Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
210-068
• • Image Project Well History File Cover Page 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. al 0 - ©bs Well History File Identifier Organizing (done) Two -sided 111 11111 111111111 ❑ Rescan Needed 1 1 11111111111 RE A N DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: ❑ Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: 0 „ / a /s/ u Project Proofing I IIIIIIIt 11111 ! g BY: C Maria Date: (P /ca 7/42. Isi MC Scanning Preparation I x 30 = 3 0 + 3 = TOTAL PAGES 3 3 n (Count does not i nclude cover sheet) / 1 BY: C Maria Date: - a. / /s/ Production Scanning 111 11111111111 Stage 1 Page Count from Scanned File: - 3 I-" (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: (7-YES NO BY: Maria Date: /0:7 / a..., Is' 04 1 0 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: Is/ Scanning is complete at this point unless rescanning is required. 11 1 1 111 ReScanned 11111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked III II11111111111111 12/22/2011 Wet History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 6/18/2012 Permit to Drill 2100680 Well Name /No. KUPARUK RIV UNIT 3K- 09BL1 -01 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 029 - 21656 -63 -00 MD 8903 TVD 6724 Completion Date 6/12/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION "`a Mud Log No Samples No Directional Su y Yes 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 III Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments ED �is 19906 Induction /Resistivity 6528 8903 Open 7/27/2010 GR, ROP, RES Log Induction /Resistivity 2 Col 7863 8903 Open 7/27/2010 MD MPR, GR Log Induction /Resistivity 5 Col 7863 8903 Open 7/27/2010 MD MPR, GR Log re"' Induction /Resistivity 5 Col 7863 8903 Open 7/27/2010 TVD MPR, GR ED / Directional Survey 7860 8903 Open RptW Directional Survey 7860 8903 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION • Well Cored? Y) Daily History Received? , Y // Chips Received? - 1 7 717 — Formation Tops `r'"' N Analysis q-{4 Received? Comments: Compliance Reviewed By: ` Date: • 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 ❑ 1b. 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. or Aband.: June 12, 2010 210 - 0680 / 3. Address: 6. Date Spudded: 13. API Number. P. O. Box 100360, Anchorage, AK 99510 - 0360 May 31, 2010 50 029 - 21656 - 63 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 1, 2010 3K 09BL1 - 01 Top of Productive Horizon: 8. KB (ft above MSL): 69' RKB 15. Field /Pool(s): 1698' FSL, 2585' FEL, Sec. 35, T13N, R9E, UM GL (ft above MSL): 30' Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 2538' FSL, 2083' FEL, Sec. 35, T13N, R9E, UM 8897' MD / 6722' 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 8903' MD / 6724' TVD ADL 25519 TPI: x - 531682 y- 6008702 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 532179 y 6009544 Zone 4 2183' MD / 2183' TVD 2555 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 7863' MD / 6726' 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 7193' 8897' 6650' 6722' 3" solid /slotted liner 24. Open to production or injection? Yes 0 No ❑ 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: 7297' - 7953' MD 6739' - 6719' TVD _ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8203' - 8896' MD 6670' - 6722' TVD ; ' =MEM DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED f ' f� � �j $ 7033' 17 ppg cement -4 ar Y, r.. .....,f/ . 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 Q Sidewall Cores Acquired? Yes ❑ No EI 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 '! .; 3 2018 RBDMS JUL 0 3 2O1 - Aiaska Oil & Gas Cons. Compassion Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE Afl Suomi ri only /14- if c 28. GEOLOGIC MARKERS (List all formations and marrs 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 1700' 1700' needed, and submit detailed test information per 20 AAC 25.071. Top B 7863' 6726' Top A 7982' 6713' N/A Formation at total depth: Kuparuk A2 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 1 70. 7 ./a o Printed Nam V. Ca Title: Alaska Wells Manager Signature t Phone 265 - 6306 Date b Sharon llsup -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 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 , KUP • 3K- 09BL1 -01 /li ° ? Wel Attributes Max Angle & MD TD Ala Inc, APIIUWI !Field Name Well Status Inc' (3 MD (ftKB( Act Btm (ftKB) ( _ 500292165663 KUPAR UK RIVER UNI I PROD Comrnent !H2S (ppm) Date !Annotation End Date KB - Grd (85 Rig Release Date SSSV 1 RDP Ij L 120 I 2/23/2009 i Last WO 6/17/2010 39 90 Well Config 3K - 0 61101201010.1E 31 AM .. _10/1711986 Schematic Actual Annotation Depth (ftKB) End Date Annotation Last Mod... End Date I Last lag. I 6/17/2010 I Rev Reason SIDETRACK, GLV C/O j Imosbor 6/17/2010 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) .. String Wt... String ... String Top Thrd BL1 -01 LINER 23/8 1.995 I 7,193.3 I 8,897.0 I 1 4.60 _ L-80 1 STL Liner D etails Top Depth (TVD( Top Inc! Nooti... Top (ftKB) (ftKB( (°) item Daeeription Comment ID (in) 7,193.3 DEPLOY Deployment sleeve 1.000 - - - - -- BILLET t' Perforations & Slots fi " Shot . Top (TVD) Btm (TVD) Dena HANGER, 35 ' �f Tom ftKB Ban (PoCB) (ftKB( (ftKB) Zone Date (sh ... T • Comment 7,297 7,953 6/22010' SLOT Alternating solid /slotted pipe - 0.125 "x2.5' @ 4 circumferential adjacent rows, 3' centers staggered 1 ‘:: '. 18 deg, 3' non - slotted ends 8,203 8,896 6/2/2010 SLOT Alternating solid /slotted pipe - 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends l Notes: General & Safety End Date Annotation 6/ 11/2010 NOTE. VIEW SCHEMATIC w /Alaska Schematic9 0 CONDUCTOR, 38.110 SURFACE, 37 -3,172 TD (3K- 09BL1 -01), 3,172 PRODUCTION, 35 -7,559 . 1 SLOT, 7,297 -7,953 / /..,.� F, I ser Mandrel Details SLOT, I 1 __ .. -- Top Depth Top Port 8,203 -8,896 ) I (TVD) Inc! OD Valve Latch Size TRO Run o c Stn Top (ftKB) (RIM) ( °) Make Model (in) Sent/ TYPO Type (in) (pal) Run Date Can... 