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210-044
• • 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. ®Z1 0 - 0 14-q- -- Well History File Identifier Organizing (done) ❑ Two -sided 111111 11111 III ❑ Rescan Needed 1 11111 1 RES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: s eyscale 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: 111100 Date: (e/A7//g... is/ t Project Proofing 1111 11111111 11 1 BY: Maria Date: 6/a4/ lsl Scanning Preparation l x 30 = 3 0 + 5- = TOTAL PAGES .'D- BY: Maria Date: 1 n (Count does not include cover sheet) /0-7/ a� /s/ 01 Production Scanning 1 11111111111 11111 Stage 1 Page Count from Scanned File: 33 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: 1 NO BY: 'P Date: a / I ` D_. /s/ I Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ IIIII Scanning is complete at this point unless rescanning is required. I 1 ReScanned 111111E11 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked III ItIIII11I111I Ili 12/22/2011 Wet History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 6/18/2012 Permit to Drill 2100440 Well Name /No. KUPARUK RIV UNIT 3K -09BL2 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 029 - 21656 -61 -00 MD 8879 TVD 6775 Completion Date 6/12/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Su ey 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 Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments F" C Lis 19907 Induction /Resistivity 6689 8879 Open 7/27/2010 GR, ROP, RES Lo- Induction /Resistivity 2 Col 7150 8879 Open 7/27/2010 MD MPR, GR Log (i Induction /Resistivity 5 Col 7150 8879 Open 7/27/2010 MD MPR, GR Log — Induction /Resistivity 5 Col 7150 8879 Open 7/27/2010 TVD MPR, GR 1 C Directional Survey 7150 8879 Open (NI Directional Survey 7150 8879 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION III Well Cored? Y N ; Daily History Received? eb Chips Received? ..,11111.— a Formation Tops N Analysis _y_1.14- Received? Comments: Compliance Reviewed By: \''"z\--75 Date: 'P ‘' )--- I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil El Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Q 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 - 0440 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 June 2, 2010 50 029 - 21656 - 61 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 5, 2010 3K - 09BL2 Top of Productive Horizon: 8. KB (ft above MSL): 69' RKB 15. Field /Pool(s): 927' FSL, 2108' FWL, Sec. 35, T13N, R9E, UM GL (ft above MSL): 30' Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 43' FSL, 1449' FWL, Sec. 35, T13N, R9E, UM 8879' MD / 6775' 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 8879' MD / 6775' TVD ADL 25519, 25629 TPI: x - 531099 y- 6007928 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 530444 y- 6007041 Zone 4 2183' MD / 2183' TVD 2555, 2562 18. Directional Survey: Yes El 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 7151' MD / 6613' 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 7749' 8879' 6769' 6775' 3" solid /slotted liner 24. Open to production or injection? Yes Q 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: 7756' -8868' MD 6771' -6775' TVD r" COMPLETION 26 . ACID, FRACTURE, CEMENT SQUEEZE, ETC. • 1 . DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED f -- - ; 033' 17 ppg cement 4.4 014 ti' 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 El Sidewall Cores Acquired? Yes ❑ No IN 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 [� RECEI ED NONE *Ail. 1 a, 2010 RBDMS JUL 0 3 2010.1 icli Oil & Gas Cons. Commission Anchorage Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit riginal only Z /v G 28. GEOLOGIC MARKERS (List all formations and ma rs encountered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes II 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 7165' 6625' Top A 7281' 6700' 1 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 G C /.& 7/2/o Printed Na Ca Title: Alaska Wells Manager � Signature ✓�. � Phone 265 - 6306 Date 7/12/ 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). I 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 -09BL2 �((���� (� Well Attributes Max Angle 8 MD TD ` xJ Ina. Wellbore APUUWI Field Name Well Status Inc! ( ") MD (ftKB) Act Btm (ftKB) 500292165661 KUP_ARUK RIVER UNIT PROD Comment H 2S (ppm) (Date Annotation End Date KB ((t) Rig Release Date SSSV: TRDP 120 2/2312009 Last WO: 6/17/2010 39.90 10/17/1986 Well Config 3K -098L26/18/2G11 55 AM _ — - - - Schema[c Actual Annotation Depth(11KB) End Date Annotation Last Mod ..,End Date 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 (1... Set Depth (TVD) .. String Wt... String ... String Top Thrd BL2 LINER 2 3/8 I 1.995 7,747.1 8,879 0 4.60 L-80 STL Liner Details Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) (5 Item Description Comment ID (in) 7,747.1 DEPLOY Aluminum Billet 1.000 !BILLET Perforations & Slots Shot T op (TVD) Btm (TVD) Dena Top (ftKB) Ben (ftKB) (ftKB) (ftKB) Zone Dote (sh_. A, Comment 7,756 8,868 6/5/2010 SLOT Alternating solid /slotted pipe - 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends HANGER, 35 - _ Notes: General & Safety ; End Dab A otation 6/17/2010 NOTE: VIEW SCHEMATIC w /Alaska Schemanc9 0 h111 "dP CONDUCTOR, 38 -110 SURFACE, 37 -3,172 TD (36- 0991.2), 3,172 PRODUCTION, 35 -7,559 I \( , ) 1 Ft 1 SLOT, 7,756 -8,868 " Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top)ftKB) MKS) ("1 Mace Model (in) Sery TYP• TYPe (in) (Pei) Run Data Cont... 