUW 03:00 03:15 0.25 7,170 7,170 PROD5 DRILL DLOG P Tie into RA marker, -4.5' correction 03:15 04:00 0.75 7,170 8,655 PROD5 DRILL WPRT P RIH 04:00 10:00 6.00 8,655 8,805 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4100 CTP, 4620 BHP, 350 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 10:00 11:00 1.00 8,805 7,035 PROD5 DRILL WPRT P Wiper to window, 22K PUW 11:00 11:12 0.20 7,035 7,055 PROD5 DRILL DLOG P Tie in, zero correction 11:12 12:00 0.80 7,055 8,805 PROD5 DRILL WPRT P Continue wiper in hole, 13K RIW 12:00 14:12 2.20 8,805 8,955 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4200 CTP, 4640 BHP, 250 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 14:12 16:00 1.80 8,955 7,175 PROD5 DRILL WPRT P TD well, recip to get low /high vis sweeps around then wiper to window 16:00 16:18 0.30 7,175 7,195 PROD5 DRILL DLOG P Tie in, -1' 16:18 17:00 0.70 7,195 8,955 PROD5 DRILL WPRT P RBIH, tag TD at 8955' 17:00 19:45 2.75 8,955 0 PROD5 DRILL TRIP P POOH, laying in liner running pill, Paint 6800, 5000' EOP Flag Stop and check injector, Making noises. Stop and check reel 19:45 21:00 1.25 0 0 PROD5 DRILL PULD P At surface, PJSM while performing No -Flo test Good test, Lay down BHA #19. Bearing rollers and Race pieces in sump Page 23 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 23:00 2.00 0 0 PROD5 DRILL RGRP T Circulate KWF out of coil. Unstab and remove UQC. Seal end of E -Line. Blow back coil with 350PSI Air compressor Bleed off air, Unstab. ** *Nabors Downtime Starts * ** 23:00 00:00 1.00 0 0 PROD5 DRILL RGRP T PJSM, Rig up to unstab coil from Injector 06/09/2010 Complete Injector repairs, Perform slack Mgmt. Start BL2 -01 Liner pick up 00:00 16:00 16.00 0 0 PROD5 DRILL RGRP T Nabors Downtime. Continue to prep for skate removal: unstab coil, lay down stripper, Break chains, remove skates, install skates, MU Chains, Check chains and gripper blocks, MU stripper, Stab coil, Cut off grapple. * ** Nabors Downtime ends * ** 3 Hours for the 8th, 16 Hours for the 9th. 16:00 18:00 2.00 0 0 COMPZ CASING SLPC P Seal end of E -line, stab onto well and pump slack, cut off 50' to find wire 18:00 21:00 3.00 0 0 COMPZ CASING CTOP P PJSM, Dress coil and install CTC, Pull test to 35K Test E -Line, Make up Upper quick connect Run Valve checklist, Fill coil and PT connector to 4K 21:00 22:45 1.75 0 0 COMPZ CASING CTOP P Replace Packoffs, Roll coil to KWF. PT lubricator and packoff to 4K. Open swabs, Fill hole monitor for flow 22:45 00:00 1.25 0 0 COMPZ CASING PUTB P PJSM, Make up BL2 -01 Liner Perform safety joint drill 06/10/2010 Make up Liner / RIH, Unable to get past 7420, POOH, P/U Mill, unable to get to past 7406. POOH Revise BHA 00:00 02:42 2.70 0 2,036 COMPZ CASING PUTB P Continue to Make up BL2 -01 Liner Make up coil track to liner, Surface test, Open EDC 02:42 04:12 1.50 2,036 6,955 COMPZ CASING RUNL P Trip in with Liner 04:12 04:24 0.20 6,955 7,419 COMPZ CASING RUNL P 6955, Correct to EOP Flag +31' (last liner correction +32) PUW =24k, Continue in well, RIW =16K 04:24 06:18 1.90 7,419 7,419 COMPZ CASING RUNL T Unable to work past 7419'. Tried different speeds and different operators with no luck. 06:18 07:48 1.50 7,419 0 COMPZ CASING RUNL T POOH, KWF down backside. Page 24 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:48 12:24 4.60 0 0 COMPZ CASING PUTB T Lay down liner running BHA. RU and lay down liner string. Shoe had hard packed salt on the nose. It turned and moved up and down normally. RD liner running equipment 12:24 12:36 0.20 0 0 COMPZ CASING SFTY T PJSM 12:36 13:18 0.70 0 0 COMPZ CASING PULD T PU cleanout BHA, 1.1 Deg. motor and used bicenter bit. 13:18 15:06 1.80 0 6,670 COMPZ CASING TRIP T RIH circulating KWF at .3 BPM 15:06 15:18 0.20 6,670 6,700 COMPZ CASING DLOG T Tie in, +24' 15:18 16:18 1.00 6,700 7,400 COMPZ CASING TRIP T Continue RIH, Displace KWF from 7400' 16:18 17:33 1.25 7,400 7,408 COMPZ CASING TRIP T RIH and bring rate up. Tag and stall at 7408'. PU clean, RIH at .3 BPM and tag in same place. Try at .8 BPM and RIH at 30 FPM, tag same. 17:33 19:33 2.00 7,408 0 COMPZ CASING TRIP T POOH to revise BHA 19:33 21:03 1.50 0 0 COMPZ CASING PULD T PJSM, Undeploy BHA # 21 21:03 21:48 0.75 0 0 COMPZ CASING PULD T Reset motor AKO, service FVS. Load PDL 21:48 23:18 1.50 0 0 COMPZ CASING PULD T PJSM, Deploy BHA #22, Surface test tool, Strip on and bump up 23:18 00:00 0.70 0 1,875 COMPZ CASING TRIP T RIH with BHA #22. 2.3 degree motor and 2.74 Mill 06/11/2010 Cleanout wellbore to TD, Run liner to TD BOL =8957 TOL =6965 00:00 01:00 1.00 1,875 6,680 COMPZ CASING TRIP T Continue in well 01:00 01:06 0.10 6,680 6,737 COMPZ CASING DLOG T 6680, Log tie in for +23' correction 01:06 01:48 0.70 6,737 7,408 COMPZ CASING TRIP T Continue in well. Started 10 BBI KCL +Claystop pill down coil after passing window. Tagged up @ 7408 PUH and wait for pill to get to mill 01:48 02:00 0.20 7,408 7,510 COMPZ CASING MILL T Mill at 7402 pill at mill. RIH @ 3fpm 1.30BPM@ 3908 PSI Free spin 7415 to 5 FPM, 7425 to 10 FPM to 7510 Bottom of build 02:00 04:15 2.25 7,510 0 COMPZ CASING TRIP T Clean trip to 7510, POOH following MP Schedule. Stop and open EDC 04:15 06:00 1.75 0 0 COMPZ CASING PULD T PJSM, Undeploy BHA #22 06:00 06:24 