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 12 GAS LIFT OV rdo-20 0.250 0.0 6/16/2010 5 6,307.0 CAMCO MMG t 12 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 BL1 -01 LINER, 7,193 -8,897 Conoc�Phillip Alaska ' ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3K Pad 3 K- 09BL1 -01 50- 029 - 21656 -63 Baker Hughes INTEQ Fan • Definitive Survey Report BER HUGHES 22 June, 2010 ConocoPhillips VMS ConacaPhillr D efinitive Survey Report BAKER I Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate R eference: 3K - 09 I Project: Kuparuk River Unit TVD Reference: 3K -09 @ 69.00ft (3K -09) i Site: Kuparuk 3K Pad MD Reference: 3K -09 @ 69.00ft (3K -09) 1 Well: 3K - 09 North Reference: TRUE I 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 09BL1 - 01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( °) ( °) (nT) 1 BGGM2009 6/1/2010 17.19 79.87 57,389 Design 3K- 09BL1 -01 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,860.44 Vertical Section: Depth From (TVD) +N/-S +E/ -W Direction I (ft) (ft) (ft) r) III i 69.00 0.00 0.00 65.62 J 1 Survey Program Date From To Survey Survey (ft) (ft) Survey (Wellbore) Tool Name Description Start Date End Date 100.00 7,200.00 3K -09A GyroData (3K -09A) GYD -CT -CMS Gyrodata cont.casing m/s 3/9/2009 7,230.27 7,860.44 3K -09B (3K -09B) MWD MWD - Standard 5/21/2010 5/25/2010 7,863.00 8,865.02 3K- 09BL1 -01 (3K- 09BL1 -01) MWD MWD - Standard 6/1/2010 6/1/2010 6/22/2010 8:16:55AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips .ar Conoco Phillips Definitive Survey Report BAKER HUGHES Alaska j 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 1 Design: 3K - 09 _ _ W Database: EDM Alaska Prod v16 Survey I MD Inc Azi TVD TVDSS +N/-S +E/-W Map Map DLS vertical (ft) ( °) (1 (ft) (ft) (ft) (ft) No ft,ng (1100') Se(ft, °n Survey Tool Name Annotation • 7,860.44 88.04 51.53 6,726.23 6,657.23 462.95 2,375.84 6,008,700.88 531,679.69 8.39 2,355.11 MWD (2) TIP 3K - 09B 7,863.00 87.99 51.72 6,726.32 6,657.32 464.53 2,377.85 6,008,702.48 531,681.69 7.67 2,357.59 MWD (3) KOP 7,890.42 92.79 51.55 6,726.13 6,657.13 481.55 2,399.34 6,008,719.57 531,703.11 17.52 2,384.19 MWD (3) 7,920.56 96.64 48.71 6,723.66 6,654.66 500.80 2,422.39 6,008,738.91 531,726.08 15.85 2,413.13 MWD (3) 7,950.42 99.62 43.80 6,719.43 6,650.43 521.22 2,443.74 6,008,759.42 531,747.35 19.09 2,441.01 MWD (3) 7,980.52 102.12 39.14 6,713.75 6,644.75 543.36 2,463.31 6,008,781.63 531,766.83 17.32 2,467.97 MWD (3) I 8,010.36 101.97 34.75 6,707.52 6,638.52 566.68 2,480.85 6,008,805.01 531,784.28 14.40 2,493.57 MWD (3) 8,040.13 103.58 30.15 6,700.94 6,631.94 591.17 2,496.42 6,008,829.56 531,799.75 16.01 2,517.86 MWD (3) 8,070.13 105.06 35.44 6,693.51 6,624.51 615.60 2,512.16 6,008,854.05 531,815.39 17.78 2,542.28 MWD (3) 8,100.43 104.11 39.81 6,685.88 6,616.88 638.81 2,530.05 6,008,877.33 531,833.20 14.31 2,568.16 MWD (3) 8,130.28 101.18 43.68 6,679.34 6,610.34 660.53 2,549.44 6,008,899.13 531,852.50 16.01 2,594.79 MWD (3) 8,160.54 97.14 48.13 6,674.52 6,605.52 681.31 2,570.89 6,008,919.98 531,873.86 19.72 2,622.90 MWD (3) 8,190.44 93.65 46.27 6,671.71 6,602.71 701.53 2,592.73 6,008,940.29 531,895.62 13.21 2,651.14 MWD (3) 8,220.65 92.64 42.92 6,670.05 6,601.05 723.01 2,613.91 6,008,961.85 531,916.71 11.57 2,679.29 MWD (3) 8,250.74 94.02 48.39 6,668.30 6,599.31 743.99 2,635.38 6,008,982.92 531,938.09 18.72 2,707.51 MWD (3) 8,280.33 93.93 48.17 6,666.25 6,597.25 763.64 2,657.41 6,009,002.65 531,960.05 0.80 2,735.69 MWD (3) 8,310.53 92.55 44.22 6,664.55 6,595.55 784.51 2,679.17 6,009,023.60 531,981.72 13.83 2,764.11 MWD (3) 8,340.56 91.53 38.42 6,663.48 6,594.48 807.04 2,698.97 6,009,046.20 532,001.43 19.60 2,791.45 MWD (3) III 8,370.38 92.52 34.19 6,662.42 6,593.42 831.05 2,716.61 6,009,070.28 532,018.98 14.56 2,817.43 MWD (3) 8,400.47 91.53 37.09 6,661.36 6,592.36 855.48 2,734.13 6,009,094.78 532,036.40 10.18 2,843.47 MWD (3) 8,430.54 88.34 42.43 6,661.39 6,592.39 878.59 2,753.36 6,009,117.96 532,055.53 20.68 2,870.52 MWD (3) 8,460.56 86.68 45.27 6,662.70 6,593.70 900.21 2,774.13 6,009,139.66 532,076.22 10.95 2,898.37 MWD (3) 8,490.63 84.84 43.49 6,664.92 6,595.92 921.64 2,795.10 6,009,161.17 532,097.10 8.50 2,926.32 MWD (3) 8,520.65 82.74 38.14 6,668.17 6,599.17 944.22 2,814.60 6,009,183.82 532,116.51 19.05 2,953.39 MWD (3) 8,550.81 82.24 32.31 6,672.12 6,603.12 968.63 2,831.84 6,009,208.30 532,133.66 19.24 2,979.17 MWD (3) 8,580.41 83.51 27.12 6,675.79 6,606.79 994.13 2,846.39 6,009,233.86 532,148.11 17.92 3,002.95 MWD (3) 8,610.57 84.99 22.25 6,678.81 6,609.81 1,021.39 2,858.92 6,009,261.16 532,160.52 16.80 3,025.61 MWD (3) 8,640.73 86.44 16.86 6,681.07 6,612.07 1,049.72 2,868.98 6,009,289.53 532,170.47 18.46 3,046.47 MWD (3) 8,672.17 89.02 10.76 6,682.31 6,613.31 1,080.21 2,876.48 6,009,320.05 532,177.85 21.05 3,065.88 MWD (3) 8,700.33 90.80 5.67 6,682.36 6,613.36 1,108.07 2,880.50 6,009,347.92 532,181.76 19.15 3,081.04 MWD (3) 6/22/2010 8:16:55AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips NM ConocoPhillips Definitive Survey Report UCER 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 Wellbore: 3K - 09 Survey Calculation Method: Minimum Curvature ( Design: 3K - 09 Database:, EDM Alaska Prod v16 Survey MD Inc Az! TVD TVDSS +N/-S +E/ -W Northing Easting DLS Sect on • (ft) ( ^) ( ") (ft) (ft) (ft) (ft) (ft) (ft) ( ft) 1100') ( Survey Tool Name Annotation 8,730.65 86.04 359.72 6,683.19 6,614.19 1,138.32 2,881.92 6,009,378.17 532,183.07 25.12 3,094.83 MWD (3) 8,760.59 85.54 356.77 6,685.39 6,616.39 1,168.17 2,881.01 6,009,408.01 532,182.03 9.97 3,106.31 MWD (3) 8,790.41 80.12 358.29 6,689.11 6,620.11 1,197.71 2,879.73 6,009,437.55 532,180.64 18.87 3,117.35 MWD (3) 8,820.36 75.22 359.73 6,695.51 6,626.51 1,226.96 2,879.22 6,009,466.79 532,180.02 17.02 3,128.95 MWD (3) 8,850.44 70.04 359.69 6,704.48 6,635.49 1,255.66 2,879.08 6,009,495.48 532,179.76 17.22 3,140.67 MWD (3) 8,865.02 67.57 359.26 6,709.76 6,640.76 1,269.25 2,878.96 6,009,509.07 532,179.58 17.16 3,146.16 MWD (3) 8,903.00 67.57 359.26 6,724.25 6,655.25 1,304.35 2,878.50 6,009,544.17 532,178.99 0.00 3,160.24 PROJECTED to TD III 1 1 6/22/2010 8 :16 :55AM 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" 3 -1/2" Camco MMG gas lift mandrels @ 2396' 3533' 16" 62# H -40 shoe 4607' @ 110' MD 5586' 6307' .