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 1,320M 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 1 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 OA 4/13/2010 BL2 LINER, 7,747 - 8,879 - ConocoPhillips Alaska s ConocoPhilli Alaska • p� ) Inc. Kuparuk River Unit Kuparuk 3K Pad 3K -09BL2 50- 029 - 21656 -61 Baker Hughes INTEQ FA. • Definitive Survey Report BAKER Y p HUGHES 22 June, 2010 Noe" ConocoPhillips Er ConocoPhilli S BAKER Definitive Survey Report HUGHES Alaska 1 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) I Well: 3K - 09 North Reference: TRUE Wellbore: 3K - 09 Survey Calculation Method: Minimum Curvature i Design: 3K -09 Database: EDM Alaska Prod v16 I 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 III 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: 529,305.92ft Longitude: 149° 45' 39.960 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 3K - 09BL2 o Name Sample Date Declination Dip Angle Field Strength Magnetics Model p p g 9 ( °) (') (nT) BGGM2009 7/15/2010 17.14 79.87 57,394 Design 3K -09BL2 Audit Notes: Version: 1.0 Phase: ACTUAL Depth From (TVD) Tie +N /S On Depth: 7,150.00 Vertical Section: +E! W Direction (ft) (ft) (ft) ( °) 69.00 0.00 0.00 136.43 • 1 Survey Program Date From To Survey SLIMY (ft) (ft) Survey (Wellbore) Tool Name Description Start Date End Date 100.00 7,150.00 3K -09A GyroData (3K -09A) GYD -CT -CMS Gyrodata cont.casing m/s 3/9/2009 l 7,180.09 8,840.26 3K -09BL2 (3K- 09BL2) MWD MWD - Standard 6/3/2010 6/4/2010 6/22/2010 8:18:30AM Page 2 COMPASS 2003.16 Build 69 r ConocoPhillips WAS Conoco Phillips Definitive Survey Report HUGHES K 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 WeUbore: 3K - 09 Survey Calculation Method: Minimum Curvature Design: 3K - 09 Database: EDM Alaska Prod v16 Survey MD Inc Azl TVD TVDSS +N /-S +E/-W Northing E ng DLS Section Survey Tool Name Annotation (to C) el (ft) (ft) (ft) (ft) O (ft) mool (ft) 7,150.00 31.41 90.44 6,613.46 6,544.46 33.12 1,914.57 6,008,269.28 531,220.16 0.22 1,295.55 MWD (2) TIP / KOP 3K - 7,180.09 42.08 89.23 6,637.54 6,568.54 33.19 1,932.55 6,008,269.43 531,238.13 35.53 1,307.88 MWD (2) Interpolated AZI 7,210.00 50.91 88.42 6,658.11 6,589.11 33.65 1,954.21 6,008,269.97 531,259.79 29.59 1,322.49 MWD (2) 7,240.23 53.56 109.29 6,676.75 6,607.75 29.93 1,977.58 6,008,266.34 531,283.18 55.15 1,341.29 MWD (2) 7,270.15 52.04 128.48 6,694.95 6,625.95 18.54 1,998.30 6,008,255.04 531,303.93 51.25 1,363.81 MWD (2) 7,300.39 49.67 143.82 6,714.11 6,645.11 1.76 2,014.50 6,008,238.32 531,320.20 40.06 1,387.14 MWD (2) 7,330.41 56.00 159.00 6,732.30 6,663.30 -19.19 2,025.76 6,008,217.42 531,331.54 45.39 1,410.08 MWD (2) 7,360.48 63.02 173.19 6,747.60 6,678.60 -44.26 2,031.85 6,008,192.38 531,337.73 46.82 1,432.44 MWD (2) 7,390.59 72.50 183.46 6,759.01 6,690.01 -72.04 2,032.58 6,008,164.60 531,338.57 44.54 1,453.07 MWD (2) 7,420.44 85.02 189.09 6,764.83 6,695.83 - 101.07 2,029.36 6,008,135.56 531,335.46 45.82 1,471.88 MWD (2) 7,450.52 90.71 199.89 6,765.95 6,696.95 - 130.11 2,021.84 6,008,106.49 531,328.06 40.55 1,487.75 MWD (2) 7,480.63 92.09 209.36 6,765.21 6,696.21 - 157.45 2,009.32 6,008,079.11 531,315.64 31.77 1,498.92 MWD (2) I 7,510.01 89.11 222.11 6,764.90 6,695.90 - 181.24 1,992.19 6,008,055.25 531,298.61 44.56 1,504.36 MWD (2) 7,540.41 91.04 226.85 6,764.86 6,695.86 - 202.92 1,970.90 6,008,033.49 531,277.41 16.83 1,505.40 MWD (2) i 7,570.31 92.24 231.10 6,764.01 6,695.01 - 222.54 1,948.36 6,008,013.79 531,254.95 14.76 1,504.07 MWD (2) 7,600.53 91.78 236.00 6,762.95 6,693.95 - 240.48 1,924.07 6,007,995.76 531,230.73 16.28 1,500.33 MWD (2) 7,630.56 90.25 240.60 6,762.41 6,693.41 - 256.25 1,898.54 6,007,979.89 531,205.26 16.14 1,494.16 MWD (2) • 7,660.72 88.80 244.88 6,762.66 6,693.66 - 270.06 1,871.73 6,007,965.97 531,178.51 14.98 1,485.69 MWD (2) 7,680.62 87.11 247.39 6,763.37 6,694.37 - 278.10 1,853.55 6,007,957.86 531,160.36 15.20 1,478.99 MWD (2) 7,710.56 84.06 244.82 6,765.68 6,696.68 - 290.19 1,826.26 6,007,945.66 531,133.13 13.30 1,468.94 MWD (2) 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 1,460.50 MWD (2) 7,770.37 81.62 238.67 6,772.81 6,703.81 - 318.55 1,774.12 6,007,917.11 531,081.11 10.34 1,453.55 MWD (2) 7,800.19 83.48 235.11 6,776.67 6,707.67 - 334.70 1,749.36 6,007,900.86 531,056.41 13.38 1,448.19 MWD (2) 7,830.50 84.47 230.79 6,779.86 6,710.86 - 352.86 1,725.31 6,007,882.61 531,032.43 14.55 1,444.77 MWD (2) 7,860.47 84.47 225.45 6,782.75 6,713.75 - 372.76 1,703.11 6,007,862.62 531,010.31 17.73 1,443.89 MWD (2) 7,890.52 84.71 220.22 6,785.58 6,716.58 - 394.69 1,682.78 6,007,840.61 530,990.07 17.35 1,445.77 MWD (2) 7,920.61 87.14 215.85 6,787.72 6,718.72 - 418.33 1,664.29 6,007,816.91 530,971.68 16.58 1,450.15 MWD (2) 7,950.26 87.73 210.46 6,789.05 6,720.05 - 443.11 1,648.10 6,007,792.06 530,955.58 18.27 1,456.95 MWD (2) 7,980.65 86.96 206.04 6,790.46 6,721.46 - 469.85 1,633.73 6,007,765.27 530,941.32 14.75 1,466.42 MWD (2) 8,010.41 87.60 204.46 6,791.87 6,722.87 - 496.73 1,621.05 6,007,738.34 530,928.75 5.72 1,477.16 MWD (2) 6/22/2010 8:18:30AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips Rif ConocoPhillips Definitive Survey Report WISHES 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 Wel!bore: 3K - 09 Survey Calculation Method: Minimum Curvature Design: 3K -09 Database: EDM Alaska Prod v16 - Survey ,--._ Map Map cal MD Inc Azi TVD TVDSS + +E/ -W DLS Vertical Easting Section Survey Tool Name Annotation (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) MOO') (ft) ill 8,040.64 89.69 209.22 6,792.58 6,723.59 - 523.69 1,607.41 6,007,711.33 