0.40 0 0 COMPZ CASING SFTY T PJSM, crew change 06:24 07:54 1.50 0 0 COMPZ CASING PULD T Deploy BHA # 23 07:54 09:24 1.50 0 6,880 COMPZ CASING TRIP T RIH following MPD tripping schedule 09:24 09:36 0.20 6,880 6,738 COMPZ CASING DLOG T Tie in, +23' correction. Close EDC 09:36 11:06 1.50 6,738 8,955 COMPZ CASING TRIP T Continue RIH 11:06 12:06 1.00 8,955 7,400 COMPZ CASING DISP T Tag bottom at 8955'. Lay in liner running pill. 12:06 14:06 2.00 7,400 0 COMPZ CASING DISP T Lay in KWF, Flag pipe at 6800' EOP and 5000' EOP Page 25 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:06 15:06 1.00 0 0 COMPZ CASING PULD T Lay down cleanout BHA 15:06 15:24 0.30 0 0 COMPZ CASING SFTY T PJSM for liner ops 15:24 19:00 3.60 0 0 COMPZ CASING PUTB T Run liner 19:00 20:30 1.50 0 7,006 COMPZ CASING RUNL T RIH with Liner 20:30 21:30 1.00 7,006 8,962 COMPZ CASING RUNL T Correct @ Flag +30.5' correction PUW =23K 21:30 21:36 0.10 8,962 8,945 COMPZ CASING RUNL T 8969, Set down with liner. P/U and confirm bottom, Neutral weight depth 8962. Pump off liner 1 BPM @ 4620, PUW 23K 21:36 22:24 0.80 8,945 8,945 COMPZ CASING CIRC P Circulate Spacer then seawater down coil 22:24 22:42 0.30 8,945 6,670 COMPZ CASING DLOG P Pull up hole to Tie In, Reset depth to remove liner length, Log GR Tie in for -6' correction BOL =8957, TOL =6965' Corrected 22:42 00:00 1.30 6,670 3,480 COMPZ CASING RUNL P POOH. Load coil with Diesel 06/12/2010 Swap well to SW and FP from 2500' with diesel. RDMO 00:00 01:00 1.00 3,480 0 COMPZ CASING RUNL P continue out of well 01:00 03:00 2.00 0 0 COMPZ CASING PUTB P PJSM, At surface, Pressure undeploy BHA #24 Blow down tools and lay down Final SITP =1650 IA =37, OA =150 03:00 04:15 1.25 0 0 DEMOB WHDBO NUND P PJSM, Get FMC equipment to rig floor to set BPV 04:15 05:00 0.75 0 0 DEMOB WHDBO NUND P PT Lubricator to 3K, RI with BPV 05:00 06:12 1.20 0 0 DEMOB WHDBO NUND P Stab back on well to flush rig 06:12 08:06 1.90 0 0 DEMOB WHDBO NUND P Start blowing down rig 08:06 10:00 1.90 0 0 DEMOB WHDBO NUND P ND BOP stack and RD ops. Release rig at 10:00, start rig move charges on 1 R -06. Exception rig move. Page 26 of 26 • ConocoPhillips Alaska RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wright, 907 263 -4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk * / 333 West 7th Ave, Suite 100 in lieu of sepia ** Electronic Anchorage, Alaska 99601 CGM / TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk * / David Douglas in lieu of sepia ** Electronic P.O. Box 196612 CGM / TIFF LIS Anchorage, Alaska 99519 -6612 CHEVRON /KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk * / P.O.Box 196247 in lieu of sepia ** Electronic Anchorage, Alaska 99519 CGM / TIFF LIS Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 Disk * / 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501 -3510 LIS RECEIVED viii 2 7 2011 c ) 0 —(54 / q'3� AT1Chlr ;/o -643 / 4906' 9a5 ato -oGt5 /996(0 3 to • SEAN PARNELL, GOVERNOR FIAIrE ALASKA. OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 James Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3K- 09BL2 -01 ConocoPhillips Alaska, Inc. Permit No: 210 -045 Surface Location: 1234' FSL, 317' FWL, Sec. 35, T13N, R9E, UM Bottomhole Location: 165' FNL, 847' FWL, Sec. 1, T12N, R9E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re -drill the above referenced development well. The permit is for a new welibore segment of existing well KRU 3K -09B, Permit No 210- 042, API 50- 029 - 21656 -02. Production should continue to be reported as a function of the original API number stated above. 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. Sincerely, Daniel T. eamount, Jr. L / Chair DATED this 1 raayof April, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via e -mail) RECEIVED • 4111 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 0 9 2010 PERMIT TO DRILL Alaska Oil & Gas Cons. Commission 20 AAC 25.005 AtleilOrdae la. Type of Work: • lb. Proposed Well Class: Development - Oil is Service - Winj ❑ Single Zone 0 • lc. Specify if well is proposed for: Drill ❑ Re -drill 0 Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re -entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: U Blanket U Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 • 3K 09BL2 - 01 • 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 9075' ' TVD: 6660' ' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 1234' FSL, 317 FWL, Sec. 35, T13N, R9E, UM . ADL 25519, 25629 Kuparuk River Oil Field . Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 946' FSL, 2129' FWL, Sec. 35, T13N, R9E, UM 2555, 2562 4/26/2010 • Total Depth: 9. Acres in Property: 14. Distance to 165' FNL, 847' FWL, Sec. 1, T12N, R9E, UM 2560 Nearest Property: 8200' . 