–...M110 TV' - �� 6839' 10 -3/4" 45.5# K -55 shoe @ 3172' MD tit ft • 43 3 -1/2" X Nipple @ 6888' MD (2.813" profile) r Baker PBR @ 6922' MD (4" ID) Top of liner 6965' Baker KBH -22 Anchor Seal Assembly @ 6935' MD (3.0" ID) Baker SAB3 Packer @ 6936' MD (4.0" ID) 2.813 " 'XN' Nipple @ 6984' MD (milled out to 2.80" min ID) = Perfs for Cement r- ---- 7033' - 7035' WLEG @ 7049' MD f Tubing Tail @ 7050' MD 2 - 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' 7250' - Bottom of Pilot Hole – -- - North Laterals A3 •sand erfs 7279' 3K- 09BL2: 8879' p T o f Bill - 7863' - 7297' MD A2 -sand perfs 7310' Iii ____ \ \ 3K - 09BL1: 10,034' - -------------------------------------- - 7326'MD .�. - -`_ --- – --- 7333' \�`\\ ` Top of Billet - 8059' 7344' _ - � ‘ \ \ y\ 3K -09B: TD - 9610' 7348' - 7352' 1 BOL - 9510' 7359' - 7363' _ - —. 7" 26# J -55 shoe @ -- " ; ,.. , __ ( 3K - 09BL1 - 01: 8897'1 7559' MD • 3K -09B Well Events Summary ill 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 06:00 10:00 4.00 0 2,211 COMPZ CASING PUTB P Rig up and run 66 joints slotted liner, aluminum billet and Inteq BHA 10:00 11:18 1.30 2,211 7,111 COMPZ CASING RUNL P RIH 11:18 12:30 1.20 7,111 10,044 COMPZ CASING RUNL P Correct at EOP flag, +40', 25K PUW, 15K RIW 12:30 12:54 0.40 10,044 7,220 COMPZ CASING TRIP P Stack weight at 10044'. Release from liner, 1.3 BPM, 4300 CTP. Continue PUH pumping down backside. 12:54 13:06 0.20 7,190 7,216 COMPZ CASING DLOG P Tie in to RA, -10' correction 13:06 14:36 1.50 7,216 0 COMPZ CASING TRIP P POOH, pumping down coil. 14:36 15:18 0.70 0 0 COMPZ CASING PUTB P At surface, flow check, lay down BHA 15:18 17:18 2.00 0 0 PROD3 DRILL CIRC P Stab back onto well and displace CT to fresh water, jeting stack and flushing surface lines. 17:18 17:48 0.50 0 0 PROD3 DRILL SFTY P Crew Change, PJSM 17:48 19:00 1.20 0 0 PROD3 DRILL SVRG P Grease Tree, and Choke Valves 19:00 00:00 5.00 0 0 PROD3 DRILL BOPE P Start BOP Testing State Witnessed: Chuck Scheve 05/31/2010 Complete BOP testing (10 hrs), PU /MU BHA 11, RIH, displace well back to flo -pro. Tag alluminum top billet 7863'. Sidetrack, drill ahead BL1 -01 lateral 7863'- 8310'. 00:00 05:00 5.00 0 0 PROD3 DRILL BOPE P BOP testing BOP testing complete 05:00 07:30 2.50 0 0 PROD3 STK PULD P Install check valves, Displace CT to KWF, MU Drilling BHA with res 07:30 09:30 2.00 0 6,700 PROD3 STK TRIP P RIH 09:30 10:00 0.50 6,700 6,750 PROD3 STK DLOG P Tie -in, +29' correction 10:00 11:30 1.50 6,750 7,200 PROD3 STK TRIP P Continue RIH, stop at window and circulate out KWF, 0.5 BPM at 4675 BHP 11:30 12:00 0.50 7,200 7,863 PROD3 STK TRIP P RIH and tag top of billet at 7863.4 with pump down. 24K PUW, 11K RIW 12:00 14:24 2.40 7,863 7,890 PROD3 STK KOST P Mill off billet. 1.4 BPM, 4060 CTP, 4450 BHP, 360 WHP. 1 FPH for one foot, 2 FPH for 1 foot, 3 FPH for 1 foot then 10 FPH, then 30 FPH 14:24 14:36 0.20 7,890 7,890 PROD3 STK KOST P PUH past billet then dry drift. Clean up and down. 14:36 16:00 1.40 7,890 8,010 PROD3 DRILL DRLG P Drilling ahead, 1.3 BPM, 4000 CTP, 4460 BHP, 360 WHP. 1 - 2K WOB, 200 -300 psi motor work for 100 -150 ROP 16:00 17:00 1.00 8,010 8,010 PROD3 DRILL WPRT P Wiper to window, 24K PUW Page 16 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 20:30 3.50 8,010 8,160 PROD3 DRILL DRLG P Drilling ahead, 1.3 BPM, 4000 CTP, 4460 BHP, 360 WHP. 1 - 2K WOB, 200 -300 psi motor work for 100 -150 ROP 30 -60 FPH 2 -3K WOB, drilling through B formation 20:30 21:30 1.00 8,160 8,160 PROD3 DRILL WPRT P Wiper trip to window, 23K PUW 21:30 23:30 2.00 8,160 8,310 PROD3 DRILL DRLG P Drilling ahead, 1.3 BPM, 4000 CTP, 4460 BHP, 360 WHP. 1 - 2K WOB, 200 -300 psi motor work for 100 -150 ROP 40 -80 FPH 2 -3K WOB, drilling through B formation 23:30 00:00 0.50 8,310 8,310 PROD3 DRILL WPRT P Wiper trip to window, 23K PUW 06/01/2010 TD BL1 -01 Lateral, 8903'. Lay in liner running pill, POOH killing well. PU /MU BL1 -01 liner. RIH 00:00 00:12 0.20 8,310 7,230 PROD3 DRILL DLOG P Tie in depth with RA marker. 0 correction. 00:12 00:42 0.50 7,230 8,310 PROD3 DRILL WPRT P RIH 11KRIW. 00:42 02:12 1.50 8,310 8,460 PROD3 DRILL DRLG P Drilling ahead, 1.3 BPM, 4000 CTP, 4500 BHP, 280 WHP. 1 - 2K WOB, 200 -300 psi motor work for 80 -100 ROP 02:12 03:36 1.40 8,460 8,460 PROD3 DRILL WPRT P Wiper trip to window, 23K PUW 03:36 05:06 1.50 8,460 8,610 PROD3 DRILL DRLG P Drilling ahead, 1.36 BPM, 4000 CTP, 4500 BHP, 230 WHP. 1 - 2K WOB, 200 -300 psi motor work for 80 -125 ROP 05:06 06:06 1.00 8,610 7,280 PROD3 DRILL WPRT P Wiper trip to window, 23K PUW 06:06 07:00 0.90 7,280 8,610 PROD3 DRILL WPRT P While RIH for wiper stacked weight at 7280' at .25 BPM. Shut down pump and ran by to 7350'. PUH at full pump rate. RBIH at .25 BPM and stack weight again. Able to get down with pump down. Continue wiper 07:00 08:18 1.30 8,610 8,760 PROD3 DRILL DRLG P Drilling ahead, 1.36 BPM, 4050 CTP, 4560 BHP, 250 WHP. 1 - 2K WOB, 200 -300 psi motor work 08:18 09:18 1.00 8,760 7,230 PROD3 DRILL WPRT P Wiper to window, 24K PUW 09:18 09:30 0.20 7,230 7,250 PROD3 DRILL DLOG P Tie in at RA, -3.5' 09:30 10:18 0.80 7,250 8,760 PROD3 DRILL WPRT P Wiper back in hole, Shut pump down through build. 10:18 11:30 1.20 8,760 8,902 PROD3 DRILL DRLG P Drilling ahead, 1.36 BPM, 4050 CTP, 4560 BHP, 250 WHP. 1 - 2K WOB, 200 -300 psi motor work 11:30 13:06 1.60 8,902 7,230 PROD3 DRILL WPRT P TD, Pump low /high vis sweeps, PUH for final tie -in 13:06 13:18 0.20 7,230 7,250 PROD3 DRILL DLOG P Tie in to RA, -1' correction 13:18 15:18 2.00 7,250 8,903 PROD3 DRILL WPRT P Wiper back to TD Page 17 of 26 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:18 16:03 0.75 8,903 7,350 PROD3 DRILL DISP P Tag TD at 8903'. Lay in liner running pill with alpine beads. Lay in KWF. Paint white flag at 7000' EOP and paint yellow flag at 5300' EOP 16:03 17:33 1.50 7,350 0 PROD3 DRILL TRIP P POOH Displacing well to KWF 17:33 18:03 0.50 0 0 PROD3 DRILL OWFF P At surface, perform flow check 18:03 18:33 0.50 0 0 PROD3 DRILL SFTY P Crew change, PJSM 18:33 19:03 0.50 0 0 PROD3 DRILL PULD P LD BHA 12 19:03 19:33 0.50 0 0 COMPZ CASING PUTB P Prep floor to run liner 19:33 19:48 0.25 0 0 COMPZ CASING PUTB P Start running Liner 19:48 20:03 0.25 0 0 COMPZ CASING SFTY P BOP drill, Shut down, talk about drill. 20:03 23:03 3.00 0 0 COMPZ CASING PUTB P Continue running liner 23:03 23:48 0.75 0 0 COMPZ CASING PUTB P MU Coil Track to liner and CT 23:48 00:00 0.20 0 COMPZ CASING RUNL P RIH 06/02/2010 RIH with BL1 -01 liner releasing liner at 8904' BOL, 7200' TOL. PUH tie in depth with -7' correction. Correct liner depths 8897' BOL, 7193' TOL. POOH displacing KWF. PU WS setting on depth 7150' TOWS. POOH displacing KWF. PU milling BHA, RIH, displace well to milling fluid. Start milling window #2 at 7150.5'. 