530,915.22 17.19 1,487.29 MWD (2) 8,070.30 88.96 212.96 6,792.93 6,723.93 - 549.08 1,592.10 6,007,685.88 530,900.01 12.85 1,495.14 MWD (2) 8,100.48 88.28 216.76 6,793.66 6,724.66 - 573.84 1,574.86 6,007,661.06 530,882.87 12.79 1,501.19 MWD (2) 8,130.45 91.23 220.90 6,793.79 6,724.79 - 597.18 1,556.07 6,007,637.65 530,864.17 16.96 1,505.15 MWD (2) 8,160.29 92.27 226.02 6,792.88 6,723.88 - 618.82 1,535.56 6,007,615.93 530,843.75 17.50 1,506.70 MWD (2) 8,190.57 91.93 231.61 6,791.77 6,722.77 - 638.74 1,512.80 6,007,595.93 530,821.07 18.48 1,505.44 MWD (2) 8,220.56 90.15 230.17 6,791.22 6,722.22 - 657.65 1,489.54 6,007,576.92 530,797.88 7.63 1,503.11 MWD (2) 8,250.32 91.23 226.12 6,790.86 6,721.86 - 677.50 1,467.38 6,007,556.99 530,775.80 14.08 1,502.22 MWD (2) 8,280.42 93.72 221.84 6,789.56 6,720.56 - 699.13 1,446.50 6,007,535.27 530,755.01 16.44 1,503.51 MWD (2) 8,310.49 93.87 217.01 6,787.57 6,718.57 - 722.30 1,427.45 6,007,512.03 530,736.06 16.04 1,507.17 MWD (2) 8,340.29 95.25 212.41 6,785.20 6,716.20 - 746.71 1,410.54 6,007,487.56 530,719.24 16.07 1,513.20 MWD (2) 8,370.37 94.82 207.34 6,782.56 6,713.56 - 772.69 1,395.62 6,007,461.53 530,704.43 16.85 1,521.73 MWD (2) 8,400.26 94.21 203.01 6,780.21 6,711.21 - 799.65 1,382.95 6,007,434.52 530,691.86 14.58 1,532.54 MWD (2) 8,431.72 92.33 199.93 6,778.41 6,709.41 - 828.87 1,371.45 6,007,405.25 530,680.48 11.46 1,545.79 MWD (2) 8,460.20 88.50 198.51 6,778.21 6,709.21 - 855.76 1,362.08 6,007,378.33 530,671.22 14.34 1,558.81 MWD (2) 8,490.71 86.04 195.12 6,779.66 6,710.66 - 884.92 1,353.27 6,007,349.14 530,662.52 13.72 1,573.87 MWD (2) 8,520.51 86.34 193.65 6,781.64 6,712.64 -913.73 1,345.88 6,007,320.31 530,655.25 5.02 1,589.64 MWD (2) 8,550.52 87.67 197.81 6,783.21 6,714.21 - 942.56 1,337.76 6,007,291.44 530,647.24 14.53 1,604.94 MWD (2) • 8,580.36 88.96 201.49 6,784.09 6,715.09 - 970.65 1,327.73 6,007,263.32 530,637.32 13.06 1,618.38 MWD (2) 8,610.46 88.96 205.95 6,784.63 6,715.63 - 998.20 1,315.62 6,007,235.73 530,625.33 14.81 1,630.00 MWD (2) 8,640.40 89.05 211.40 6,785.15 6,716.15 - 1,024.45 1,301.27 6,007,209.42 530,611.07 18.20 1,639.12 MWD (2) 8,670.24 90.43 215.95 6,785.29 6,716.29 - 1,049.27 1,284.73 6,007,184.53 530,594.63 15.93 1,645.71 MWD (2) 8,700.70 90.18 220.37 6,785.13 6,716.13 - 1,073.22 1,265.91 6,007,160.52 530,575.91 14.53 1,650.09 MWD (2) 8,730.50 91.66 225.66 6,784.65 6,715.65 -1,095.00 1,245.59 6,007,138.66 530,555.68 18.43 1,651.87 MWD (2) 8,760.38 93.16 230.05 6,783.39 6,714.39 1,115.02 1,223.46 6,007,118.55 530,533.63 15.51 1,651.13 MWD (2) 8,791.02 94.02 234.16 6,781.47 6,712.47 -1,133.80 1,199.34 6,007,099.68 530,509.58 13.68 1,648.10 MWD (2) 8,820.42 94.18 229.15 6,779.37 6,710.37 - 1,151.99 1,176.35 6,007,081.40 530,486.67 17.01 1,645.44 MWD (2) 8,840.26 94.85 226.63 6,777.81 6,708.81 - 1,165.25 1,161.67 6,007,068.09 530,472.05 13.10 1,644.93 MWD (2) 8,879.00 94.85 226.63 6,774.53 6,705.53 -1,191.76 1,133.61 6,007,041.47 530,444.09 0.00 1,644.80 PROJECTED to TD 6/22/2010 8:18:30AM 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 -112" Cameo MMG gas lift mandrels @ 2396' 3533' 16" 62# H -40 shoe 4607' @ 110' MD 5586' 6307' 6839' 10 -314" 45.5# K -55 shoe @ 3172' MD , +; • 1 3 -1/2" X Nipple @ 6888' MD (2.813" profile) l 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 -... I � ... -- 4- ---- 7033' - 7035' WLEG @ 7049' MD Tubing Tail @ 7050' MD 1. i \ 2 -5/8" Openhole anchor/whipstock @ 7150' Top of liner 7193' :::\\\ \\\\ \ `,. south Laterals Top of Billet - 7749' 3K- 09BL2 -01: 8955' • 2 -5/8" Openhole anchor /whipstock @ 7201' j 7250' - Bottom of Pilot Hole - -- North Laterals A3 - sand pads 7279' 3K - 096L2: 8879' - 7297' MD ITop of Bi llet - 7863' A2 - sand perfs 7310' 3K - 096L 1: 10,034' 7333' � ` \ ` Top of Billet - 8059' 7339' _ • t � ` 3K -09B: TD - 9610' 7348' - 7352' - t\ 1 l BOL - 9510' 7359' - 73 63' _ _ 7" 26# J -55 shoe @ I 3K 09BL1 - 01: 8897' 7559' MD —.MO - 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 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, 21 K 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 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:06 09:24 0.30 0 0 PROD4 WHPST SFTY P PJSM 09:24 10:36 1.20 0 0 PROD4 WHPST PULD P lay down BHA #14, PU BHA # 15. Service injector and check P'offs 10:36 12:24 1.80 0 6,700 PROD4 WHPST TRIP P RIH 12:24 12:42 0.30 6,700 6,760 PROD4 WHPST DLOG P Tie in, +28' 12:42 14:12 1.50 6,760 7,151 PROD4 WHPST DISP P Dry tag WS at 7151', Circulate out KWF 14:12 18:12 4.00 7,151 7,154 PROD4 WHPST MILL P 11K RIW, 24K PUW, 1.35 BPM, 3900 CTP, 4300 BHP, 215 WHP. Start window milling from 7150.5 18:12 20:42 2.50 7,154 7,155 PROD4 WHPST MILL P 350 psi pressure increase. No stall, continue milling. 20:42 21:12 0.50 7,155 7,147 PROD4 WHPST TRIP P WOB and surface weight stacking without motor work, PUH, 21 K PUW, Reset WOB sensor of bottom, RIH 2FPM. Depths =bit to bend wear plate at top of WS 21:12 22:27 1.25 7,154 7,156 PROD4 WHPST MILL P Set auto driller to .5 FPH, off bottom 3950 CTP, 4325 BHP, 215 WHP 22:27 22:57 0.50 7,156 7,156 PROD4 WHPST MILL P Pop by wear band, 170psi motor work increase. Cont. milling .5 FPH 4070 CTP, 7K CTP, 4325 WHP, 1.3 BPM, 22:57 00:00 1.05 7,156 7,157 PROD4 WHPST MILL P WOB drop to .5K. 4000 CTP, Continue milling .8 FPH 06/03/2010 Complete window #2, TOWS 7151', BOW 7156'. POOH PU 2.3 AKO with hughes bit. Drill build section, landing at 7510', POOH 00:00 00:15 0.25 7,157 7,162 PROD4 WHPST MILL P Increase ROP to 2 FPM 00:15 02:00 1.75 7,162 7,166 PROD4 WHPST MILL P Increase ROP 4 FPH, 1 -1.5K WOB drilling rat hole 02:00 03:06 1.10 7,166 7,150 PROD4 WHPST TRIP P PUH 1 FPM through window. 