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 69 feet • 15. Distance to Nearest Well Open Surface: x - 529306 ' y - 6008229 • Zone 4 GL Elevation above MSL: 30 feet to Same Pool: 3K -03 , 1200 • 16. Deviated wells: Kickoff depth: 7700 , ft. 17. Maximum Anticipated �� pressures in psig, (see 20 AAC 25.035) `` Maximum Hole Angle: 100 deg Downhole: psig YW 2 -i , Surface: 3863 psig ' 18. Casing Program: _ Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L - 80 ST - L 2105' 6970' 6460' 9075' 6660' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 7580 6980 7400', 7453' Casing Length Size Cement Volume MD TVD Conductor /Structural 80' 16 1540# Poleset 110' 110' Surface 3172' 9.625 1400 sx AS IV, 125 sx CI G 3172' 3169' Intermediate Production 7559' 7 910 sx Class G, 175 sx AS 1 7559' 6962' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 7279' 7297', 7310' 7326', 7333', 7339', 7344', 7348' 7352', 7359' - 7363' 6727'- 6743', 6754'- 6767', 6773', 6779', 6783', 6786'- 6790', 6796' -6799' 20. Attachments: Property Plat ❑ BOP Sketch isi Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: L / /g�p "c2Q 22. I hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265 - 1102 Printed Name V. Cawvey Title Alaska Wells Manager Signature Z Phon 265 -63o6 Date +/a/UN Commission Use Only T Permit to Drill l API Num Permit Approval See cover letter l Number: 2. � C ' / _ C 50- t+� %� -- Z *5 -6z I Date: L{/ I 4 /10 for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed me ane, gas hydrates, or gas contained in shales: ie SQOV p.J� B((' S� Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No [� Other: +l 2500 lox:- A„` e -4 C 3 >L H2S measures: Yes [/No ❑ Directional svy req'd: Yes M No ❑ (am-) I / APPROVED BY THE COMMISSION i �t� DATE: , COMMISSIONER Form 10 (Revis d 7/2009) This permit is valid 0 inIpt ■ srr Vatef t dp'prov (20 AAC 25.005(g)) Submit in Duplicate y /Y•% , -' /v -41:' Y 2 ./0 • Permit to Drill Summary of Operations KRU 3K -09B, 3K- 09BL1, 3K- 09BL2, and 3K- 09BL2 -01 Laterals Coiled Tubing Drilling Overview: Well 3K -09A is currently a producer completed in the A3 and A2 sands through the 7" production casing with 3- 1/2 tubing to surface. The proposed CTD sidetracks will be named 3K -09B, 3K- 09BL1, 3K- 09BL2, and 3K- 09BL2-01 and will target the A3 and A2 -sands to access provide offtake in two dead segments to the north of 3K -09A, replace the existing production near the (cemented) motherbore, and improve sweep efficiency across two baffling fault zones south of the parent well. A cement plug will be placed across the existing perforations, and a 2.80" pilot hole will be a drilled on the high - side of the 7" casing to a depth of approximately 7,250' MD. Two whipstocks will then be set at 7,200' MD and 7,150 for high -side casing exits. The 3K -09B is planned for a 2 -3/8" slotted liner with a liner -top aluminum billet for the KOP for the BL1 lateral at - 8,200' MD. 3K -09BL1 will be completed with 2 -3/8" slotted liner with the liner top brought up into the pilot hole inside the 7" casing at 7,195' MD. The completion for 3K -09BL2 will consist of 2 -3/8" slotted liner with a liner - top aluminum billet for the KOP for the BL2 -01 lateral at -7,700' MD. The completion for 3K- 09BL2 -01 will be 2 -3/8" slotted liner with the liner top brought up into the existing 3 -1/2" tailpipe to approximately 6,970' MD. Operational Outline Pre -Rig Work • Slickline: Dummy perf gun drift. Obtain SBHP. Dummy GLVs, MIT -IA. • E -line: Run GR/CCL jewelry log / tie -in log (K1 Marker to Tubing Tail). Shoot holes in the 3%2" tubing below the Baker SAB3 Packer from 7033' to 7035' RKB. • Coil: Mill out the XN- nipple at 6984' RKB to 2.80" with a left -hand motor. • Coil: Lay in cement plug from PBTD plug to —7033' RKB. • Slickline: Tag top of cement, pressure test cement plug. • Prepare wellsite for rig arrival. Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU BOPE and test. 2. Mill cement pilot hole. 3. Set top of whipstock at 7,200' MD. 4. Mill 2.80" window at 7,200'. 5. 3K -09B Sidetrack a. Drill a 2.70" x 3" bi- center lateral to a TD of 9,975' MD b. Run the 2%" slotted liner from TD to —8,200' MD. An aluminum liner top billet will be placed at —8,200' MD. 6. 3K -09BL1 Lateral a. Kick off of the aluminum liner top billet at —8,200' MD b. Drill a 2.70" x 3" bi- center lateral to a TD of 10,050' MD c. Run the 2 %" slotted liner from TD to —7,195' MD, into the pilot hole inside the 7" casing Page 2 of 5 4/6/2010 1' ) t r III • Permit to Drill Summary of Operations Cont. KRU 3K -09B, 3K 09BL1, 3K 09BL2, and 3K- 09BL2 -01 7. Set top of whipstock at 7,150' MD. 8. Mill 2.80" window at 7,150'. 9. 3K -09BL2 Sidetrack a. Drill a 2.70" x 3" bi- center lateral to a TD of 9,075' MD b. Run the 2%" slotted liner from TD to —7,700' MD. An aluminum liner top billet will be placed at —7,700' MD. 10. 3K- 09BL2 -01 Lateral a. Kick off of the aluminum liner top billet at —7,700' MD b. Drill a 2.70" x 3" bi- center lateral to a TD of 9,075' MD P rD c. Run the 2%" slotted liner from TD to —6,970' MD, inside the 3 -1/2" tubing tail of the motherbore. Post -Rig Work 1. Install GLV's 2. Obtain SBHP 3. Produce to system Mud Program • Chloride -based Biozan brine (8.9 ppg) for milling operations, and chloride -based Flo -Pro mud ( -10.0 ppg) for drilling operations. • There is an SSSV installed in 3K -09A so we will not have to load the well with completion fluid to deploy the 2 - %" slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. New Completion Details: Lateral Name Top Btm Liner Details Other Details MD MD 3K - 09B 8,200 9,975 2%", 4.7 #, L -80, ST -L slotted Unanchored aluminum billet 3K - 09BL1 7,195 10,050 2%", 4.7 #, L -80, ST -L slotted 3K - 09BL2 - 7,700 9,075 2%", 4.7 #, L -80, ST -L slotted Unanchored aluminum billet 3K - 09BL2 - 6,970 9,075 2%", 4.7 #, L -80, ST -L slotted Existing Completion Details: Category OD Weight Grade Top Btm Burst Collapse (ppf) MD MD psi psi Conductor 16" 62 H -40 0 110 1640 670 Surface 9'/ 36 J -55 0 3,172 3520 2020 Casing 7" 26 J -55 0 7,559 4980 4320 Tubing 3'/ " 9.3 L -80 0 6,940 10,160 10,530 Page 3 of 5 4/6/2010 3 Permit to Drill Summary of Operations Cont. KRU 3K-09B, 3K 09BL1, 3K- 09BL2, and 3K 09BL2 -01 Well Control: • Two well bore volumes of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 5000 psi. Maximum potential surface pressure is 3863 psi assuming a gas gradient to surface based on the potential offset well pressure of an equivalent 13.0 ppg mud weight. • The annular preventer will be tested to 250 psi and 2500 psi. Directional: • See attached directional plans. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 3K -09B 7220' 3K -09BL1 7220' 3K -09BL2 8200' 3K- 098L2 -01 8200' • Distance to Nearest Well within Pool (toe measured to offset well 3K-03, and 3K -12) Lateral Name Distance 3K -09B 1350' 3K -09BL1 1350' 3K -09BL2 1200' 3K- 09BL2 -01 1200' Logging MWD directional, resistivity, and gamma ray will be run over the entire open -hole sections. Reservoir Pressure 3K -12 is the closest offset well injecting in the A -sand interval and had a static bottom hole pressure of 3584 psi (10.3 ppg EMW). 3K -12 has been flowing back for several months to bring the reservoir pressure down. 3K -05 has been shut in since October '09 from injecting water and it measured 4564 ps (13.2 ppg EMW, Feb. '10). Similar pressures are expected as the laterals are drilled. The most recent static bottom hole pressure reading in 3K -09 was 2065 psi (6.0 ppg EMW). The 3K -09 has been shut -in for 5 months to allow the reservoir pressure to build up high enough to drill without excessive losses and to mitigate high differential pressure at fault crossings. Hazards • Laterals are approaching injectors in both directions. Pressure is expected to increase along wellbore. Maintain sufficient ECD to overbalance. A 10.0 ppg mud system, annular friction and 400 psi on the drilling choke will supply enough pressure to overbalance. • Well 3K -09 has 120 ppm H2S as measured on Feb. '09. The maximum H level on the 3K pad is 400 ppm measured on Jan. '09 at 3K -27. All H monitoring equipment will be operational. Page 4 of 5 4/6/2010 • Permit to Drill Summary of Operations Cont. KRU 3K-09B, 3K- 09BL1, 3K 09BL2, and 3K-09812-01 Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 10.0 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows for the use of less expensive drilling fluid and minimizes fluid losses and /or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is located between the BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA with trapped wellhead pressure. Pressure deployment of the 2 %" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. Well 3K -09 does have a SSSV, so the well will not have to be loaded with completion fluid prior to running slotted liner. Operating parameters and fluid densities will be adjusted based on real -time bottom hole pressure measurements while drilling and shale behavior. The following charts show the different pressure parameters in both "pumps on" and "pumps off" conditions. Drilling Conditions: Pressure at the Window Using MPD (FloPro) Pumps On Pumps Off (1.5 bpm) Formation Pressure 4480 psi 4480 psi Mud Hydrostatic (10.0 ppg) 3384 psi 3384 psi Annular friction (i.e. ECD) 684 psi 0 psi 4068 psi 3384 psi + Mud ECD Combined ( underbalance (underbalanced (no choke pressure) d —412 psi) —553 psi) Target Pressure (13.3 ppq) 4500 psi 4500 psi Choke Pressure Required 432 psi 1116 psi to Maintain 13.3 ppg Examole: Using the 3K -05 SBHP from Feb. '10 and assuming a reservoir pressure of 4480 psi (Shut -in and dropping 1 psi /day) at 6663' TVDss (12.9 EMW). While drilling and circulating at 1.5 bpm with 2" e-coil, head from the 10.0 ppg mud (3384 psi), plus an estimated 684 psi of annular friction (assuming friction of 95 psi /1000 ft) plus 530 psi WHP will provide 4600 psi BHP (13.6 ppg EMW) and overbalance the reservoir by —100 psi. When circulation is shut down, the mud will still be underbalanced to the reservoir pressure. However maintaining —1216 psi at surface when the pumps are shut down will maintain a constant 13.6 EMW to promote wellbore stability. Page 5 of 5 4/6/2010 a 3K -09B + Proposed CTD Sidetrack 3-1/2" TRMAXX -5E SCSSV @ 2,183' MD ID = 2.812" _ 3-1/2" 9.3# L -80 EUE 8rd Tubing to surface ID = 2.992" 16 "62 #H -40 shoe _ @ 110' MD 3 -1/2" Camco MMG gas lift mandrels © 2396' 3533' 4607' 9 -5/8" 36# J-55 shoe ■ 5586' © 3172' MD 6307' ■ 6839' • 3-1/2" X Nipple @ 6888' MD (2.813" profile) 11 Baker PBR © 6922' MD (4" ID) Baker KBH -22 Anchor Seal Assembly @ 6935' MD (3.0" ID) Packer to OP.-, - IPerfs for Cement Baker SAB3 Packer @ 6936' MD (4.0" ID) Tubing Tail = 104' �� 7033' -7035' I' 2.813 "'XN' Nipple @ 6984 MD (2.75" min ID) 1 I II WLEG @ 7049' MD Tubing Tail to �— ' t1baii ,iii,''' ` Tubing Tail @ 7050' MD ,' Top of Whipstock = 100' - i. d !d _ • 1 N. '2 -5/8" :::: ::::::::::: ::: • 2 -5/8" ' r , ,.I , ulN'LG ,, it L f� ;; .: 4 , ,r,, _ I� n I � 3K 09BL1. 