00:00 00:45 0.75 2,000 7,047 COMPZ CASING RUNL P RIH with liner 00:45 01:00 0.25 7,047 7,047 COMPZ CASING RUNL P Correct depth to EOP flag, +34'. Record up and down weights 22K PUW, 15K RIW 01:00 01:30 0.50 7,047 8,904 COMPZ CASING RUNL P RIH, stop at 8904' CTMD. 3.5K WOB 01:30 01:45 0.25 8,904 6,698 COMPZ CASING RUNL P Release off liner 3800psi, 21K PUW, POOH, keeping well dead Remove liner length from CTMD= 1703.73' 01:45 02:00 0.25 6,698 6,691 COMPZ CASING DLOG P Tie in depth with gamma -7'. correction 02:00 03:30 1.50 6,691 0 COMPZ CASING RUNL P POOH Correct depth's to tie in. BOL= 8897', TOL 7193'. 03:30 03:45 0.25 0 0 COMPZ CASING OWFF P At surface. Monitor well for flow, PJSM 03:45 04:45 1.00 0 0 COMPZ CASING PUTB P LD BHA 13 04:45 05:30 0.75 0 0 PROD4 WHPST PULD P PU BHA 14 05:30 07:00 1.50 0 6,700 PROD4 WHPST TRIP P RIH 07:00 07:18 0.30 6,700 6,770 PROD4 WHPST DLOG P Tie in to formation, +28' correction 07:18 07:30 0.20 6,770 6,760 PROD4 WHPST WPST P RIH to 7170', 11K riw, PUH to setting depth at 7159.7', Top of whipstock at 7150', oriented HS. Pressure up at .5 BPM, set at 3900 CTP, stack down to 4K WOB. 07:30 09:06 1.60 6,760 0 PROD4 WHPST TRIP P POOH Page 18 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 99501 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 b 1�ei : a. 2 .:i i'da SI Zia C''iM C4rar11,31),: 0/0 -fir 3 96,5 ago -o't5 99 6(0 °'°' b Of o -6q5 • • An (IF Alta SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 V. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3K- 06BL1 -01 ConocoPhillips Alaska, Inc. Permit No: 210 -068 Surface Location: 1234' FSL, 317' FWL, Sec. 35, T13N, R9E, UM Bottomhole Location: 2332' FNL, 2248' FEL, Sec. 35, T13N, 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 wellbore 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. Seamount, Jr. Chair DATED this /0 day of June, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via e -mail) • STATE OF ALASKA 0 RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUN Q 2 2010 PERMIT TO DRILL 20 AAC 25.005 Alaska Oil & Gar Cuts. Commission 1a. Type of Work: 1 b. Proposed Well Class: Development - Oil Q • Service - Winj ❑ Single Zone ©• 1c. 40111300 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 09BL1 - 01 . 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 9345' TVD: 6660' Kuparuk River Field �� �/f 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): l' 0'(. Surface: 1234' FSL, 317' FWL, Sec. 35, T13N, R9E, UM ADL 25519 • Kuparuk River Oil Fjerfd , Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1691' FSL, 2595' FEL, Sec. 35, T13N, R9E, UM 2555 5/31/2010 Total Depth: 9. Acres in Property: 14. Distance to 2332' FNL, 2248' FEL, Sec. 35, T13N, R9E, UM 2560 Nearest Property: 7220 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 , 1350 • 16. Deviated wells: Kickoff depth: 7850 . ft. 17. Maximum Anticipated Pressures in prig (see 20 AAC 25.035) Maximum Hole Angle: 104° d Downhole: 4654 psig - Surface: 3863 psig , 18. Casing Procram: _ 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 2150' 7195' 6652' 9345' 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 ❑ Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements i0 21. Verbal Approval: Commission Representative: G. Schwartz Date: 5/29/2010 22. I hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265 - 110 2, Printed Name V. Cawvey Title Alaska Wells Manager Signature Phon 265 -63o6 Date G / z 1 74 / a Commission Use Only Permit to Drill API Number: Permit Approval See cover letter ,.,f (j 50-02, Number: .' 50- Q-. 21C--56 "C61 Date: /) I I D I ,U 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: Q' i - 5000 ( jcD( � Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No []' Other: 4; p . A --T;14 H2S measures: Yes Er No El Directional svy req'd: Yes [✓] No ❑ (4......:.....\ AV/ APPROVED BY THE COMMISSION DATE: / ^^ tt dna•l , COMMISSIONER Form 10 -401 (Revised 7/2009) This per it is valid for 2 • i nRo fA4 I (20 AAC 25.005(g)) Submit in Duplicate 6 • 5 1111����,,,ffff jjjj iii 111 LLLL....... -- , . �,. q - M-, Y om., • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 1,2010 Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill an additional lateral out of the quadrilateral proposed for the Kuparuk Well 3K -09A using the coiled tubing drilling rig, Nabors CDR2 -AC. Two of the CTD laterals will be drilled in a northeasterly direction and will target the A -sands in the fault blocks containing the 3K -05 and 3K -07 injection wells. This additional lateral is to pick up the missed footage in the A2 laterals that the 3K -09B and BL1 laterals missed. The other lateral pair will be drilled in a southwesterly direction across a highly baffling fault into the fault block containing the 3K -12 injection well. The original motherbore perforations will be cement squeezed prior to CTD operations and it is expected that the exposure to the reservoir in the near wellbore region from the CTD laterals will be sufficient to replace motherbore production. Attached to this application are the following documents: — Permit to Drill Application Form for 3K- 09BL1 -01 — Detailed Summary of Operations — Proposed Schematic — Directional Plans — BOP Schematic If you have any questions or require additional information please contact me at 907 - 265 -1102. Sincere James Ohlinger Coiled Tubing Drilling Engineer • • Permit to Drill Summary of Operations KRU 3K -09B, 3K- 09BL1, 3K- 09BL1 -01, 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 a liner -top aluminum billet for the KOP for the BL1 -01 lateral at —7,850' MD. 3K- 09BL1 -01 is to be completed with 2 -3/8" slotted liner from TD to —7195' MD in the original well bore. 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 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 Page 2 of 5 6/1/2010 • . Permit to Drill Summary of Operations KRU 3K -09B, 3K- 09BL1, 3K- 09BL1 -01, 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 a liner -top aluminum billet for the KOP for the BL1 -01 lateral at —7,850' MD. 3K- 09BL1 -01 is to be completed with 2 -3/8" slotted liner from TD to —7195' MD in the original well bore. 