7150'. 03:06 03:21 0.25 7,150 7,166 PROD4 WHPST TRIP P RIH drifting window pumps on 03:21 03:36 0.25 7,166 7,150 PROD4 WHPST TRIP P POOH drifting window pumps on. 03:36 04:06 0.50 7,150 7,166 PROD4 WHPST TRIP P RIH drifting window, no pumps X2, Looks good. 04:06 06:00 1.90 7,166 0 PROD4 WHPST TRIP P POOH following MP schedule 06:00 06:30 0.50 0 0 PROD4 WHPST TRIP P Crew change out, walk arounds and start of tour checklists. PJSM 06:30 07:48 1.30 0 0 PROD4 WHPST PULD P Un- deploy milling BHA. 2.80 go / 2.79 no -go on mill and string reamer 07:48 08:18 0.50 0 0 PROD4 DRILL PULD P Adjusting motor to 2.3+ 08:18 09:48 1.50 0 0 PROD4 DRILL PULD P Deploy BHA # 16 for build 09:48 11:12 1.40 0 6,698 PROD4 DRILL TRIP P RIH with open EDC following MPD tripping schedule 11:12 11:24 0.20 6,698 6,740 PROD4 DRILL DLOG P Tie in , + 26' correction. Page 19 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:24 11:36 0.20 6,740 7,166 PROD4 DRILL TRIP P Continue RIH. 11K RIW Close EDC above window and drift through window HS, clean. 11:36 14:48 3.20 7,166 7,288 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 4100 CTP, 4300 BHP, 150 WHP, 1 - 2K WOB, 150 -300 PSI motor work. Saw RA at 7156 while drilling 14:48 15:00 0.20 7,288 7,288 PROD4 DRILL WPRT P Wiper to window, 21K PUW, started getting gas and crude cut retums, divert to TT 15:00 21:00 6.00 7,288 7,440 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 4100 CTP, 4300 BHP, 250 WHP, 1 - 2K WOB, 150 -300 PSI motor work. Swap Mud. 21:00 21:15 0.25 7,440 7,440 PROD4 DRILL WPRT P Wiper trip to window, 21 K PUW. Some more gas and crude cut mud, sent 38 Bbls to TT, start holding 50 - 75 psi extra on BHP 21:15 22:30 1.25 7,440 7,510 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 4100 CTP, 4450 BHP, 250 WHP, 1 - 2K WOB, 150 -300 PSI motor work. 22:30 00:00 1.50 7,510 0 PROD4 DRILL TRIP P Land build section. POOH 06/04/2010 Undeploy BHA 16, Deploy BHA 17, RIH, Drill BL2 Lateral, 7510'- 8260'. 00:00 01:00 1.00 0 0 PROD4 DRILL TRIP P At surface 01:00 01:15 0.25 0 0 PROD4 DRILL SFTY P PJSM 01:15 02:45 1.50 0 0 PROD4 DRILL PULD P Undeploy BHA 16 02:45 04:30 1.75 0 0 PROD4 DRILL PULD P Deploy BHA 17 04:30 06:12 1.70 0 6,800 PROD4 DRILL TRIP P RIH 06:12 07:12 1.00 6,800 7,200 PROD4 DRILL DLOG P Tie -in, tried to find the K1 marker without success. PUH to 6690. +26' correction. RIH, close EDC and log RA at 7155' 07:12 07:30 0.30 7,200 7,510 PROD4 DRILL TRIP P Continue RIH 07:30 09:30 2.00 7,510 7,660 PROD4 DRILL DRLG P Drill ahead, 4100 CTP, 4430 BHP, 300 WHP, 11K RIW. Starting to get some crude cut mud to the shaker, divert to TT, sent 40 Bbls. to TT. 09:30 10:42 1.20 7,660 7,200 PROD4 DRILL DLOG P MAD pass from 7550 to 7160', 22K PUW 10:42 11:00 0.30 7,200 7,660 PROD4 DRILL WPRT P RBIH, 12K RIW 11:00 12:48 1.80 7,660 7,810 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 4100 CTP, 4490 BHP, 310 WHP, 1 - 2K WOB, 200 -300 Motor work 12:48 13:30 0.70 7,810 7,810 PROD4 DRILL WPRT P Wiper trip to window, 22K PUW, 12K RIW. Clean trip. 13:30 16:12 2.70 7,810 7,960 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 4100 CTP, 4520 BHP, 350 WHP, 1 - 3K WOB, 200 -300 Motor work 16:12 16:42 0.50 7,960 7,175 PROD4 DRILL WPRT P Wiper to window, 22K PUW 16:42 16:54 0.20 7,175 7,195 PROD4 DRILL DLOG P Tie in, -0.5' Page 20 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:54 17:18 0.40 7,195 7,960 PROD4 DRILL WPRT P Wiper back in hole, 13K RIW 17:18 19:18 2.00 7,960 8,110 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 3950 CTP, 4590 BHP, 200 WHP, 1 - 3K WOB, 200 -300 Motor work 19:18 20:48 1.50 8,110 8,110 PROD4 DRILL WPRT P Wiper trip back to window 20:48 22:48 2.00 8,110 8,260 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 3950 CTP, 4595 BHP, 200 WHP, 1 - 3K WOB, 200 -300 Motor work 22:48 00:00 1.20 8,260 8,260 PROD4 DRILL WPRT P Wiper trip back to window, 23K PUW 06/05/2010 Drill BL2 Lateral 8260'- 8880'. Lay in liner running pill, POOH displacing well to KWF. PU /MU Liner. 00:00 02:15 2.25 8,260 8,410 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 4150 CTP on bottom, 3950 of bottom 4590 BHP, 200 WHP, 1 - 3K WOB, 200 -300 Motor work 02:15 03:03 0.80 7,180 7,180 PROD4 DRILL WPRT P Wiper trip to window, 23K PUW 03:03 03:18 0.25 7,180 7,180 PROD4 DRILL DLOG P Correct -3' correction 03:18 04:00 0.70 7,180 8,410 PROD4 DRILL WPRT P RIH 04:00 06:48 2.80 8,410 8,560 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 4175 CTP on bottom, 4000 of bottom 4610 BHP, 200 WHP, 1 - 3K WOB, 200 -300 Motor work 06:48 08:24 1.60 8,560 8,560 PROD4 DRILL WPRT P Wiper to window, 22K PUW, 11K RIW. Clean trip 08:24 10:18 1.90 8,560 8,710 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 4100 CTP, 4630 BHP, 240 WHP, 1 - 3K WOB, 200 -300 Motor work. Losing about 1 Bbl /Hr. 10:18 12:06 1.80 8,710 8,710 PROD4 DRILL WPRT P Wiper to window, 22K PUW, 12K RIW, 12:06 15:06 3.00 8,710 8,880 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 4100 CTP, 4620 BHP, 240 WHP, 1 - 3K WOB, 200 -300 Motor work. TD 15:06 16:36 1.50 8,880 7,165 PROD4 DRILL WPRT P Pump 6 low/ 10 high vis sweeps and wiper to window. 20K PUW 16:36 16:48 0.20 7,165 7,185 PROD4 DRILL DLOG P Tie in to RA, -3'. 16:48 17:48 1.00 7,185 8,879 PROD4 DRILL WPRT P Wiper back in hole, 11K RIW 17:48 18:48 1.00 8,879 5,900 PROD4 DRILL DISP P Tag TD at 8879', PUH laying in liner running pill. 23K PUW. Paint flag at 7600 EOP. Lay in KWF from 7400'. 