7 i,l i 7250' - Bottom of Pilot Hole '' , 111`'; ' 4 G '' 5' WP06 ' ��;° ' � 1 l North Laterals � '" � � �� 3K 09BL2: 907 ti . -, F s � I�i'I. I{.;�+,I„mu'- titwjt =I.-i .y.2 �.::�aWir..i N.1;�..a,..� ,�I'i.:. -.���i i,. i„w,"`�`4,': A3 - sand perfs 7279'pi,µ�� 7299' MD �� I � I �l 1:ilalitteftf a lih i lf s h'i , _ i "'�f'IIIflII 4h, 732V MD � '15 �' IKOP - 8200'1 �!( ,��� %.,. .. d 3 K �- A2 -sand arts 7310' xw - 088L1: 10,050' WP07 7333 ,' T' 26# J SS shoe @ -. ; 9 ',r. u . , 13K-09B: 9975' WP 7348' - 7352' PBTD @ 9'410' 7359' - 7363' -.Non/ i 11122/09 'I __ 7559 MD KUP 3K-09A 1 .11. ps pliF ,4 . COnotor- ; blitalti,:::,:„„ L 2 Well Attribute! --:_-_,::_-::-_,=-_-: _:-; _-- --_:;:- -_ -„--,-_ :- , _•..,...,:. ,_,.. ,.. __, m mcy TD: _, ; _,_, , ,;.,. : -. if ,.. t „ Al fr pr 99I ) Wellbore APVUWI Field Name Well Status Ind r) MD (MB) Act Btm (MB) ' 'AY 500292165601 KUPARUK RIVER UNIT I PROD 08000748,81/ps 37.33 4,675.00 7580.0 Colrnnnnt H2S (ppm) Date Annotation End Date KB.Grd (ft) Rig Release Date ... SSSV: TRDP 135 1/12/2008 Last WO: 9/5/2008 39.90 10/17/1986 Wall Conti: • 316.00A.11/2192009 100327 AM Salaam* -Actual Annotation Depth (MB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,397.0 11/22/2009 Rev Reason: TAG Imosbor 11/26/2009 E CiiiiiiiStriiiiii0f=4:-= , , Casing Description String 0... String ID - Top (MB) Set Depth (f... Set Depth (TVD) - String Wt... ' String ... String Top Thrd CONDUCTOR 16 15.062 0.0 110.0 110.0 62.50 H CONDUCTOR, Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (PM).- String WL- String ... String Top Thrd 0.110 c spi sto ... Top (MB) 5.8 setD. ,17 0h 2.0 3 (f... set Depth (TVD) )... sui shi swop Top Tpro Safety Valve, -Jr- PRODUCTION 7 6.151 0.0 7,559.0 26.00 .1-55 alto lie: Witiiiiii&iritigigi ._* - _=4 Tubing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth )TVD) - String Wt... String ... String Top Thrd GAS LIFT, TUBING 3 1/2 2.992 0.0 6,940.4 6,434.6 9.30 L EUE 8rd Z 396 it CiiiiipiiitiaifciiitifiiiiV::=M --5aTi-:',-'_'s:::,15-5-.•=:-='n=t4,4:41iMtg=:==-7,71W-Ft-'4-;;10";:EW - Top Depth MD) Top hid Noml... SURFACE (MB) BM) r) kern Description ID (in) OFt,172 M • I 0.0 0.0 0.00 HANGER 3.5" Gen V Tubing Hanger EUE 8rd Mod (Pup jt 3.66') 3.500 2,183.3 2,183.3 1.24 Safety Valve 3.5" TRMAXX-55 SCSSV w/ 2.812" X Profile EUE 8rd Mod 2.812 GAS LIFT, 11 6,888.0 6,390.0 31.54 NIPPLE 3.5" X Nipple w/ 2.813" profile 2.813 11 M I 6,927.6 6,423.7 31.23 LOCATOR Baker 3.5' Locator O.D. 4.54" I. D. 3.99" 3.030 GAS LIFT, 6,927.9 6,424.0 31.23 SEAL ASSY Baker 80 PBR w/Seal Assembly O.D. 4.01" I.D. 2.99 2.990 ' -W 4,607 i Tubing Description String 0... String ID - Top (MB) Set Depth (1.- Set Depth (TVD) - String Wt... String ... Sting Top 76.8 TUBING Original 31/2 2.992 6,921.6 7,050.0 6,528.1 9.30 L-80 EUE 8rd iiiiiiiiiiiii Details , g C 01_ ok4 5,556 GAS LIFT, lit I Top Depth (TVD) Top Ind Top (MB) (MB) (1 G) Item Description m Coment Nomi.- • ID (In) GAS LIFT, i 6,921.6 6,418.7 31.87 PBR Baker PBR Polish Bore Receptacle (6 Pins 40,000 lb Shear) 4.000 6,307 . I 6,935.0 6,430.0 31.25 SEAL ASSY Baker KBH-22 Anchor Seal Assembly (3.5" EUE 8rd Box Up) 3.000 6,935.9 6,430.8 31.25 PACKER Baker 7" x4,5" SAB3 Retainer Production Packer (LTC Box Down) 3.250 GAS LIFT, 6,639 - 6,946.4 6,439.7 3128 XO-Reduc.ing Crossover 4.5" LTC Box x 3.5" EUE 8rd Pin 3.500 6,983.8 6,471.6 31.09 NIPPLE 2.813" 'XN' Nipple (2.75" No-Go) 2.750 NIPPLE, 608 FL 7549.1 6,527.4 31.59 WLEG Wireline Entry Guide 4.18" 0.0. 2.992 IT difiiiiiiTCOiel ' iiiiiiiiiiiiiiiiiiiYiiii4ifi,Iliiiiiiiilliitit Iiii.fftW:#7,1=42.5,3 Top Depth 1 I r (TVD) Top Ind Top (MB) (MB) (I Daacriptip, Comment Run Date ID (in) LOCATOR, 1 VI i 7,400 FISH 1 1/7 OV 1.5" OV LOST 2/24/2006 2/24/2006 6,928 PBR, 5,922 16. t 7,473 FISH 1 1/2" DV & TG Latch Dropped to Rathole 12/16/1986 12/16/1986 SEAL ASSY, S - 1---=i44-4igi, SEAL ASSY, 8,935 ; -,-. Shot is or PACKER, 6.936 ad; Top (TVD) Btm (TVD) Dens Top (MB) Btm (MB) (MB) (ftl(E) Zone Date OR- Type Comment '11 1 7,279 7,297 6,723.4 6,738.7 A-3, 3K-09A 9/27/1987 8.0 RPERF 2 1/8" Silver Jet, 60 ph 1 7,284 7,284 6,727.7 6,727.7 A-3, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph 7,289 7,289 6,731.9 6,731.9 A-3, 3K-09A 12/14/1986 1.0 IPERF 21/8" EnerJet, 0 deg ph XO 7,292 7,292 6,734.5 6,734.5 A-3, 3K-09A 12/14/1986 1.0 IPERF 21/8" EnerJet, 0 deg ph 6,506 ti 7,294 7,294 6,736.2 6,736.2 A-3, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph I 7,310 7,326 6,749.8 6,763.4 A-2, 3K-09A 9/27/1987 8.0 RPERF 2 1/8" Silver Jet, 60 ph 7,315 7,315 6,754.0 6,754.0 A-2, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph NIPPLE, 6,984 1111 7,325 7,325 6,762.5 6,762.5 A-2, 3K-09A 12/14/1986 1.0 IPERF 21/8" EnerJet, 0 deg ph 1 7,333 7,333 6,769.3 6,769.3 A-2, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg Ph WLEG, 7,049 IL 7,339 7,339 6,774.4 6,774.4 A-2, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph 7,344 7,344 6,778.7 6,778.7 A-2, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph 7,348 7,352 6,782.1 A-2, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph !PERE, 7,294 - 7,359 7,363 A 3K 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph r .