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 /z" 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. SPY ? 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 Page 2of5 R 1 G 1 NAl 6/1/2010 • Permit to Drill Summary of Operations Cont. KRU 3K -09B, 3i - O9BL1, 3K 09BL2, and 3K 09BL2 -01 c. Run the 2 slotted liner from TD to 7,850' MD. An aluminum liner top billet will be placed at -7,850' MD. 7. 3K- 09BL1 -01 Lateral a. Kick off of the aluminum liner top billet at -7,850' MD . b. Drill a 2.70" x 3" bi- center lateral to a TD of 9,345' MD . c. Run the 2%" slotted liner from TD to -7,195' MD, into the pilot hole inside the 7" casing 8. Set top of whipstock at 7,150' MD. 9. Mill 2.80" window at 7,150'. 10. 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. 11. 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 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 bad 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 -01 6,970 9,075 2'/ ", 4.7 #, L -80, ST -L slotted Page 3 of 6 ORIGINAL 6/1/2010 • Permit to Drill Summary of Operations Cont. KRU 3K -098, 3K-09BL1, 3K- 09BL2, and 3K- 09BL2 -01 Existing Completion Details: Category - OD Weight Grade Top Btm Burst. Collapse 9 rY 9 P se p (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'/z" 9.3 L -80 0 6,940 10,160 10,530 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 preventerwill 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- 09BL2 -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. Page 4 of6 ORIGINAL 6/1/2010 • • Permit to Drill Summary of Operations Cont. KRU 3K -09B, 3K- 09BL1, 3K 09BL2, and 3K 09BL2 -01 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 H 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 5 of 6 ; R 1 G l A L 6/1/2010 • Permit to Drill Summary of Operations Cont. KRU 3K -09B, 3K- 09BL1, 3K- 09BL2, and 3K- 09BL2 -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 Tess 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 Mud ±ECD Combined 4068 psi 3384 psi (no choke pressure) (underbalanced (underbalanced —412 psi) —553 psi) Target Pressure (13.3 ppg) 4500 psi 4500 psi Choke Pressure Required to Maintain 13.3 432 psi 1116 psi ppg Example: 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" a -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 I' —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 r/ EMW to promote welibore stability. Page 6 of 6 i t G 1 N A L 6/1/2010 3 -1/2" TRMAXX -5E SCSSV @ 2,183' MD ID = 2.81 2" aav 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface ID = 2.992" 16" 62# H -40 shoe @ II 110' MD 3 -1/2" Camco MMG gas lift mandrels © 2396' J �� 3533' 4607' 9 -5/8" 36# J -55 shoe 5586' @ 3172' MD 6307' 6839' • 3 -1/2" X Nipple © 6888' MD (2.81 3" profile) w -- r .—. " Baker PBR @ 6922' MD (4" ID) Baker KBH -22 Anchor Seal Assembly @ 6935' MD (3.0" ID) Packer to = = Perfs for Cement Baker SAB3 Packer @ 6936' MD (4.0" ID) Tubing Tail = 104' , - r1 L - t- 7033' - 7035' 2.813 " 'XN' Nipple @ 6984' MD (2.75" min ID) G WLEG @ 7049' MD i Tubing Tail to Tubing Tail@ 7050' MD Top of Whipstock = 100' 1 2 -5/8" Openhole anchor /whipstock @ 7150' \\ 11, South Laterals KOP - 7700' I I3K- 09BL2 -01: 9075' WP03 2 -5/8" Openhole anchor /whipstock @ 7200' __ I �+►... • 7250' - Bottom of Pilot Hole 3K -09BL2 9075' W P06 A3 -sand perfs 7279' N North Laterals 7297 MD ----:" ___________ ' `\ KOP - 8059' - A2 -sand perfs 7310' ' N - �--- - 7326' MD �N...� --- - 7333' N t 7339' _ \ , 3K- 09BL1: 10,050' WPM 344' _ _ `∎1 `� .�) 7348' - 7352' x KNyti.\\............,... 7 359' - 7363' _ �_- PBTD @ 7410' _ _ 3K -096: 9975' WP06 7" 26# J -55 shoe @ 7559' MD _-..■1111111 KO - 7850' 3K- 09BL1 -01: 9345' WP07 --0-- 31C-09BL 1 -0 1 Surrer; BL1-01 WF'7 •••':'''■F' nent Well 3K-09A ConoccoPhilli Well 3K-1 9BIA-01 Meastuse(II)ep --0— 31(-0913 Surpey5 — 7. — 3K-09BL1 auvey..; —Top A6 Stnictiffal Cross-Section Interpr ---- Top A3 —Top A2 ---- -Baie A2 pay Leger To P.b each F mit 5 • T arcet:. r - -- --- - 5 ..ti. . \ 1 : -; .': -' ' I !-- :- -.-- , - ` - ! - -',' .„,„ H.„L.,,, , r..II • i — • . ■ r e, t , .e '''''''' " :. ' ' j e : ' : ' 1 I elmeeti ''''' '' s "..' % — — — I 1 - — e •-• '' a — ,.. " ' 1 '' .: — — ——. - — ' :' — i ' —' " 1 .4 e — — — - 7 7 '. 7 - 7 ' r' 7 7 ''' - ' ' ' 7 ' 7 4 - - :- ,- -4 - - r - -- • -; --; - - Parent Well , -'--, `-, - , - : ; , *--- -....,, ,...., -.... ....,_ ...,. ... - - i - i - 4 - -',- -,- - ,- - - r - 7 - i — 7 7 : 7 -' —r — - i ' i — 4 - - -:-- -.: - .,,, . _ ■,.. . :... _ _ _ .2, _ ., , i _ _ E1 .115110 TIP I— —— ',— — I. - I.. — . — ..I - —:- —:— — • I f1111 -6575 I „ , i , III III 1 1. 1 / I I I I S I I r '- 11 ■ 4' ' `tr , ,,,,,.. - '' 1 .... I. 'I". '. .. ' r ..' t .... j 1 .. "' -I I ." ''': '. ' - * ■,,, 71 tC'''' ' ''''' ''''. " .. t . 3K - 0 9 A :::::::'-_ ....11-a- I_ 11 6i 7 7 -6600 — ii ' . . - . , . , . -.2-•T•E . -,.. 4, , I I I ,. ...., . bk, 4,y ., ■ 5 , ' , ..„...... .*.... - **"*"" - '- . ' .. I .. 1 ' - '. -' - '''“ l .. I t 1 " "7..” ' Th . . .: 'L.!' v ;'■ ' " I ; I ' . ^* - '. .. ',-. ' 0 '''7''' ''''''' "''.." may 11 ,, :; ... 0 .. 3:) 121 - 0 1.01•••=01. -- ...**.' .. ' .. 1 ....' r ..' .• ' r I 4 g' 'r - 4 • ( 4,,' • • 'lb, L - - . - l' 7 i -i• - i - - -; • : n : . - , -...- .. - 625-- --. t , 7 - t'-----, , ..).,„ • - - - - , ' , ... .. 1/1/1....IM . ' '......"""'".'""."' r,r.•anme• El ' .' ". ' ' ' 4 ... tik - - 4. - t ... - , - - 1 — '1 . :- . t - ,' - 1 '.. 7 - " ' ' 4 = 1 — - i 5) . • - - -N - - - - - - - - - -' - - - - - - 7 - ' , ' : - : ' • , - I- ., - . ,- - ....- , - , iglatik -,- ,- - _ . ...,.....J...:. _./ ; ' ll. -1, . ' 0...N f:. m ,...._,_ ' 4 , - - - - -, - , - - , 4 -, ,: 4, . ., .. 1,,, i t , t„,, , ,,.., 4-0;nt ,,_.-: -•,.. 1 ........ , , •,-,„. , • t' 1= i . t1 , :t1 - c ' : ". f.: 4. , ,,:,' 1 61 II' ■ 4, f"..- 4, r- ' , -6675 ---4-- .',, ' . . F.,..........,...... ...,....... ..... ...-..„-.....:,,,, . „,....,,,.... —.7..., I L. 1.. 1 - -t:. f r '' ' IE. • e ; ■ e e e e — I — — —■ — e — T .' ZEI i - . ' t 't"".r . , .1 /: ''' I -'- "4"1"1E.P" i 1 - -: - -:- -:- - - - ■• e ''''' : - - . - - '...-. -1 , - ..7 -,''''''"'"-• - -'„,,,,-' - -,-- I -,': - :- - ,. ',.- 1 - ' ' aitarstror-issr.. T - - -,- -,- -,- - I - - r " r 7 - - " - - r - r - T " -71- -,- - , , , -6700 —+--1 -- - . --, .