18:48 20:18 1.50 5,971 0 PROD4 DRILL TRIP P Paint EOP flag 5900', Continue POOH 20:18 20:33 0.25 0 0 PROD4 DRILL SFTY P At surface, PJSM, Monitor well for flow 20:33 21:18 0.75 0 0 PROD4 DRILL PULD P LD BHA 17 21:18 22:03 0.75 0 0 COMPZ CASING SVRG P Prep floor to run liner 22:03 22:18 0.25 0 0 COMPZ CASING SFTY P PJSM, running liner 22:18 00:00 1.70 0 0 COMPZ CASING PUTB P Run liner Page 21 of 26 • • 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 PRODS 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 • 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 RECEVED JO 2 7 7q i; "l 1. {_, Antra Sla Coro ; issim /996 c ra 0/0 -043 gro -oG 5 /996(0 310 - �g9a� b� 010 _bars • • ALAsEA scifir[E o[ SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM IISSION 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 ConocoPhillips Alaska, Inc. Permit No: 210 -044 Surface Location: 1234' FSL, 317' FWL, Sec. 35, T13N, R9E, UM Bottomhole Location: 161' FNL, 834' 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 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. incerely, Daniel T. Seamount, Jr. i it Chair DATED this 'fday of 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 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 A tM�. I la. Type of Work: lb. Proposed Well Class: Development - O Q - Se ry i ce - Winj ❑ Single Zone 0 . lc. Specify if well is proposed for: Drill ❑ Re -drill El 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 • 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 9075' - TVD: 6695' • 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 161' FNL, 834' 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: 7150 . ft. 17. Maximum Anticipated ressu, es in psig (see 20 AAC 25.035) Maximum Hole Angle: 95° deg Downhole: psig 4:,s u54 , 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 1375' 7700' 6702' 9075' 6695' 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 20. Attachments: Property Plat ❑ BOP Sketch II Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements El 21. Verbal Approval: Commission Representative: Date: 4/4�0p/ (2O 22. I hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265 - 1102 Printed Name V. Cawvey Title Alaska Wells Manage ' � 7 �z), / Signature Phon 265-6306 Date y � 4' Commission Use Only to Permit to Drill API Numbe . Permit Approval See cover letter Number: 2. / Co Z ! T D 50 -(i . f - z. /6: 56, 7 - 64 Date: y/ I i/ /f for other requirements d Conditions of approval : If box // ii� checked, well may not be used to explore for, test, or produce coalbed m gas hydrates, or gas contained in shales: .,r 5 coo PS% ots r T , 1- Samples req'd: Yes ❑ No L 7 Mud log req'd: Yes ❑ No Er Other: .4 ".4'4.• �sf H2S measures: Yes l' ❑ Directional svy req'd: Yes 0 No ❑ 2500 r T�`� ^ Cam) dip APPROVED BY THE COMMISSION L / 6 ') DATE: f , COMMISSIONER Form 0 - 401 (Re ed 7/2009) This permit is valid r 4 • n fr the4latbf (Approval (20 AAC 25.005(9)) Submit in Duplicate •!""'— ct. /10•16 .''e Y C, v A '{' 9 • ii) • 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 %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. 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 • • 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 er 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 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 23/4', 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 5 / 8 " 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 n } }t, 1 i • 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- 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. 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 � i �� , �� �4 ? . s • • 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 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 Mud + ECD Combined 4068 psi 3384 psi (no choke pressure) ( underbalance (underbalanced d —412 psi) —553 psi) Target Pressure (13.3 ppg) 4500 psi 4500 psi Choke Pressure Required 432 psi 1116 psi • to Maintain 13.3 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° 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 O.R ! flY. 3K -09B + Proposed CTD Sidetrack 3 -1/2" TRMAXX -5E SCSSV © 2,183' MD ID = 2.812" MO _ 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 r_ 5586' @ 3172' MD 6307' IP 6839' 3-1/2" X Nipple @ 6888' MD (2.813" profile) LI • Baker PBR 6922' MD (4" ID) 1a1 o' Baker KBH -22 Anchor Seal Assembly @ 6935' MD (3.0" ID) Packer to g. �Perfs for Cement Baker SAB3 Packer © 6936' MD (4.0" ID) >, Packer Tubing Tail = 104' ,, i, ' 7033' - 7035' a r ;�' ;k I •" ,?` „ 2.813 "'XN' Nipple @ 6984' MD (2.75" min ID) ''` !11111111 WLEG © 7049' MD ^ II .... Ji ll 'Tubing Tail @ 7050' MD Tubing Tail to ' 1 [ 6 ,, , _ Top of Whipstock = 100' ', �; r e 2 -5/8" Openhde anchor /whipstock @ 7150' ,� � " " qt , ' ti1�1,1, ' South Laterals IKOP - 7700' 3K 096 L1 9075' WP03 2 -5/8" Openhde anchor/whipstock @ 7200' + ,�� u�H� i . �" il I 7250' - Bottom of Pilot Hole —' �' --;■= '-- -�- -�`—�' _.