----- - - RPERF. . - _ 7,279-7,297 --,... "- - - Ntitii & Safety: --- 7 - -;:' ,,, F: - -';' - i' ., i' 5- ,F - v1 . 5=E - 5 , = - UV;Y-..f.!}:';' -- ''::6 - 3 - :* - -'nlii. -, i. r asZ5 1 4 IPERF, 7,289 End Date Annotation - ..t- -. - --.= , - 9/20/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 MERE, 7,292 .,_ - IPERF. 7,294 ----,-- = - ... - M- . =- - - IPERF, 7,365 "......_=- 7,3104,326 ------.-=`--- IPERF, 7,325 7=d- - = - -=E - ---- - ___ =_- - IPERF, 7,333 IPERF, 7,339 - _ IPERF, 7,344 Top Depth Top Pod (TVD) Ind OD Valve Latch Ste TRO Run MERE, Stn Top (MB) (M) (") Make Model (In) Sera Type Type (In) (psfi Run Date Com.- 7,348 1 2,396.3 2,3962 2.10 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,346.0 9/28/2008 2 3,532.7 3,523.8 11.53 CAMCO MMG 1 1/2' GAS LIFT GLV RK 0.188 1,327.0 9/28/2008 IPERF. --" - 7 _ 3 4,606.5 4,510.4 37.11 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/2/2008 7. 7 4 5,586.4 5,305.4 34.86 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,307.0 9/28/2008 5 6,307.0 5,900.3 33.83 CAMCO MMG 1112 GAS LIFT DMY RK 0.000 0.0 9/2/2008 FISH, 7,400 6 6,839.0 6,348.4 32.17 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.188 0.09/27/2008 FISH, 7,473 I PRODUCTION, TD (21 \ ORIGINAL 7,580 • • C onocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3K Pad 3K-09 3K- 09BL2 -01 Plan: 3K- 09BL2 -01 wp03 -= I Standard Planning Report 05 April, 2010 ISR1 BAKER HUGHES • ConocoPhillips laki ConocoPhi lips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Site Kuparuk 3K Pad Company:- = ConocoPhillips(Alaska) Inc. TVD Reference: - Mean Sea Level Project Kuparuk River Unit MD Reference: 3K-09 © 69.00ft (3K -09) Site: Kuparuk 3K Pad North Reference: True Well: - - -- 3K - 09 Survey Calculation Method: Minimum Curvature Welibore: 3K 09BL2 - 01 Design: - 3K 09BL2 01_wp03 = 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 Site = Kuparuk 3K Pad Site Position: Northing: 6,008,428.74ft Latitude: 70° 26' 2.781 N From: Map Easting: 529,306.18ft Longitude: 149° 45' 39.930 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.23 ° Well -_ -- 3K-09 Well Position +N / -S - 200.11 ft Northing: 6,008,228.65ft Latitude: 70° 26' 0.812 N +E/ - - 1.04 ft Easting: 529,305.92 if Longitude: 149° 45' 39.960 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft 1 Wellbore - 3K 09BL2 - 01 Magnetics Model Name =- Sample Date Declination Dip Angle Field Strength r) ( (nT) BGGM2009 7/15/2010 17.14 79.87 57,394 Design, 3K- 09BL2- 01 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,700.00 _Vertical Section: - Depth From (TVD) +N -S +E1 W Direction " (ft) _ _ (ft) (it) r) - 0.00 - 200.11 - 1.04 214.00 Plan Sections Measured TVD Below - Dogleg Build Turn - - - -_ Depth Inclination Azimuth _ System +N!.S +E! -W Rate = Rate _ Rate - TFO - (ft) ('1 _ ( °) - (ft) (ft) - (ft) ( °11008) - (1100ft) (°/100ft) (°) = Target 7,700.00 86.22 236.03 6,702.17 - 488.90 1,811.73 0.00 0.00 0.00 0.00 7,715.00 89.22 236.03 6,702.77 - 497.27 1,799.30 20.00 20.00 0.00 0.00 7,770.00 100.22 236.03 6,698.26 - 527.85 1,753.91 20.00 20.00 0.00 0.00 7,815.00 100.09 226.89 6,690.31 - 555.42 1,719.31 20.00 -0.28 -20.32 270.00 7,965.00 90.05 211.87 6,676.99 - 670.53 1,625.03 12.00 -6.69 -10.01 237.00 8,090.00 88.50 196.95 6,678.58 - 784.03 1,573.53 12.00 -1.24 -11.94 264.00 8,340.00 89.95 226.91 6,682.05 - 993.76 1,442.82 12.00 0.58 11.99 87.50 8,390.00 90.47 232.89 6,681.86 - 1,025.95 1,404.59 12.00 1.04 11.95 85.00 8,715.00 93.51 193.98 6,670.11 - 1,291.72 1,228.98 12.00 0.94 -11.97 275.00 8,815.00 99.42 204.50 6,658.83 - 1,385.37 1,196.35 12.00 5.91 10.52 60.00 8,890.00 90.55 206.05 6,652.31 - 1,452.86 1,164.48 12.00 -11.82 2.08 170.00 9,075.00 84.90 227.55 6,659.73 - 1,599.99 1,054.49 12.00 -3.05 11.62 105.00 4/5/2010 9:39:32AM Page 2 COMPASS 2003.16 Build 69 I (_, g t, s f` t t ' 4T,. ConocoPhillips rag ConocoPhtmmmps Planning Report BAKER Alaska Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Site Kuparuk 3K Pad Company:, - _` ConocoPhillips(Alaska) Inc. TVD Reference: , -- Mean Sea Level Project , Kuparuk River Unit MD Reference: _ 3K -09 © 69.00ft (3K -09) Site: - Kuparuk 3K Pad North Reference: . True Well: 3K - 09 Survey Calculation Method: -- Minimum Curvature Welibore: - - 3K 09BL2 - 01 Design: = 3K 09BL2 - 01 _wp03 Planned Survey - Measured - ` TVD Below Vertical - Dogleg Toolface Map Map Dept Inclination- Azimuth System _ + -s . - _ +Et W Section Rate Azimuth Northing -' Fasting (ft) (°) (°) (ft) Mr- - (ft) (ft) (°/100ft) (1 (ft) -- (ft) ='- 7,700.00 86.22 236.03 6,702.17 - 488.90 1,811.73 - 774.28 0.00 0.00 6,007,947.02 531,119.6 TIP / KOP 3K - 09BL2 1 7,715.00 89.22 236.03 6,702.77 - 497.27 1,799.30 - 760.39 20.00 0.00 6,007,938.60 531,107.24 1 2 7,770.00 100.22 236.03 6,698.26 - 527.85 1,753.91 - 709.65 20.00 0.00 6,007,907.84 531,061.98 3 7,800.00 100.16 229.93 6,692.94 -545.62 1,730.35 -681.74 20.00 -90.00 6,007,889.98 531,038.49 7,815.00 100.09 226.89 6,690.31 - 555.42 1,719.31 - 667.44 20.00 -91.08 6,007,880.14 531,027.48 End of DLS 20 7,900.00 94.44 218.32 6,679.54 - 617.42 1,662.34 - 584.18 12.00 - 123.00 6,007,817.92 530,970.76 7,965.00 90.05 211.87 6,676.99 - 