--r--*- z, 7000 7200 7400 7600 7800 8000 8200 .400 8600 8800 9000 9200 9400 9r-00 9c»:' 1 n 0 00 10200 • 11.•rtical E i•z: ''. 7.7z Measured Depth 3K-09BL1-01 . AnntAlstoTrue NMn WELLBORE DETAILS: 3K- O9BL1 -01 REFERENCE INFORMATiON � Project Kuparuk River Unit v gnetioNodm21.71` Site: Kuparuk 3K Pad Nsgne cFioi Parent Wellbore: 3K -096 Co- ordinale (NIE) Reference: Well 3K -09, True North -- Well: 3K - so-engmazss Tie on MD: 7830.39 Vertical (ND) Reference: Mean Sea Level 5 {� Wellbore: 3K 098L1.01 iNpMgk:EO.gP SeGion(VS) Reference . Slot - (0.00N, 0.00E) Q o d l I1 1 Plan: 3k - 09BLI.01 wp07(3K 09t3K 09BLI.01) t Measured Depth Reference: 3K- 09@69.00rt(3K 09) Calculation Method: Minimum Curvature ` ,1 ,., 2550- -- WELL DETAILS: 3K -09 2400---- - Ground Level: 0.00 • +N / -S +E / -W Northing Easting Latittude Longitude Slot 2250-- - - -- -- 0.00 0.00 6008228.65 529305.92 70° 26' 0.812 N 149° 45 39.960 W ' SECTION DETAILS ANNOTATIONS 2100 / - Sec MD Inc Azi TVDSS +N / -S +EFW DLeg TFace VSec Target Annotation 1950- _ ' / -- - 1 7830.39 88.90 49.16 6656.43 443.78 2352.72 0.00 0.00 1018.72 TIP - 2 7850.00 88.34 50.71 6656.90 45640 2367.72 8.40 109.89 1034.69 KOP 3 7920.00 97.43 45.44 6653.38 503.03 2419.67 15.00 330.00 1092.85 3 1800 M 71 4 8010.00 101.82 32.49 663827 571.82 2475.38 15.00 290.00 1173.39 4 3K- 0913K 09BL1 -01 5 8088.11 104.00 44.30 6620.76 631.39 2522.54 15.00 78.00 1242.88 5 1650 -_ _ i .' 6 8168.11 95.39 52.79 660728 683.44 2581.58 15.00 135.00 1308.05 - 6 7 8308.11 94.32 31.74 6595.29 786.10 2674.86 15.00 268.00 1430.79 7 0 1 n� 8 8369.01 90.00 39.80 6593.00 835.42 2710.40 15.00 118.01 1487.44 8 "1500 - - -- 9 8439.01 85.09 49.09 6596.00 88528 2759.29 15.00 118.00 1547.95 9 11 10 8700.00 87.14 9.90 6614.39 1107.52 2884.90 15.00 271.50 1794.56 10 1350 - 11 8960.00 86.52 330.85 6629.35 1358.51 2842.36 15.00 268.00 2026.91 11 0 12 9055.00 84.17 344.95 6637.10 1446.00 2806.81 15.00 240.00 2102.71 12 1200 t 13 9135.00 7831 33435 6649.31 1 1520.01 1 2779.42 15.00 24000 2167.51 13 �-. i t t i 14 9214.51 90.00 332.00 6657.40 1590.46 2743.78 15.00 -11.46 2226.79 14 15 9345.00 87.66 35144 6660.09 1713.74 2703.05 15.00 97.00 2335.94 TD 1050- I V1 i 9, { 900 I 8, ) 7 ` _ I C D 750- - {- - 6, l - •- Ou 600 - - -- f - -- �._ 4- -- - • -I .......... i KOP 3 ' • 1 G) 450 -- - i - - '_. t -_ f - - j I �"� 1200 1350 1500 1650 1800 1950 21 2250 2400 2550 2700 2850 3000 3150 3300 3450 3600 3750 3900 6254 --7 - fi - -- _.. { - - � - 1 ± + a We - )/East( +) (150 ft/in) - - i . , , 6311 i I I 6350- - ! ,-- --- -} - - - -� - -- -- -,._ - -- - I ----- -- -- j- - 7 - I i ::: 0' - -1 - - O I `•'� 6501 - . - - Y N a � � 6551 9 __ + - , ' - - -- - -- -- __-- - -- - -- -- '3K 09 -d -098: 6601 ■ �� _�� - 9 -- t --- t t a - - - -- - -- - - -- - - T N ` � -- - - i -_ 4 _-j -- - ! - -- - .__. } _.. - - - - -0 -- �---�- 11 I2 13 1 3 093K:0961,4 6651 6711 I { 1� I (� I 1 1 a 1u/3K- 096Lt -01 6751 I 1 I ba - y - - - -- - -- J - - - - - - -- r - - � - -- - -a- ?-- - -..� - ----- - - *-- + -- - - -- rt --- - -- -- i � - -- - - : --- .._._. - ..--- --- -,- - -- - - - -- - -- 685 3K -09 1 -- - -- - - - -- * - .... -- =---- - - -`-- - - -- - - - -- � - - - _ _- __.... : 3K -' 3 -094 09.4 S i, 450 500 550 600 650 700 750 800 850 900 950 1000 1050 1100 1150 1200 1250 1300 1350 1400 1450 1500 1550 1600 1650 1700 1750 1800 1850 1900 1950 2000 2050 2100 2150 2200 2250 2300 2350 2400 2450 • • C onoc�Phillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3K Pad 3K -09 3K- 09BL1 -01 Plan: 3k- 09BL1 -01 wp07 Standard Planning Report 01 June, 2010 Fake BAKER HUGHES ORIGINAL ConocoPhillips Iran Cons coPhillips Planning Report BAKER ES Alaska Database: ` EDM Alaska Prod v16 Local Co- ordinate Reference.__ - Well 3K Company _ - ConocoPhillips(Alaska) Inc. TVD Reference: - -i Mean Sea Level Project ` Kuparuk River Unit -, MD Reference: 3K -09 @ 69.00ft (3K -09) Sits = Kuparuk 3K Pad North Reference: '_: True • Well: 3K - 09 Survey Calculation Method: Minimum Curvature Wellbore: 3K- 09BL1 -01 - _ Design: 3k- 09BL1 -01 wp07 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 0.00 ft Northing: 6,008,228.65ft Latitude: 70° 26' 0.812 N +E/ - 0.00 ft Easting: 529,305.92 ft Longitude: 149° 45' 39.960 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellborn - 3K- 09BL1 -01 Magnetics Model Name Sample Date Declination Dip Angle -- Field Strength = (°) (°} -- _ (nT) - BGGM2009 6/1/2010 17.19 79.87 57,389 Design 3k- 09BL1- 01_wp07 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,830.39 Vertical Section: Depth From (TVD) +N/-S +E/ -W Direction _ _ _ ( ( (ft) _ - (°) 0.00 0.00 0.00 14.50 Plan Sections - Measured - TVD Below Dogleg _ Build Turn Depth Inclination Azimuth System +N/-S +E/ -W Rate Rate Rate TFO - (ft)- ` ( °) ( °) (0) (ft) (ft) (1100ft) (1100ft) (° /100ft}- (°)° Target - 7,830.39 88.90 49.16 6,656.43 443.78 2,352.72 0.00 0.00 0.00 0.00 7,850.00 88.34 50.71 6,656.90 456.40 2,367.72 8.40 -2.86 7.90 109.89 7,920.00 97.43 45.44 6,653.38 503.03 2,419.67 15.00 12.98 -7.53 330.00 8,010.00 101.82 32.49 6,638.27 571.82 2,475.38 15.00 4.88 -14.39 290.00 8,088.11 104.00 44.30 6,620.76 631.39 2,522.54 15.00 2.79 15.12 78.00 8,168.11 95.39 52.79 6,607.28 683.44 2,581.58 15.00 -10.76 10.61 135.00 8,308.11 94.32 31.74 6,595.29 786.10 2,674.86 15.00 -0.77 -15.04 268.00 8,369.01 90.00 39.80 6,593.00 835.42 2,710.40 15.00 -7.09 13.23 118.01 8,439.01 85.09 49.09 6,596.00 885.28 2,759.29 15.00 -7.01 13.28 118.00 8,700.00 87.14 9.90 6,614.39 1,107.52 2,884.90 15.00 0.78 -15.02 271.50 8,960.00 86.52 330.85 6,629.35 1,358.51 2,842.36 15.00 -0.24 -15.02 268.00 9,055.00 84.17 344.95 6,637.10 1,446.00 2,806.81 15.00 -2.47 14.85 100.00 9,135.00 78.31 334.35 6,649.31 1,520.01 2,779.42 15.00 -7.34 -13.24 240.00 9,214.51 90.00 332.00 6,657.40 1,590.46 2,743.78 15.00 14.71 -2.96 -11.46 9,345.00 87.66 351.44 6,660.09 1,713.74 2,703.05 15.00 -1.79 14.90 97.00 6/1/2010 12 :01 :28PM Page 2 COMPASS 2003.16 Build 69 0 I0 011\1 n � . • ConocoPhillips • C Yea I onOCO Planning Report BAKER Database: - EDM Alaska Prod v16 Local Co- ordinate Reference: Well 3K - 09 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 Welt: 3K - 09 Survey Calculation Method: -- Minimum Curvature Welibore: - 3K 09BL1 - 01 Design: - 3k 09BL1 - 01 wp07 