�1': " I� & 3 K 09BL2 9075' WP06 rr Ili I North Laterals � 1 ;i; 1 � �� A3 -sand peril 7279' 1 �fl41111111 a„ J�' i4.R ^� i vw W11-� .u..Lr,v -;4 .0 ua ;;:41� ��, t 1 � 4 r -729T MD t � ■ ■ um 1,411u Iii 3z4, 1 )pl r 326' MD eras 7310' ' • *r, �• r � .4+ g e l . "' . - 3K 03K : 1 0 50 WPO A2 - sand P OP - 8200' 7333' A a r 7339' ° 7 - i,1mv; -�. t- . ,- ,irmi. i .. . . .. -[� 7344' . ' .: ' "r 'a ` i 3K - 09B: 9975' WP06 7348' - 7352' . q PBTD @ 7410' . ;� -- 7" 26# J-55 shoe @ 7359' - 7363' i 11122/09 " , 7559' MD )0 Allik,,m"' KUP 3K -09A Conoco Phillips _ " Weul'Attributes` -= _ - _ _ . " MaxAngle - &MD STD Alaska. (r::. Wellbore APIIUWI Field Name Well Status Ind MD (tIKB) Act Btm (ftKB) Co 3x+cd A h@U� 500292165601 I (") KUPARUK RIVER UNIT I PROD 37.33 4,675.00 7,580.0 Comment H2S (ppm) Date Annotation End Date KB.Grd (R) Rig Release Date "' SSSV: TRDP 135 1/12/2008 Last WO: 9/5/2008 39.90 10/17/1986 well Cello: - 3K-09A, E. Ad1 OS 1"3°1 AM 1 Annotation Depth NEB) End Date Annotation Last Mad _. End Date Last Tag: SLM 7,397.0 11/22/2009 Rev Reason: TAG Imosbor 11/26/2009 CaaingnSls HANGER, o :: Casing Description String O String ID Top (tIKB) 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 (fti(B) Set Depth (t Set Depth (TVD)... String Wt... String ... String Top Thrd 0110 95 0.0 3,172.0 3,169.4 36.00 .1-5 Casing SURFACE Deseffption String 0_ String 8,697 ID ." Tap (/ti(B) Set Depth (1... Set Depth (TVD) ... Shin Wt... String 5 ••• String Tap Thrd Safety Valve, � � PRODUCTION 7 6.151 0.0 7,559.0 26.00 J-55 ;163 - e Tubing Strins' = _ g - Tubing Description String 0... String ID Top (ftKB) Set Depth (} 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-80 EUE 8rd 2306 Comple tlo ._ -- _ . e tach) - - - - - _ _ n De ' Top Depth ._ -.. _ _ . (TVD) Top roll Norm_ Top (1IXB) (91KB) (1 Item Deserlption Comment ID (in) SURFACE, D3,172 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 2,183.3 124 Safety Valve 3.5" TRMAXX -5E SCSSV w/ 2.812" X Profile EUE 8rd Mod 2.812 GAS LIFT, 3,533 6,888.0 6,390.0 31.54 NIPPLE 3.5" X Nipple w/ 2.813" profile 2.813 I' 1 6,927.6 6,423.7 31.23 LOCATOR Baker 3.5" Locator O.D. 4.54" I. D. 3.99" 3.030 oss LIFT 6,927.9 6,424.0 3123 SEAL ASSY Baker 8040 PBR w /Seal Assembly 0.D. 4.01" D I 2.99 2.990 4,657 us 1 Tubing Description String 0... String ID Top (M03) Set Depth (f Set Depth (TVD) String Wt... String String Top Thrd TUBING Original 31/2 Z992 6,921.6 7 050 0 6,528.1 930 L EUE 8rd GAS LIFT. Completion�Details -= - -- - - 5,586 Top Depth IS i Top Ind Top (fti(B) (6103) r) it.. Deseription NomL. Comment ID (In) GAS LIFT, 6,921.6 6,418.7 31.87 PBR Baker PBR Polish Bore Receptacle (6 Pins 40,000 ID Shear) 4.000 6,307 6,935.0 6,430.0 31.25 SEAL ASSY Baker KBH-22 Anchor Seal Assembly (3.5" EUE 8rd Box Up) 3.000 I 6,935.9 6,430.8 31.25 PACKER Baker 7" x 4.5" SAB3 Retainer Production Packer (LTC Box Down) 3250 GAS LIFT, 6.639 6,946.4 6,439.7 3128 XO- Reducing Crossover 4.5" LTC Box x 3.5" EUE 8rd Pin 3.500 IN 6,983.8 6,471.6 31.09 NIPPLE 2.813 " 'XN' Nipple (2.75" No-Go) 2.750 NIPPLE, 6666 it 7,049.1 6,527.4 31.59 WLEG Wireline Entry Guide 4.18" 0.D. 2 Other lif:Hoier In refine rettievable-plugsvalves,- Pumps, fish; etc) _ .- _ - - : Top Depth 11 T (Tw) Top Ind T op (11K 1+ 19 Description Run Dote ID (In) LOCATOR, 7,400 FISH 1 12" OV 1.5" OV LOST 2242006 2242006 6,928 NZ PBR, 6,928 7,473 FISH 1 12 DV 8 TG Latch Dropped to Ratho(e 12/16/1986 12/16/1986 i SEAL ASSY, ilr- 6,928 SEAL ASSY, C Perforations &Slots - - - _ - _ . - 6,935 Shot LL. Top (TVD) Btm(IVO) Dens PACKER, 6,936 % : Top (BBB) Btm (RIM) (BBB) (16(9) Zone Date MR- Type Comment I - 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 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 2 1/8' EnerJet, 0 deg ph xo Reduelng. 7,292 7,292 6,734.5 6,734.5 A-3, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph 6996 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 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 II 7,325 7,325 6,762.5 6,762.5 A -2, 3K -09A 12/14/1986 1.0 IPERF 2 1/8" 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 21/8" EnerJet, 0 deg ph 7,339 7,339 6,774.4 6,774.4 A -2, 3K-09A 12/14/1986 1.0 IPERF 21/8" EnerJet, 0 deg ph WLEG, 7,019 7,344 7,344 6,778.7 6,778.7 A -2, 3K -09A 12/14/1986 1.0 IPERF 21/8" EnerJet, 0 deg ph 7,348 7,352 6,782.1 A -2, 3K -09A 12/14/1986 1.0 IPERF 21/8" EnerJet, 0 deg ph 7,359 7,363 A-2, 3K-09A 12/14/1986 1.0 IPERF 21/8' EnerJet, 0 deg ph IPERF, 7,294 RPERF, . - - 7,279 -7,297 ` Nctef:,Genrei & Safet¢= - a 7 LL-f- . 3 ` - E - IPERF, 7,269 - - End Date Annotation 9/20/2008 NOTE: VIEW SCHEMATIC w /Alaaska Schematic9.0 IPERF, 7,292 IPERF, 7,294 - IPERF, 7,315 RPERF, 7,310.7,328 _ IPERF, 7,325 IPERF, 7,333 IPERF, 7,339 • - -- - IPERF, 7,344 _ . -- Mandrel' Details - Po rt Top Depth Top (ND) Ind OD Valve Latch Size TRO Run IPERF, Sfn Top (BBB) (RKB) (1 Make Model 1911) Sere Typo Type (In) (psi) Run Dote Com. 7.34e_7.3s2 - 1 2,396.3 2,396.2 2.10 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1,346.0 9/28/2008 2 3,532.7 3,523.8 11.53 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1,327.0 9/28/2008 IPERF, = 3 4,606.5 4,510.4 37.11 CAMCO MMG 1 12 GAS LIFT DMY ' RK 0.000 0.0 9/2/2008 7,359 - 7,363 -- - - 4 5,586.4 5,305.4 34.86 CAMCO MMG 1 12 GAS LIFT GLV ' RK 0.188 1,307.0 9/28/2008 5 6,307.0 5,900.3 33.83 CAMCO MMG 1 12 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 12 GAS LIFT OV RK 0.188 0.0 9/27/2008 FISH, 7,473 PRODUCTION, 0.7, ORIG1 @ \ L , TD (30 7,580 • • ConocoPhil Alaska ConocoPhillips(Alaska) Inc Kuparuk River Unit Kuparuk 3K Pad 3K -09 3K -09BL2 Plan: 3K -09BL2 wp06 Standard Planning Report 05 April, 2010 BAKER HUGHES - • • ConocoPhillips Waal 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 -09 Survey Calculation Method: Minimum Curvature Wellbore: 3K -09BL2 Design: 3K -09BL2_wp06 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 1 Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.23 ° :Welt = 3K -09 Well Position +NI-S - 200.11 ft Northing: 6,008,228.65ft Latitude: 70° 26' 0.812 N +E / -W -1.04 ft Easting: 529,305.92 ft Longitude: 149° 45' 39.960 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore -= 3K -09BL2 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 wp06 _ _ Audit Notes: Version: Phase: PLAN Tie On Depth: 7,150.00 Vertical Section: - Depth From (TVD) +W-S _ +E! W - Direction = - t 1= (ft) (ft) r) - 0.00 - 200.11 -1.04 211.00 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) ( 1100ft) (°l100ft) (1100ft) - -- ( °') Target 7,150.00 31.41 90.44 6,544.46 - 167.00 1,913.53 0.00 0.00 0.00 0.00 7,165.00 34.41 90.44 6,557.06 - 167.06 1,921.68 20.00 20.00 0.00 0.00 7,195.00 46.09 94.72 6,579.92 - 168.02 1,941.00 40.00 38.94 14.28 15.00 7,456.57 93.10 202.11 6,698.47 - 350.54 2,004.45 40.00 17.97 41.06 100.00 7,556.57 90.13 242.02 6,695.54 - 423.23 1,938.81 40.00 -2.97 39.91 93.50 7,606.57 87.13 247.22 6,696.73 - 444.65 1,893.67 12.00 -5.99 10.40 120.00 7,831.57 85.18 220.23 6,712.11 - 576.17 1,714.34 12.00 -0.87 -12.00 265.00 7,931.57 87.96 208.53 6,718.12 - 658.41 1,658.08 12.00 2.78 -11.70 283.00 8,131.57 89.96 232.46 6,721.81 - 809.36 1,529.17 12.00 1.00 11.96 85.50 8,456.57 94.99 193.73 6,707.20 - 1,076.01 1,355.12 12.00 1.55 -11.92 278.00 8,756.57 90.82 229.54 6,691.48 - 1,326.80 1,200.40 12.00 -1.39 11.94 95.50 9,075.00 87.86 191.44 6,695.28 - 1,596.09 1,041.78 12.00 -0.93 -11.97 265.50 4/5/2010 9 :36 :28AM Page 2 COMPASS 2003.16 Build 69 i • -- ConocoPhillips MUM 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 - 09 Survey Calculation Method: - I Minimum Curvature Welibore:. - - = 3K - 09BL2 Design: - 3K - 09BL2 wp06 = Planned Survey Measured _- TVD Below Vertical Dogleg , Toolface _ Al p_ Map , _ -D epth Inclination Azimuth System +WS .FE/ AN ' Section - Rate _ Azimuth Northing Eastlng (ftM _ (') ( ") (tt) (ft) (ft) (ft) (°H00ft) (0) (ft) _ (ft) 7,150.00 . 31.41 90.44 6,544.46 - 167.00 1,913.53 - 1,014.46 0.00 0.00 6,008,269.28 531,220.16 TIP / KOP 3K - 09A 7,165.00 34.41 90.44 6,557.06 - 167.06 1,921.68 - 1,018.61 20.00 0.00 6,008,269.25 531,228.31 End of DLS 20 7,195.00 46.09 94.72 6,579.92 - 168.02 1,941.00 - 1,027.74 40.00 15.00 6,008,268.37 531,247.63 3 7,200.00 45.78 97.47 6,583.39 - 168.40 1,944.57 - 1,029.25 40.00 100.00 6,008,268.00 531,251.20 7,300.00 53.20 150.10 6,650.98 - 209.44 2,002.42 - 1,023.86 40.00 98.09 6,008,227.19 531,309.21 7,400.00 77.27 185.83 6,693.71 - 296.22 2,018.06 - 957.53 40.00 62.39 6,008,140.48 531,325.18 7,456.57 93.10 202.11 6,698.47 - 350.54 2,004.45 - 903.96 40.00 46.67 6,008,086.11 531,311.79 4 7,500.00 91.91 219.46 6,696.56 - 387.67 1,982.32 - 860.74 40.00 93.50 6,008,048.90 531,289.81 7,556.57 90.13 242.02 6,695.54 - 423.23 1,938.81 - 807.85 40.00 94.26 6,008,013.17 531,246.44 End of DLS 40 7,600.00 87.53 246.54 6,696.43 - 442.07 1,899.70 - 771.56 12.00 120.00 6,007,994.19 531,207.42 7,606.57 87.13 247.22 6,696.73 - 444.65 1,893.67 - 766.24 12.00 119.91 6,007,991.59 531,201.39 6 7,700.00 86.22 236.03 6,702.17 - 488.90 1,811.73 - 686.11 12.00 -95.00 6,007,947.02 531,119.64 7,800.00 85.39 224.03 6,709.51 - 552.84 1,735.44 - 592.01 12.00 -94.35 6,007,882.78 531,043.60 7,831.57 85.18 220.23 6,712.11 - 576.17 1,714.34 - 561.14 12.00 -93.47 6,007,859.37 531,022.60 7 7,900.00 87.06 212.22 6,716.75 - 631.20 1,674.03 - 493.21 12.00 -77.00 6,007,804.18 530,982.51 7,931.57 87.96 208.53 6,718.12 - 658.41 1,658.08 - 461.67 12.00 -76.46 6,007,776.92 530,966.67 8 8,000.00 88.62 216.72 6,720.17 - 715.97 1,621.24 - 393.36 12.00 85.50 6,007,719.22 530,930.05 8,100.00 89.63 228.68 6,721.70 - 789.31 1,553.55 - 295.63 12.00 85.25 6,007,645.62 530,862.66 8,131.57 89.96 232.46 6,721.81 - 809.36 1,529.17 - 265.89 12.00 85.07 6,007,625.48 530,838.36 9 8,200.00 91.10 224.32 6,721.17 - 854.76 1,478.05 - 200.65 12.00 -82.00 6,007,579.88 530,787.43 8,300.00 92.72 212.43 6,717.83 - 932.97 1,416.11 - 101.71 12.00 -82.08 6,007,501.44 530,725.81 8,400.00 94.22 200.50 6,711.75 - 1,022.16 1,371.71 -2.39 12.00 -82.47 6,007,412.09 530,681.76 8,456.57 94.99 193.73 6,707.20 - 1,076.01 1,355.12 52.32 12.00 -83.20 6,007,358.17 530,665.38 10 8,500.00 94.47 198.94 6,703.62 - 1,117.53 1,342.96 94.17 12.00 95.50 6,007,316.61 530,653.38 8,600.00 93.15 210.89 6,696.95 - 1,207.86 1,301.00 193.21 12.00 95.93 6,007,226.13 530,611.78 8,700.00 91.68 222.81 6,692.72 - 1,287.66 1,241.18 292.41 12.00 96.73 6,007,146.10 530,552.29 8,756.57 90.82 229.54 6,691.48 - 1,326.80 1,200.40 346.97 12.00 97.23 6,007,106.81 530,511.66 11 8,800.00 90.41 224.35 6,691.01 - 1,356.43 1,168.68 388.71 12.00 -94.50 6,007,077.05 530,480.06 8,900.00 89.45 212.39 6,691.13 - 1,434.69 1,106.72 487.70 12.00 -94.56 6,006,998.55 530,418.42 9,000.00 88.52 200.42 6,692.91 - 1,524.08 1,062.34 587.18 12.00 -94.54 6,006,909.00 530,374.39 9,075.00 - 87.86 191.44 6,695.28 • - 1,596.09 1,041.78 659.49 12.00 -94.33 6,006,836.91 530,354.12 TD I 4/5/2010 9:36:28AM Page 3 COMPASS 2003.16 Build 69 QR IG!NAE. ConocoPhillips "dam • Conoco Phillips 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 Wellbore: 3K - 09BL2 Design: - 3K 09BL2_wp06 Targets Target Name - hWmiss target Dip Angle Dip Dir. _ _ TVD +WS - - +Et W - Northing - _ _ Easting -Shape ! °}` (e) (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 6544.51 ft at 7150.00ft MD (6544.46 TVD, - 167.00 N, 1913.53 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 6552.40ft at 7150.00ft MD (6544.46 TVD, - 167.00 N, 1913.53 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 Point 4 0.00 - 518.72 1,771.66 6,007,917.04 531,079.68 3K -09BL2 t5 0.00 0.00 6,706.00 - 1,093.12 1,350.33 6,007,341.05 530,660.66 70° 25' 52.029 N 149° 45' 0.310 W - plan hits target center - Point 3K -09BL2 t4 0.00 0.00 6,722.00 - 803.82 1,535.49 6,007,631.04 530,844.66 70° 25' 54.874 N 149° 44' 54.876 W - plan hits target center - Point 3K -09BL2 t6 0.00 0.00 6,692.00 - 1,319.58 1,208.42 6,007,114.06 530,519.65 70° 25' 49.802 N 149° 45' 4.475 W - plan hits target center - Point 3K -09BL2 t3 0.00 0.00 6,712.00 - 571.52 1,718.43 6,007,864.03 531,026.67 70° 25' 57.158 N 149° 44' 49.507 W - plan hits target center - Point 3K- 09BL2, BL2 -01 fal. 