670.53 1,625.03 - 519.29 12.00 - 124.09 6,007,764.67 530,933.67 5 8,000.00 89.61 207.69 6,677.10 - 700.90 1,607.65 - 484.40 12.00 -96.00 6,007,734.23 530,916.41 8,090.00 88.50 196.95 6,678.58 - 784.03 1,573.53 - 396.40 12.00 -95.99 6,007,650.98 530,882.62 6 8,100.00 88.55 198.14 6,678.84 - 793.56 1,570.52 - 386.82 12.00 87.50 6,007,641.44 530,879.64 8,200.00 89.11 210.13 6,680.89 - 884.63 1,529.70 - 288.50 12.00 87.47 6,007,550.22 530,839.19 8,300.00 89.71 222.12 6,681.93 - 965.24 1,470.86 - 188.75 12.00 87.22 6,007,469.38 530,780.67 i 8,340.00 89.95 226.91 6,682.05 - 993.76 1,442.82 - 149.44 12.00 87.10 6,007,440.76 530,752.75 7 8,390.00 90.47 232.89 6,681.86 - 1,025.95 1,404.59 - 101.37 12.00 85.00 6,007,408.42 530,714.65 8 8,400.00 90.58 231.70 6,681.77 - 1,032.06 1,396.68 -91.88 12.00 -85.00 6,007,402.28 530,706.76 8,500.00 91.60 219.74 6,679.86 - 1,101.74 1,325.23 5.84 12.00 -85.01 6,007,332.33 530,635.60 8,600.00 92.55 207.77 6,676.23 - 1,184.68 1,269.81 105.59 12.00 -85.24 6,007,249.18 530,580.50 8,700.00 93.40 195.78 6,671.02 - 1,277.25 1,232.83 203.01 12.00 -85.67 6,007,156.48 530,543.89 8,715.00 93.51 193.98 6,670.11 - 1,291.72 1,228.98 217.16 12.00 -86.30 6,007,141.99 530,540.10 9 I 8,800.00 98.55 202.90 6,661.17 - 1,371.81 1,202.31 298.47 12.00 60.00 6,007,061.81 530,513.751 8,815.00 99.42 204.50 6,658.83 - 1,385.37 1,196.35 313.05 12.00 60.94 6,007,048.22 530,507.85 10 8,890.00 90.55 206.05 6,652.31 - 1,452.86 1,164.48 386.83 12.00 170.00 6,006,980.61 530,476.24 11 8,900.00 90.24 207.21 6,652.24 - 1,461.80 1,160.00 396.74 12.00 105.00 6,006,971.66 530,471.79 9,000.00 87.15 218.81 6,654.52 - 1,545.49 1,105.63 496.52 12.00 105.01 6,006,887.77 530,417.76 9,075.00 - 84.90 227.55 6,659.73 . - 1,599.99 1,054.49 570.31 12.00 104.74 6,006,833.06 530,366.84 TD 4/5/2010 9:39.32AM Page 3 COMPASS 2003.16 Build 69 ' ! n1 ConocoPhillips 1 ConocoPhddlips Planning Report BAKER ,Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Site Kuparuk 3K Pad Company: - = ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project: ` � Kuparuk River Unit MD Reference: 3K -09 © 69.00ft (3K -09) Kuparuk 3K Pad North Reference: True Well: _ 3K - 09 Survey Calculation Method: Minimum Curvature Wellbore: - 3K 09BL2 - 01 Design: 3K 09BL2 01_wp03 Targets F Target Name - hit/miss target - -` Dip Angle Dip Dir. _ TVD - +141/4 +E/ -W Northing Feting Shah ( °)` ( °) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3K- 09BL2, BL2 -01 Po 0.00 0.00 0.00 - 142.25 1,911.14 6,008,294.02 531,217.67 70° 26' 1.379 N 149° 44' 43.849 W - plan misses target center by 6701.04ft at 7900.00ft MD (6679.54 TVD, - 617.42 N, 1662.34 E) - Polygon Point 1 0.00 - 142.25 1,911.14 6,008,294.02 531,217.67 Point 2 0.00 - 173.07 2,122.04 6,008,264.03 531,428.67 Point 3 0.00 - 383.88 2,067.22 6,008,053.03 531,374.69 Point 4 0.00 - 551.36 1,928.56 6,007,885.02 531,236.70 Point 5 0.00 - 908.37 1,662.14 6,007,527.01 530,971.71 Point 6 0.00 - 1,785.35 1,116.69 6,006,647.98 530,429.76 Point 7 0.00 - 1,582.09 797.44 6,006,849.96 530,109.75 Point 8 0.00 - 696.19 1,364.93 6,007,738.00 530,673.70 Point 9 0.00 - 407.03 1,588.08 6,008,028.00 530,895.69 Point 10 0.00 - 142.25 1,911.14 6,008,294.02 531,217.67 3K- 09BL2, BL2 -01 fat. 0.00 0.00 0.00 - 321.15 1,630.41 6,008,114.03 530,937.67 70° 25' 59.620 N 149° 44' 52.088 W - plan misses target center by 6685.45ft at 7938.37ft MD (6677.44 TVD, - 648.25 N, 1639.60 E) - Polygon Point 1 0.00 - 321.15 1,630.41 6,008,114.03 530,937.67 Point 2 0.00 - 518.72 1,771.66 6,007,917.04 531,079.68 Point 3 0.00 - 723.35 1,929.88 6,007,713.05 531,238.69 Point4 0.00 - 518.72 1,771.66 6,007,917.04 531,079.68 3K- 09BL2 -01 t5 0.00 0.00 6,660.00 - 1,599.99 1,054.29 6,006,833.06 530,366.64 70° 25' 47.044 N 149° 45' 8.998 W - plan hits target center - Point 3K- 09BL2 -01 t3 0.00 0.00 6,669.00 - 1,303.64 1,225.48 6,007,130.06 530,536.65 70° 25' 49.958 N 149° 45' 3.974 W - plan hits target center - Point 3K- 09BL2 -01 t2 0.00 0.00 6,682.00 - 992.48 1,443.74 6,007,442.05 530,753.66 70° 25' 53.018 N 149° 44' 57.569 W - plan hits target center j - Point 3K- 09BL2 -01 t1 0.00 0.00 6,677.00 - 683.13 1,616.98 6,007,752.04 530,925.67 70° 25' 56.060 N 149° 44' 52.484 W - plan hits target center - Point 3K- 09BL2, BL2 -01 fai 0.00 0.00 0.00 - 1,133.78 1,012.12 6,007,299.06 530,322.65 70° 25' 51.629 N 149° 45' 10.234 W - plan misses target center by 6661.70ft at 8890.00ft MD (6652.31 TVD, - 1452.86 N, 1164.48 E) - Polygon Point 1 0.00 - 1,133.78 1,012.12 6,007,299.06 530,322.65 Point2 0.00 - 1,305.62 1,223.48 6,007,128.07 530,534.66 Point 3 0.00 - 1,457.34 1,404.91 6,006,977.08 530,716.67 Point4 0.00 - 1,305.62 1,223.48 6,007,128.07 530,534.66 3K- 09BL2 -01 t4 0.00 0.00 6,652.00 - 1,461.40 1,159.85 6,006,972.06 530,471.65 70° 25' 48.407 N 149° 45' 5.901 W - plan hits target center - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name ( - ( " ) 3,172.00 3,100.46 10 3/4" 10 -3/4 13-1/2 9,075.00 6,659.73 2 3/8" 2 -3/8 3 4/5/2010 9:39:32AM Page 4 COMPASS 2003.16 Build 69 ' t I A i ConocoPhillips Fail ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: -'- Site Kuparuk 3K Pad Company: -- := ConocoPhillips(Alaska) Inc. TVD Reference: - Mean Sea Level Project Kuparuk River Unit