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map - - _- Depth - Inclination Azimuth System - " +BPS +E/-W Section Rate =- Azimuth - Northing- _ Easting _ (ft) ( °) ( °) (ft) (ft) (ft) (ft) ( °nooft) ( (ft) (ft) 7,830.39 88.90 49.16 6,656.43 443.78 2,352.72 1,018.72 0.00 0.00 6,008,681.62 531,656.64 TIP 7,850.00 88.34 50.71 6,656.90 456.40 2,367.72 1,034.69 8.40 109.89 6,008,694.30 531,671.60 KOP 7,900.00 94.83 46.95 6,655.52 489.27 2,405.32 1,075.93 15.00 -30.00 6,008,727.32 531,709.06 7,920.00 97.43 45.44 6,653.38 503.03 2,419.67 1,092.85 15.00 -30.10 6,008,741.14 531,723.36 3 8,000.00 101.36 33.94 6,640.28 563.62 2,470.01 1,164.11 15.00 -70.00 6,008,801.91 531,773.45 8,010.00 101.82 32.49 6,638.27 571.82 2,475.38 1,173.39 15.00 -71.88 6,008,810.13 531,778.79 4 8,088.11 104.00 44.30 6,620.76 631.39 2,522.54 1,242.88 15.00 78.00 6,008,869.89 531,825.71 5 8,100.00 102.74 45.59 6,618.01 639.58 2,530.71 1,252.84 15.00 135.00 6,008,878.10 531,833.85 8,168.11 95.39 52.79 6,607.28 683.44 2,581.58 1,308.05 15.00 135.30 6,008,922.16 531,884.54 6 8,200.00 95.21 47.99 6,604.33 703.68 2,606.04 1,333.76 15.00 -92.00 6,008,942.49 531,908.91 8,300.00 94.40 32.96 6,595.91 779.26 2,670.53 1,423.09 15.00 -92.44 6,009,018.32 531,973.10 8,308.11 94.32 31.74 6,595.29 786.10 2,674.86 1,430.79 15.00 -93.71 6,009,025.17 531,977.40 7 8,369.01 90.00 39.80 6,593.00 835.42 2,710.40 1,487.44 15.00 118.01 6,009,074.62 532,012.75 8 8,400.00 87.82 43.91 6,593.59 858.49 2,731.06 1,514.95 15.00 118.00 6,009,097.77 532,033.32 8,439.01 85.09 49.09 6,596.00 885.28 2,759.29 1,547.95 15.00 117.92 6,009,124.68 532,061.44 9 8,500.00 85.39 39.92 6,601.07 928.58 2,801.85 1,600.53 15.00 -88.50 6,009,168.14 532,103.82 8,600.00 86.14 24.90 6,608.50 1,012.53 2,855.14 1,695.15 15.00 -87.74 6,009,252.29 532,156.77 8,700.00 87.14 9.90 6,614.39 1,107.52 2,884.90 1,794.56 15.00 -86.62 6,009,347.39 532,186.16 10 8,800.00 86.72 354.89 6,619.78 1,207.00 2,889.06 1,891.92 15.00 -92.00 6,009,446.87 532,189.93 8,900.00 86.52 339.86 6,625.70 1,304.13 2,867.31 1,980.51 15.00 -91.19 6,009,543.91 532,167.80 8,960.00 86.52 330.85 6,629.35 1,358.51 2,842.36 2,026.91 15.00 -90.30 6,009,598.18 532,142.64 1 11 9,000.00 85.50 336.77 6,632.14 1,394.30 2,824.75 2,057.15 15.00 100.00 6,009,633.90 532,124.90 9,055.00 84.17 344.95 6,637.10 1,446.00 2,806.81 2,102.71 15.00 99.59 6,009,685.52 532,106.75 12 9,100.00 80.84 339.03 6,642.97 1,488.41 2,793.03 2,140.32 15.00 - 120.00 6,009,727.87 532,092.80 9,135.00 78.31 334.35 6,649.31 1,520.01 2,779.42 2,167.51 15.00 - 119.23 6,009,759.42 532,079.07 13 9,200.00 87.87 332.42 6,657.13 1,577.63 2,750.54 2,216.06 15.00 -11.46 6,009,816.92 532,049.97 9,214.51 90.00 332.00 6,657.40 1,590.46 2,743.78 2,226.79 15.00 -11.23 6,009,829.72 532,043.16 14 9,300.00 88.45 344.73 6,658.56 1,669.76 2,712.33 2,295.68 15.00 97.00 6,009,908.88 532,011.40 9,345.00 ' 87.66 351.44 6,660.09 . 1,713.74 2,703.05 2,335.94 15.00 96.83 6,009,952.82 532,001.951 1 TD 1 1 6/1/2010 12:01:28PM Page 3 COMPASS 2003.16 Build 69 • • ConocoPhillips ConocoP illips Planning Report B Alaska HUGHES Database: - _- EDM Alaska Prod v16 Local Co- ordinate Reference: Well 3K 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 Weiibore: 3K 09BL1 - 01 Drign: 3k - 01 wp07 Targets T rget Nary - hit/miss target Dip Angle _ Dip Dir. TVD +NI-S +E/ -W Northing Easting - Shape (°) (a) (ft) (ft) (ft) (ftl lft} Latitude Longitude 3 -09BL2 t7 (copy) 0.00 0.00 6,660.00 1,721.74 2,742.83 6,009,960.98 532,041.70 70° 26' 17.740 N 149° 44' 19.456 W - plan misses target center by 40.60ft at 9344.61ft MD (6660.07 TVD, 1713.35 N, 2703.10 E) - Point 3K -09BL2 t1 (copy) 0.00 0.00 6,633.00 557.48 2,528.22 6,008,796.00 531,831.68 70° 26' 6.291 N 149° 44' 25.767 W - plan misses target center by 51.93ft at 8032.23ft MD (6633.59 TVD, 589.80 N, 2487.58 E) - Point 3K -09BL2 t6 (copy) 0.00 0.00 6,657.00 1,609.48 2,806.40 6,009,848.98 532,105.69 70° 26' 16.636 N 149° 44' 17.592 W - plan misses target center by 64.25ft at 9202.13ft MD (6657.20 TVD, 1579.52 N, 2749.55 E) - Point 3K -09BL2 t3 (copy) 0.00 0.00 6,593.00 802.66 2,741.21 6,009,041.99 532,043.68 70° 26' 8.702 N 149° 44' 19.514 W - plan misses target center by 44.66ft at 8360.45ft MD (6593.04 TVD, 828.78 N, 2704.98 E) - Point 3K -09B, BL1 fault 2 (c 0.00 0.00 0.00 1,030.83 2,450.08 6,009,269.00 531,751.69 70° 26' 10.947 N 149° 44' 28.055 W - plan misses target center by 6601.03ft at 8369.01ft MD (6593.00 TVD, 835.42 N, 2710.40 E) - Polygon Point 1 0.00 1,030.83 2,450.08 6,009,269.00 531,751.69 Point 2 0.00 1,482.82 2,723.86 6,009,722.01 532,023.66 Point 3 0.00 1,982.61 3,049.83 6,010,223.03 532,347.63 Point4 0.00 1,482.82 2,723.86 6,009,722.01 532,023.66 3K -09B, BL1 fault 3 (c 0.00 0.00 0.00 2,030.83 2,473.02 6,010,268.98 531,770.70 70° 26' 20.781 N 149° 44' 27.372 W - plan misses target center by 6671.17ft at 9055.00ft MD (6637.10 TVD, 1446.00 N, 2806.81 E) - Polygon Point 1 0.00 2,030.83 2,473.02 6,010,268.98 531,770.70 Point2 0.00 1,941.71 2,759.71 6,010,180.99 532,057.71 Point 3 0.00 1,879.96 2,951.49 6,010,120.00 532,249.71 Point 4 0.00 1,941.71 2,759.71 6,010,180.99 532,057.71 3K -09BL2 t4 (copy) 0.00 0.00 6,614.00 1,107.30 2,839.42 6,009,346.99 532,140.69 70° 26' 11.697 N 149° 44' 16.628 W - plan misses target center by 44.89ft at 8686.16ft MD (6613.68 TVD, 1093.95 N, 2882.27 E) - Point ' 3K -09B, BL1 Polygon 0.00 0.00 0.00 5.88 1,908.98 6,008,242.02 531,214.67 70° 26' 0.868 N 149° 44' 43.943 W - plan misses target center by 6675.90ft at 8168.11ft MD (6607.28 TVD, 683.44 N, 2581.58 E) - Polygon Point 1 0.00 5.88 1,908.98 6,008,242.02 531,214.67 Point2 0.00 171.93 1,901.62 6,008,408.03 531,206.66 Point 3 0.00 505.99 2,152.94 6,008,743.04 531,456.64 Point 4 0.00 813.72 2,489.17 6,009,052.06 531,791.63 Point 5 0.00 1,133.06 2,667.43 6,009,372.06 531,968.61 Point6 0.00 1,304.30 2,611.09 6,009,543.06 531,911.61 Point 7 0.00 1,610.96 2,449.26 6,009,849.05 531,748.59 Point 8 0.00 2,059.81 2,500.01 6,010,298.06 531,797.57 Point 9 0.00 2,576.26 2,914.05 6,010,816.08 532,209.54 Point 10 0.00 2,285.25 3,166.95 6,010,526.09 532,463.55 Point 11 0.00 2,029.09 2,940.93 6,010,269.07 532,238.56 Point 12 0.00 1,812.56 2,816.08 6,010,052.07 532,114.58 Point 13 0.00 1,641.50 2,826.42 6,009,881.07 532,125.59 Point 14 0.00 1,402.90 2,974.51 6,009,643.08 