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 6676.62ft at 7150.00ft MD (6544.46 TVD, - 167.00 N, 1913.53 E) - Polygon Point 1 0.00 - 1,133.78 1,012.12 6,007,299.06 530,322.65 Point 2 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 Point 4 0.00 - 1,305.62 1,223.48 6,007,128.07 530,534.66 3K -09BL2 t7 0.00 0.00 6,695.00 - 1,595.94 1,041.31 6,006,837.06 530,353.64 70° 25' 47.084 N 149° 45' 9.379 W - plan hits target center - Point ! 3K -09BL2 t1 0.00 0.00 6,699.00 - 339.65 2,008.37 6,008,097.02 531,315.67 70° 25' 59.437 N 149° 44' 40.997 W - plan hits target center - Point 3K -09BL2 t2 0.00 0.00 6,696.00 - 427.35 1,931.02 6,008,009.03 531,238.67 70° 25' 58.575 N 149° 44' 43.268 W - plan hits target center - Point 4/5/2010 9:36:28AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips ConocoPhilhps Planning Report BAKER Alaska HUGHES Database:: EDM Alaska Prod v16 Local Co-ordinate Reference: ' Site Kuparuk 3K Pad Company: ConocoPhillips(Alaska) Inc. ND 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 - 09BL2 Design: -_ = 3K 09BL2_wp06 Casing Points .. ., _- Measured Vertical - Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name . - _ O - 3,172.00 3,100.46 10 3/4" 10 -3/4 13-1/2 9,075.00 6,695.28 2 3/8" 2 -3/8 3 Plan Annotations Measured Vertical - Local Coordinates - - Depth = Depth + HUS - +EI-W (ft) _ (ft) (ft) - (ft) - Comment 7,150.00 6,544.46 - 167.00 1,913.53 TIP / KOP 3K -09A 7,165.00 6,557.06 - 167.06 1,921.68 End of DLS 20 7,195.00 6,579.92 - 168.02 1,941.00 3 7,456.57 6,698.47 - 350.54 2,004.45 4 7,556.57 6,695.54 - 423.23 1,938.81 End of DLS 40 7,606.57 6,696.73 - 444.65 1,893.67 6 7,831.57 6,712.11 - 576.17 1,714.34 7 7,931.57 6,718.12 - 658.41 1,658.08 8 8,131.57 6,721.81 - 809.36 1,529.17 9 8,456.57 6,707.20 - 1,076.01 1,355.12 10 8,756.57 6,691.48 - 1,326.80 1,200.40 11 9,075.00 6,695.28 - 1,596.09 1,041.78 TD 4/5/2010 9 :36 :28AM Page 5 COMPASS 2003.16 Build 69 ;s�i 1 i i f 4 i iy 9 a y 5 '1+w�'� E � r .a rmmimBmTrnewrm WELLBORE DETAILS: 3K -09BL2 REFERENCE INFORMATION Project: Kuparuk River Unit Magnetic NoM:21.65 Site: Kuparuk 3K Pad Sec Coorc%nate (N/E) Reference Well 3K -09, True North Waal Magnetic h 57 .6 Parent io MD 3K-09A Well: MILKER e 3K s6enMk eld Vertical (ND) Reference Mean Sea LLevel "° Tie on MD: 7150.00 Wellbore: 3K-096L2 DivAnek:80.s (VS) Reference SIW - (O.00N, O.00E) Ct711 ©CCJR �"t11 ij)5 Plan :3K- 09BL2 09BL2) NbtlNBGG Measured Depth Reference: 3K -09@69.00f -09) Calculation Method: Minimum Curvature HUGHES 600 , . - _ - . 450 WELL DETAILS: 3K -09 , ,, ' : Ground Level: 0.00 300 TIP /KOP3K -09A +N / -S +E/ -W Northing Eastmg Latittude Longitude Slot , 0.00 0.00 6008228.65 529305.92 70° 26' 0.812 N 149° 45' 39.960 W i 4 1,-0 0 4 3k -09:\ 150 - -I - �, . SECTION DETAILS ANNOTATIONS Sec MD Inc Azi TVDSS +141 -5 +E/-W DLeg TFace VSec Target Annotation 1 7150.00 31.41 90.44 6544.46 33.12 1914.57 0.00 0.00 - 1014.46 TIP I KOP 3K -09A 2 7165.00 34.41 90.44 6557.06 33.05 1922.72 20.00 0.00 - 1018.61 End of DLS 20 - 150 3 7195.00 46.09 94.72 6579.92 32.10 1942.04 40.00 15.00 - 1027.74 3 C 4 7456.57 93.10 202.11 6698.47 - 150.43 2005.49 40.00 100.00 - 903.96 4 -3oo - 5 7556.57 90.13 242.02 6695.54 - 223.12 1939.85 40.00 93.50 - 807.85 End ofDLS40 7 6 7606.57 87.13 24722 6696.73 - 244.53 1894.71 12.00 120.00 -76624 6 0 8 End of DLS 40 7 7831.57 85.18 220.23 6712.11 - 376.06 1715.38 12.00 265.00 . - 561.14 7 `r, - 450 8 7931.57 87.96 208.53 6718.12 - 458.30 1659.13 12.00 283.00 -461.67 8 9 9 8131.57 89.96 232.46 6721.81 -609.25 1530.21 12.00 85.50 - 265.89 9 + - 600 : , 4111 10 8456.57 94.99 193.73 670720 -875.90 1356.17 12.00 278.00 52.32 10 11 8756.57 90.82 229.54 6691.48 - 1126.68 1201.45 12.00 95.50 346.97 11 R - 750 12 9075.00 87.86 191.44 669528 - 1395.98 1042.83 12.00 265.50 659.49 TD l0 ' -900 ' 5' -- '° v, -1050 - • 1 ,,. -- - -._.. - -- - --- -- -1200 ' -1350 3K- 09/3K -09BL2 ' TD ..as.,. -1500 j '.: _ N _ - -1650 _ __ _ __ _ _ __ . --�.»,w 300 450 600 750 900 1050 1200 1350 1500 1650 1800 1950 ^ 2100 2250 2400 2550 2700 2850 3000 6450- West( -) /East( +) (150 ft/in) 6500- , � , . T1P /KOP3K -09A 6550- End of DLS 20 -- 6600 3 • O� 6650,, , - I T, 6700- I i Ii in 6750- 4 i 6 7 8 9 10 11 ' U 5) End ofDLS40 3K -09/3K -09BL2 . -E m 6800- > g y 6850 I E--, 6900 - ;k_oo ; s .lm : \ 6950- - , 7000-- 3K- 09/3K -09� I -1150 -1100 -1050 -1000 -950 -900 -850 -800 -750 -700 -650 -600 -550 -500 -450 -400 -350 -300 -250 -200 -150 -100 -50 0 50 100 150 200 250 300 350 400 450 500 550 600 650 700 750 Vertical Section at 211.00° (50 ft /in) • • • TRANSMITTAL LETTER CHECKLIST WELL NAME J / 1 �1� ( , PTD# 2- ( r n /Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: 4t: . -z< L l /(-) POOL: . �, . � t 6� � U 1 / 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 o existing well /� t-? G , / (If last two digits in API number are Permit No. -z - /vCJ Z - L; API No. 50 -( - �Go � -G Z. 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. 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