MD Reference: 3K-09 © 69.00ft (3K -09) Site: Kuparuk 3K Pad North Reference: True Well: 3K Survey Calculation Method: Minimum Curvature Wellbore: 3K 09BL2 - 01 Design: = - = 3K 09BL2 01_wp03 Plan Annotations Measured:- Vertical Local Coordinates - - Depth Depth'- - +NlS +E/-W (ft) (ft) (ft) . (ft) Comment _ _ 7,700.00 6,702.17 - 488.90 1,811.73 TIP / KOP 3K -09BL2 7,715.00 6,702.77 - 497.27 1,799.30 2 7,770.00 6,698.26 - 527.85 1,753.91 3 7,815.00 6,690.31 - 555.42 1,719.31 End of DLS 20 7,965.00 6,676.99 - 670.53 1,625.03 5 8,090.00 6,678.58 - 784.03 1,573.53 6 8,340.00 6,682.05 - 993.76 1,442.82 7 8,390.00 6,681.86 - 1,025.95 1,404.59 8 8,715.00 6,670.11 - 1,291.72 1,228.98 9 8,815.00 6,658.83 - 1,385.37 1,196.35 10 8,890.00 6,652.31 - 1,452.86 1,164.48 11 9,075.00 6,659.73 - 1,599.99 1,054.49 TD i 4/5/2010 9:39:32AM Page 5 COMPASS 2003.16 Build 69 Pzinuewm Tne NoM WELLBORE DETAILS: 3K- 09BL2 -01 REFERENCE INFORMATION �°°' Project: Kuparuk RiverUnk Merrerc No 21.&5° Site: Kuparuk3K Pad 0 Coordnate (NIE) Reference: Well3K -09, True North Magnetic 5767 Parent & en P io MD 7 � � '` Well: 3K Strength netic a n Vertical (ND) Reference: Mean Sea Level '` Tie on MD: 7700.00 Vertical WaBbore: 3K 09BL2 -01 pAngle. a0.9r Date. Section (VS) Reference: Slot- PAN 0 . 00 E) Pl L2 ip n Measured Depth Reference: 3K -09 @ 69.00f! (3K-09) � COn© ips PIan:3K -096L2 - 01 re: 31 3 9B1.2 -096L2 - 01j D nmae BD Calculation Method Minimum Curvature HUGHES -100 - � I ! -200 . WELL DETAILS: 3K-09 : ' . ' : 2, . ' ' Ground Level: 0.00 -300 3- +N / -S +E / -W Northing Easting Latitude Longitude Slot . TIP /KOP3K -09BL2 0.00 0.00 6008226.65 529305.92 70° 26' 0.812 N 149° 45' 39.980 W , - - ! -400 , SECTION DETAILS ANNOTATIONS 5 End of DLS 20 - 500 Sec MD Inc Azi TVDSS +N/-S +E) -W DLeg TFace VSec Target Annotation 6 1 7700.00 86.22 236.03 6702.17 - 288.78 1812.77 0.00 0.00 - 774.28 TIP / KOP 3K -09BL2 2 7715.00 89.22 236.03 6702.77 - 297.16 1800.35 20.00 0.00 - 760.39 2 - 600 - 3 7770.00 10022 236.03 6698.26 - 327.74 1754.96 20.00 0.00 - 709.65 3 S ' 4 7815.00 100.09 226.89 6690.31 -355.31 1720.35 20.00 270.00 -667.44 End ofDLS20 _700- 5 7965.00 90.05 211.87 6676.99 -470.42 1626.07 12.00 237.00 - 519.29 5 6 8090.00 88.50 196.95 6678.58 -583.91 1574.57 12.00 264.00 -396.40 6 y. 7 8340.00 89.95 226.91 6682.05 - 793.65 1443.86 12.00 87.50 - 149.44 7 0 - 800 8 i 8 8390.00 90.47 232.89 6681.86 - 825.84 1405.63 12.00 85.00 - 101.37 8 9 8715.00 93.51 193.98 6670.11 - 1091.61 1230.03 12.00 275.00 217.16 9 + -900- . 111111 10 6815.00 99.42 204.50 6658.83 -118526 1197.40 12.00 60.00 313.05 10 - ' ' 11 8890.00 90.55 206.05 6652.31 - 1252.75 1165.52 12.00 170.00 386.83 11 ..4 12 9075.00 84.90 227.55 6659.73 - 1399.88 1055.54 12.00 105.00 570.31 TD -100 ° - 9 / • `-' - 10_ cn -1200- Li . 3K- 09/3K -09BL2 / ' „ M... -. -- -- --- -1300- j . • / -1400 - TD ' -1500 3K- 09/3K- 09BL2 -01 -1600- - - 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 ' West( -) /East( +) (100 ft/in) 6520- ' - - 3K- 09/7K- 09BL2 -01 6560- - - - -_ ! 6600 - _ _ _ . _ - - 11 6640_ 10 - TIP /KOP End ofDLS 20 5 ' 7 8 A- - - TD 6680 2 3 IL---/ _ , d 6720- - - - - _ - - __ - - _ - - - - - - - - I • 3K- 09/3K -09BL2 - a y 6760- - ! ! I - U_ rd � . _ y a 6800 . 6840- H i 6880 6920 6960 � ! -800 -760 -720 -680 -640 -600 -560 -520 -480 -440 -400 -360 -320 -280 -240 -200 -160 -120 -80 -40 0 4 0 80 120 160 200 240 280320 360 400 440 480 520 560 600 6 _ 200 � 640 680 720 Vertical Section at 214.00° (40 ft/in) • Nabors CDR -2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing Lubricator Riser Annular/ Blind / Shear 2" Pipe / Sl (CT) Pump into Lubricator J L above BHA rams L % • r Choke 2 -3/8" Pipe / Slip (BHA) Choke Equalize Manifold �nY -3/8" Pipe / Shp (BHA) J Kill / \ % \ , ► r Blind ! Shear 2" Pipe / Slip (CT) Choke 2 Swab Valves Wing Valves bri Tree Flow Cross IR Surface Safety Valve BOPE: 7- 1/16 ", 5M psi, TOT Choke Line: 2- 1/16 ", 5M psi Master Valve Kill Line: 2- 1/16 ", 5M psi Equalizing Lines: 2- 1/16 ", 5M psi Choke Manifold: 3 -1/8 ", 5M psi Riser: 7- 1/16 ", 5M psi, C062 Union OR!GINAL • • TRANSMITTAL LETTER CHECKLIST WELL NAME Z l . 3 � -- (2? b3 l a _c I f PTD# Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD• 1Z i� �- x C F : L K r:2 "- -; ` !"v--- POOL: et. ' r 1-644 kj) i r� Ci 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 K c -- i( `( f (If last two digits in Permit No. 2- /(-5 6-) No. 50- tX - 2 / 6S -62_ 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(D, 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 through target 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. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 i • 0 N 0) 0 , , , , , a) c- u) co 2 o >. a) c o, c Q c o. ° z. W, N. y m. 0) N c ; o' o ' Y O ° p . m a as O � � N E N c) fn N' O. a) 0 ,`k c. � , I 6 a). N, Z p O U w Ulu a• I N' E� N. c' I a) E O N O) CO C O, a), Q N O U L' E. -co, ' � � I 110.E1 , co, toy � o N c"0,_.,1 ._� 1 0 c 3; o a N v v, co a O 3 ' c 1 co o p 0 @, a ° a) ° a) a) E' m, m, as, E Li) . °' C N a (0 O O� a m M � 0 � U� co. a 3 � � j� O N � O , O °� U. a O1 ' I N ~ _ W >i O O a) Q N N CO' � C. I C ') )' a C)' M. 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