532,274.60 Point 15 0.00 998.68 3,018.95 6,009,239.08 532,320.62 Point 16 0.00 568.47 2,803.26 6,008,808.07 532,106.65 Point 17 0.00 312.64 2,496.23 6,008,551.06 531,800.65 Point 18 0.00 -33.25 2,198.86 6,008,204.04 531,504.68 Point 19 0.00 5.88 1,908.98 6,008,242.02 531,214.67 3K -09BL2 t5 (copy) 0.00 0.00 6,636.00 1,445.31 2,845.75 6,009,684.98 532,145.69 70° 26' 15.021 N 149° 44' 16.439 W - plan misses target center by 37.29ft at 9041.52ft MD (6635.76 TVD, 1433.11 N, 2810.52 E) - Point 6/1/2010 12 :01:28PM Page 4 COMPASS 2003.16 Build 69 .i \ 1 ,. ?1i \ . • ConocoPhillips rug ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 3K - 09 - 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 Wellbore: 3K - 09BL1 - 01 Design: _ 3k- 09BL1- 01_wp07 3K -09BL2 t2 (copy) 0.00 0.00 6,607.00 632.08 2,632.52 6,008,871.00 531,935.68 70° 26' 7.024 N 149° 44' 22.705 W - plan misses target center by 71.84ft at 8174.61ft MD (6606.67 TVD, 687.40 N, 2586.70 E) - Point Casing Points F - - _ _ Measured_ Vertical - '`Casing =_ Hole Depth Depth = Diameter = Diameter tf _ (ft) Name - - ( ") (1 - 3,172.00 3,100.46 10 3/4" 10 -3/4 13-1/2_ 9,345.00 6,660.09 2 3/8" 2 -3/8 Plan Annotations Measured Vertical Local Coordinates Depth = Depth +N/-S +E/ -VII (ft) °` (ft) (ft) (ft) Comment 7,830.39 6,656.43 443.78 2,352.72 TIP 7,850.00 6,656.90 456.40 2,367.72 KOP 7,920.00 6,653.38 503.03 2,419.67 3 8,010.00 6,638.27 571.82 2,475.38 4 8,088.11 6,620.76 631.39 2,522.54 5 8,168.11 6,607.28 683.44 2,581.58 6 8,308.11 6,595.29 786.10 2,674.86 7 8,369.01 6,593.00 835.42 2,710.40 8 8,439.01 6,596.00 885.28 2,759.29 9 8,700.00 6,614.39 1,107.52 2,884.90 10 8,960.00 6,629.35 1,358.51 2,842.36 11 9,055.00 6,637.10 1,446.00 2,806.81 12 9,135.00 6,649.31 1,520.01 2,779.42 13 9,214.51 6,657.40 1,590.46 2,743.78 14 9,345.00 6,660.09 1,713.74 2,703.05 TD 6/1/2010 12 :01.28PM Page 5 COMPASS 2003.16 Build 69 ORIGINPAL • • TRANSMITTAL LETTER CHECKLIST I WELL NAME C'( � ` 7 L ! ✓ 1 PTD# % /(� '; ( 43 C Development Service Exploratory Stratigraphic Test Non- Conventional Well e � FIELD: k_lt v{� --r�_`J ,let t rr —► POOL: /��1-; V 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 f well Ke-1( (�/ (If last two digits in Permit No. CGZe:-; API No. 50- Cwt - Z%('- 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(0, 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 • 0 10 El N 0 ° N N N D Q , 1 a I ' 'C' . U ' C O = 1 I >I I 1 sit o c 1 -c 3 a) O a) � ' a `� i' m m .� a m � E O 1) O co, w' s' E o' o i U ' �' E co m a O 3' a) - 0 O' N' ' Z N ' �� � IL'. 11 N' Q' O a) 0 1 = E' 2' �' ' ' 9 ,= c ' ' O , c `O � -0 O), w - 0,, °, 1 c a) — O O a) I J; D ' 4' CI, . to d , � Q) —> O' a 0) CO 1 CO c ' > 0) � u c ) C to • N. °. O O 3 N ` "O CO E Q Cl ' c 6 T c �, c 0 rn ° O LL, � - E N, 1 �' > m m Q v� m N L0 c co D , 3° Z 3 9, c' O L, CO O CO' N N O - 4 M ''' O' c) n E c a) ' m, _ Y o, �, N, ,_- ' '0, c Q 9 O, Z 0_ � O, CO' a c O 0. t — CO, II _ _c �, G c, a), O a � o I Y' c E w ' a ' )1 a m ti ' 2' 0) v > - 0, >, DI E U c O _ � I C) N a) co co ! _c cn c. N 'a-i 1 O' _� 7 , .7 ` ' Y 0 O, O ' . (7) c ' o o, c ° 0_ •y ' 1 m' a , E o O �, m c m o o C) a 1 E +-, a 1 E a) °� @, (' � a C ( o a o_ ' c '� m 00 o o, O `o .0 Z' c ' o, a) �, M, u c Y Y, c 4) 0 ' p °. c - 0 CO '0, ' `c CO > N , N O ' E y' O< a., °, 1, M, M � 1 Y , CO c' c X' a' x (I> C , , ° c I z ' 0. " O' 0' oo E ' I O' 7 D 0 = rn O ' O' O Q� N' ce' CL N O , w ' co Y' U C)' co o n. O m c) a co M .2 2 Y' Y' °' w pl I 0 0 0 N 0, CO 0 CO 0) CO CO CO (0 (0 (1) (1) (0 CO CO VT (0 ( 0 N O Q a a)' a)' a), a), o o o a), a), Q' Q' Q, Q, ' < Q' Q' Q o a), a Q, a) a), a), a)' a), a)' Q 0, a) Q, Q' Q, \. a Z }, >- } )' m, o a)' >- >- }, > - > - > >- > - Z . Z Z, Z, ' Z Z, Z Z Z > - } , } >- )' a), Z, }, }, }, }, }, }, Z, 1 z, >- Z, Z, Z, T (� a? Vr N. t @ V �' — c E' 3 E a) o' o 5 a)' I . . cif O o o a)' C) M E a)' a) . E 3 p ° 3 M' y' 1 >. 41 O. 0 c Z p o. � , o' m' ' ' �' o cry �' Q ' m 2 0 0 o a 0. a) o' c ' in m. c �' 3' f c:r -a' w c 0' °' O 1 t' c E' �' o _ a> CO C a) E N m O ? ""' p, O N a) O` OM ' , V' 0 N , 0 C ' p ' N O . a. " c 0 N ' • v - ' �' rn 2 z CD h. O ' 3' 3' m' o u ) c rn �, U ' 3 6 0 ,n' 3 ' Q , I o o m' of 'I z1 °' ° E' �' ° o c o, m a) ° _ �' ° a) m ° ° °) a) in a CO, c c c ° a `) '- G E @ c O M ' c U ' C N' (D.' �' t a) O: N' t d 0 c Q o' o a �' -0 o', 0, m c0 c Q 1 1 0 0 rn 7 0, Q _0 4 a) 2 acs 0,, a ° B 3' ' o ' �' � ' Y a) , n V) Qj O c' ` O N O O ° 1 1 a) c O O O O a) • C , •-r,5 f6 Q. (a_ 2 0. . 'O O 0) p' a) a) Q o 0 N > o 7 7 ' 0 0 , f0 ' c o, o' E E ' N o' >' v O' . . E' o o a) . a o' o ' a) c — a Z o' 3 3 m' m' 3 0) Q m ' c - o 13 co o . a a) s L -a' co m -o E 0 m' E' c, a) v o ); r) @' o r ° �' o a 0 0 o' T 3 u c J o u) a) Iii w ; --- . ' m f6 ' a) - o o ' ' 3' .= 3 is O °. °' N ° W' 0 3 ' 1) 0 ' °) ° U c 0 n- . p C = a, 'O' > , N .a -0, "O' O. cc`a • c c � a) O O c 0- u, ' c 6' N. N 0: O' co' c '' ' O , a co T a ) I EL J -° 0. m o a) 41) E m ` o ' C) E o E w o m c J _ 0 0_ U N' 0 Q' � ' O i c 0 a c' V U ', 0 ' ! O: O ' N a) — -0 a) a) 'p Ca E' O O' . " p' c' p' O' 0 ' 1 OS o =' • C L) ' m E ' a) o o 3 @' ° N , N m -_E! c' a c a . co ' @ CO ° 0 a .- o a m a' 3 2. .' l N, v T o . _a ccan 00 m' C' CO, �, o °. m ° >, v) , a a' 3 . °' °) C a aa >' O c s, a) v ° t rn; c o o' 1 .0 5' o v °' U . - O -0 '0 U c ( 'O _ a)' N .N . a)' U c' � ' m a m (1)) o' c, @ D D 0 •u, _ 3 0 o N c o o m c a)' c' p as. Z N' c 3' U' U U c U)) O O O m U N a' 0 U , m (a' U' Q) w — y 0 "O 0)) O = c Cn (6 •- O O O U U a) u) p c U 0, O O, ca. ' ca , 01 o � 0_ E , '3 0,, @, U a U , o ). c O U ' E N Cr ° °, o • • 'a) m m .E' c o. —c a) . o' o' 0, I H c o• �'' a >' c a a; Y' a) U' m 0 m c ui c if) C C?) c a)' u a) '' �, a' O O 4 0 . if) a`) ca' a) 3 El_ o, ' o; a� 2 2 2 m, -a� 0 - ` d = 0, O t; ° Q ° a m , ' a), a), o' a > a. _1 D �', u) w , a. d U Q. d, Z, 10, u) 0 0 0 U, Q Q, w 6 m m 0.. �' `� ' a, 0 u) u), 0, I - ca E O,- N C) V O(0 N- CO O 0 3 N CO R 1f) CO r CO O 0 N CO d' ' C0 CO C's CO 0' ` _ .- N CO tt in co N. co O s- 1- a- a- s- a- a- .- e- N CV CV (V N N N N N N C') CO CO CO CO M M CO CO M U 0 I 0 0 co F (0 0 ' c " O U p e _ . O c co N I; N la N O ._ CO O 0 v 0) 0 a ) 0 v p y .. L 0 C CO c CO 1' O ° E w a) '. N N • o 0) 1 o a 0 C Q U ° Q p 0 I- v o C 0) a CJ`s 0 a a c. W 3� ; a a i '
